Global anthropogenic CO2 equivalent (CO2e) emissions continue to rise year on year, resulting in a predicted global surface temperature rise of 3.2 o C (2.2 -3.5 o C) by 2100 if all implemented climate policy targets are reached , the Sixth Assessment Report by the International Panel on Climate Change (IPCC) states that "All global modelled pathways that limit warming to 1.5°C (>50%) with no or limited overshoot, and those that limit warming to 2°C (>67%), involve rapid and deep and, in most cases, immediate greenhouse gas emissions reductions in all sectors this decade". Within the global emissions scenarios considered within the sixth assessment report, those that have a greater than 67% chance of limiting global temperature rise to less than 2 o C include between 196 -280 Gt of sequestered CO2 from fossil CO2 alone by 2100 , not including atmospheric CO2 removal via bioenergy with CCS (BECCS) or direct air CO2 capture and storage (DACCS). The International Energy Agency's (IEA) Sustainable Development Scenario, in which global emissions from the energy sector reach net zero by 2070, includes 240 Gt CO2 sequestered by 2070, accounting for 15% of emission reductions . As of 2023, around 40 carbon capture and storage (CCS) facilities are in operation globally, capturing approximately 0.045GtCO2/pa, with an additional 50 planned to come online by 2030, capturing an additional 0.125GtCO2/pa . Although ambitious, this is an order of magnitude short of the approximate 1.2GtCO2/pa capacity needed in the Sustainable Development Scenario, highlighting the wide gap between aspirations and actions. It is clear that if CCS is to contribute significantly to global climate change mitigation efforts, a rapid increase in the deployment of CCS facilities is required. Post-combustion capture (PCC) encompasses any technology that separates CO2 from a gas mixture downstream of an industrial process. Typically, this is a high-volume flow rate of combustion products and possibly additional CO2 released from process materials, e.g. limestone, at atmospheric pressure, containing mainly nitrogen, water, and oxygen, with varying quantities of CO2 . Depending on the process, the flue gas to be treated may contain trace impurities to varying degrees, including CO, NOx, SOx, volatile organic compounds (VOCs) and ammonia (NH3), to name a few. Potential applications for PCC deployment cover all facets of the industrial decarbonisation landscape, from the energy sector by decarbonising critical dispatchable power infrastructure such as combined cycle gas turbines (CCGT) and coal-fired power plants and decarbonising home heating and transport with blue hydrogen production to raw material production such as cement, glass and metal. Additional cross-industry applications lie in waste and biogenic fuel combustion, contributing to energy production, waste management, raw material recovery and negative emissions. Numerous technologies are under consideration for large-scale post-combustion capture, including solid adsorption, CO2 selective membranes, and cryogenic separation; however, the most technologically and commercially mature and the focus of this manuscript is amine-based CO2 capture. Amine-based post-combustion CO2 capture functions on the principle that amine groups will bond with acid gases, such as CO2, to form a carbamate or bicarbamate compound in a temperature-reversible reaction and, as such, can be used to separate acid gases from a dilute gas stream in a two-step absorption and desorption thermal swing process. Absorption typically occurs in a packed bed absorber column at close to atmospheric conditions. Within this column, the flue gas contacts in a counter-current fashion with descending CO2 lean liquid solvent, transferring CO2 in the gas phase to the amine solution as it travels up through the column. For a given liquid to gas ratio the residence time of the liquid solvent in the packed bed absorber column, and so also the duration of exposure of the liquid solvent to the gases, in particular CO2, O2, NOx and combustion impurities, contained in the flue gas, is proportional to the packing height. CO2 lean flue gas leaves the top of the absorber column after emission control techniques to minimise unwanted carryover of amine and amine-derived products, while CO2-rich liquid solvent leaves the bottom of the column for regeneration. Regeneration occurs in a separate pressurised desorber or "stripper" packed bed column; CO2-rich solvent descends through the stripper and condenses steam, which has been generated at the bottom of the column. As the steam condenses, it heats the rich solvent and reverses the carbamate/bicarbamate forming reaction, liberating CO2. Mostly, CO2 lean solvent exits the stripper packing and passes through a reboiler, where a thermal energy source heats the solvent, further liberating CO2 and generating the stripping steam. The highest temperature in the post-combustion capture process occurs in the reboiler. CO2/H2O vapour leaves the top of the desorber column for drying, conditioning and compression for export while the now CO2 lean solvent is returned to the absorber. At all stages the steam also provides a stripping function, by reducing the partial pressure of the CO2; the ratio of CO2 to H2O vapour at equilibrium with the solvent depends on total pressure, solvent loading and temperature. Amine CO2 capture solvents are ammonia (NH3) derivatives where a substituent, such as an alkyl or aryl group, has replaced one or more hydrogen atoms. They can be broadly characterised into primary (with monoethanolamine (MEA) being the most widely known example for CCS applications), secondary and tertiary amines, representing how many hydrogen atoms have been substituted for alkyl or aryl groups. Due to its reactivity, low cost and ease of reclamation, MEA continues to serve as a viable solution for CO2 capture from low-concentration CO2 flue gases. Stainless steel construction or corrosion inhibitors for carbon steel constructions can mitigate the corrosion concerns present for higher concentration solutions, while advanced configurations and control processes continually improve thermodynamic efficiency, particularly at high CO2 capture fractions. Historically, CO2 capture fractions, defined as the mass of CO2 exported divided by the mass of CO2 entering the absorber, of 90% were targeted. However, in recent years, net-zero commitments have challenged this assumption's viability, as 10% residual emissions from PCC is clearly incompatible with these goals unless some form of permanent negative CO2 emission technology is concurrently employed to recapture the residual emissions. The economically optimal CO2 capture fraction will be the point at which the marginal cost of increasing the CO2 capture fraction is more than the lowest cost permanent negative CO2 emission technology that is available to recapture and permanently store the emitted CO2 (a point that will change as both technologies are deployed at scale). In the absence of a definitive economic optimum, the CO2 capture fraction that results in no net addition of CO2 to the atmosphere is considered for this work. This CO2 capture fraction is dependent on the ratio of atmospheric CO2 entering the boundary of the facility with atmospheric air (typically used for combustion) and the added CO2 generated by that combustion or other processes within the facility, and, as such, varies from application to application (see Eq 1). However, it typically falls between 99.2% for a CCGT up to 99.8% for a steam methane reformer (SMR). Mullen et al. term this CO2 capture fraction as 100% fossil CO2 capture however 100% added CO2 will be use in this manuscript to account for biogenic CO2. This terminology will be adopted throughout this manuscript, while capture fractions below this will be reported as gross CO2 capture fractions, as is typical for the industry.