Aspen HYSYS Expert Certification - ACE

examine how the CPA fluid package models gas dehydration with glycols, covering Meg, DEG, and Teg; version 12 recommends CPA for Meg and DEG, Teg usable with either package.

Identify the sour water property package as the fluid package that handles H2S, ammonia, and water; caustic for property package and sour water also cover these components.

Explain the acid gas chemical solvent package: require at least one chemical solvent like amine monoethanolamine, carbon dioxide, H2S, and water, with solids, essays, salts, and ions not supported.

Select the sulfur recovery fluid package to auto-create calcium sulfur recovery component list, including must-have components and sulfur species like H2O and CO2, while solids and reactions are not supported.

The sour water property package requires ammonia, carbon dioxide or hydrogen sulfide, and water, with components allowed; salts, solids, amines, or physical solvents are forbidden, and heat-stable salts are permitted.

Explore the acid gas cleaning workflow, detailing how amines like MEA and DEA remove H2S, CO2, and sulfur compounds, then regenerate and recycle amines while addressing degradation.

Explore how acid gas is reported and monitored in Aspen HYSYS, detailing adsorption, absorption, and the acid gas versus sweet gas streams.

Set up a sulfur recovery unit in SulSim, choosing calcium or sulfur recovery. Configure the thermal stage with a reaction furnace, waste heat exchanger, and sulfur condenser.

Examine the tail gas treating section of a sulphur recovery unit, including condensers, hydrogenation beds, absorbers, quench towers, and incinerators, with Aspen HYSYS simulations of thermal and catalytic sections.

Learn how a stream saturator in Aspen HYSYS removes water from hydrocarbon feeds, saturating the hydrocarbon with water to prevent hydrate formation, with adjustable humidity, temperature, and pressure.

Learn how water dew point marks the temperature where water condenses during dehydration and how to calculate it for dry gas in Aspen HYSYS.

Learn how inhibitors lower the hydrate formation temperature in hydrocarbon streams containing water, using methanol, ethylene glycol, diethylene glycol, or triethylene glycol in Aspen HYSYS to prevent ice-like hydrates.

Explain sub dew point catalytic converter in a sulfur recovery unit, covering gas phase operation, thermal and catalytic stages, and outlet temperatures below sulfur dew point temperature.

Explore the empirical furnace model in sulfur recovery, selecting models for H2S at 35% and NH3 at 20%, including co-firing and straight-through options for acid gas streams.

Explore the degasser function within a sulfur recovery unit, removing dissolved H2S from liquid sulfur to vapor and routing elemental sulfur from thermal and catalytic stages to the Dickerson.

Learn to simulate acid gas removal with DEA in Aspen HYSYS, converting sour gas (H2S, CO2) to sweet gas via a DEA contactor and amine regeneration.

Learn to build and troubleshoot an acid gas flowsheet using amine solvents and MDA makeup. Simulate concentrations, convergence, and column hydraulics for optimized removal of CO2 and H2S.

Compare the original acid gas case to four new states in the asset case starter lab by adjusting MDA and mono diethanolamine concentrations; analyze H2S ppm and CO2 mole percent.

Explains a gas dehydration process in Aspen HYSYS using triethylene glycol to remove water from wet gas via an eight-tray absorber and TG regeneration.

Explore gas dehydration in Aspen HYSYS by determining water dew point, hydrate formation conditions, and a case study analyzing how inlet gas temperature affects lean teg purity and dew point.

Learn to evaluate a sulfur recovery unit with acid gas and sour water feeds, set H2S concentrations, apply oxygen enrichment models, and use EDA to control H2S to SO2 ratio.

Master column lab techniques in Aspen HYSYS by building a distillation column, configuring the demethanizer, condenser, and reboiler, and evaluating ua, efficiency, and hydraulic performance.

Model a three-stream upstream gathering system in the Aspen Hysis upstream lab, using Aspen Hydraulics with branches, mixers, and STD 80 mm pipe, and apply TB transfer basis.

Analyze upstream flow assurance by applying heat transfer losses, estimating network outlet temperatures, and assessing erosion and hydrate formation across branches.