morteza zarrinzadeh’s Post

#mechaniverse What does SO3 do to you after oxidation of sulfur compounds? During the oxidation of sulfur compounds, a small amount (typically 1%–5%) of the sulfur dioxide is further oxidized to SO3. The extent of conversion depends on a number of conditions like: 1️⃣ Temperature profile the flue gas, 2️⃣ The amount of SO2 in the flue gas, 3️⃣ The potential catalytic action of alumina refractory material Once formed, SO3 reacts at a temperature of between 450°F and 650°F (230°C and 340°C), with water in the gas stream, to form sulfuric acid. Sulfuric acid can cause several problems: 1️⃣ First, it raises the dew point (substantially sometimes) to temperatures greater than 400°F (200°C). Sulfuric acid condensation can lead to rapid corrosion of carbon steel surfaces 2️⃣ Second, when quenched rapidly, sulfuric acid can form an extremely fine aerosol that is difficult to remove in a packed bed scrubber 3️⃣ Third, the fine aerosol can create a visible plume that has a bright blue-white hue which is a form of pollutant. So be careful about you sulfur compounds oxidation! Photo: pcc-group.com #mechanicalengineer #pollution #acidgas #johnzinkhandbook #sulfuricacid #tailgasincinerator #thermaloxidizer

Steam injection as an enhanced oil recovery [EOR] method has undergone profound changes in its applications since it began to be used commercially in the oil industry around the 1960's. It is particularly focused on heavy and extra-heavy crude oils [X-Xp] and is based on its effect on viscosity reduction in an order close to 600 times the fluid viscosity at reservoir temperature. In line with climate change one of the main disadvantages of steam injection is its large carbon footprint, given the high energy demand required to generate and procure; not only the volume, but the steam quality and the stability of the steam front. Its adverse effects on the reservoir range from a significant increase in in-situ water saturation behind the mixing zone, viscous fingering, water coning, and formation damage mainly by particle dislodging, and the migration of the asphaltene deposition envelope. On surface, disadvantages focus mainly on controlling the reliability of steam quality and injection volume. Some ad ups have more recently surfaced linked to the use of hybrid energy sources to reduce its carbon footprint, as well as the mixing of certain-key-gases with the steam, basically to balance the carbon footprint by capturing carbons, but also to improve in some extend the sweep efficiency, the stability of the viscous front, and to reduce the effects of formation damage.

Sulfidation is primarily caused by H2S and other reactive sulfide species formed by the thermal decomposition of sulfur compounds at high temperatures. Some sulfur compounds react more readily to form H2S. Therefore, it can be misleading to predict corrosion rates based on weight percent of sulfur alone. Knowing the total “reactive sulfur” in the process stream is key to predicting or assessing its actual corrosivity.

CORROSION vs. ENVIRONMENTAL CRACKING The cracking of carbon steel components in amine service is often related to the general corrosivity of amine solutions. Corrosion reactions are the source of atomic hydrogen, which causes hydrogen blistering and cracking of wet H2S mechanisms, primarily in rich amine service. Similarly, corrosion reactions can contribute to Alkaline mechanism, primarily of equipment in lean amine service. The problems fall into two major categories : Environmental cracking. a. Sulfide stress cracking (SSC). b. Hydrogen-induced cracking (HIC) associated with hydrogen blistering. c. Stress-oriented hydrogen-induced cracking (SOHIC). d. Alkaline stress corrosion cracking (ASCC). Corrosion. It results from dissolved acid gases, including hydrogen sulfide and carbon dioxide. It can also be caused by a variety of amine degradation products including heat stable salts. API RECOMMENDED PRACTICE 945, Avoiding Environmental Cracking in Amine Units #API #API945 #NACE #AMPP #CORROSION #CORROSIONCONTROL #ASSETINTEGRITY

Let's talk about: Corrosion in natural gas.

Let's talk about: Corrosion in natural gas: amine-sweetening units.

High Pressure （71 bar) Carbon Dioxide Gas Dehydration Adsorption Dryer Unit

How do microbes contribute to corrosion? Corrosion is an electrochemical phenomenon that results in the deterioration of a metal surface and can result from a variety of different means. Abiotic (non-microbiological) corrosion can occur via CO2, H2S, acid, and general concentration cell mechanisms. Through a complex series of interactions between microbes, chemicals in the environment and the metal surface, biotic corrosion otherwise known as microbiologically influenced corrosion (MIC) can occur as well. MIC mechanisms can both directly or indirectly initiate, contribute to, or accelerate corrosion caused by any other number of mechanisms. Microbes affect corrosion by producing corrosive metabolites (H2S, iron sulfide, sulfuric acid, organic acids, CO2 ), fixing anodic sites, altering passivating films, or direct uptake of electrons from the metal surface. https://buff.ly/308EwX5 #microbes #corrosion #souring #biocides #water #oilandgas #ATP #OilandGas #ATPTesting #MicrobialMonitoring #oilandgasbiocides #calgary #houston #watertreatment #biocideexperts #FIFRA #PMRA #Antimicrobial #Assetintegrity #Fuelbiocides #IndustrialWaterTreatment #IWT

Corrosion-causing elements: Corrosion in the steam system; steam line; turbine or condenser appears, in a localized way, by pitting or alveolus. This does not reduce their danger, because even in new pipes or with little time of use they can puncture, and consequently, cause the equipment to stop. The main causes of corrosion in boilers are: Acidic pH; dissolved oxygen; high levels of sodium hydroxide and chlorides; presence of copper and nickel; suspended solids; presence of hydrogen sulfide gas; porous, complexing or chelating deposits; hide-out; and less frequently, leakage currents and thermal shocks. Corrosion in condensate lines can occur because it contains in steam, oxygen, carbon dioxide, ammonia, sulfur dioxide and hydrogen sulfide gas. Oxygen is the main corrosive agent in condensate lines. At the same concentration as carbon dioxide, its corrosion rate is six to ten times higher.

Why Ammonia used in Carbonitriding process as Nitrogen source? Why not direct Nitrogen(N₂) gas? Nitrogen gas is not directly used for carbonitriding as Nitrogen source because molecular nitrogen is extremely stable and difficult to dissociate at the carbonitriding temperatures. This stability makes it inefficient as a source of nitrogen for surface hardening processes. Ammonia is used as the nitrogen source because when ammonia is introduced into the furnace, it dissociates into nitrogen and hydrogen: 2NH3→2[N]+3H2 This reaction is thermodynamically favorable and produces atomic nitrogen on the steel surface, which is reactive and can diffuse into the steel and it helps to maintain the required Nitrogen % in the atmosphere. Can anyone share, how to calculate the Ammonia flow rate required for furnace atmosphere?