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Collaborating Authors
Abstract The increasing impact of climate change illustrates the necessity to reduce carbon intensity in industry. Many countries have already set a target to achieve carbon neutrality by 2050. However, not only regulation by authorities is an important driver, but public perception and investor interest also push all relevant industries to increase their efforts to act more sustainably. Therefore, an increasing number of companies has also set internal targets for sustainability and greenhouse gas reductions. The target of transformation to a carbon-free society is widely acknowledged. Ammonia as a key element for fertilizer production and hence agriculture, but also as a potential energy carrier, plays an important role. According to IEA [IEA NH3 2021], ammonia production contributes 450 mil. t direct CO2 emissions per year. Additionally, the related power consumption and emissions from the use of urea add 170 mil. t indirect CO2 emissions annually. This corresponds to almost 2 % of the world’s total CO2 emissions, which are reported 31.5 Gt in 2020 [IEA Energy 2021]. Therefore, the NH3 industry has the potential and obligation to contribute to overall CO2 emissions reductions. The average direct CO2 emissions per produced ton of ammonia is approx. 2.4 tons. However, the emission value of a specific plant depends widely on feedstock, applied technologies, and age. Ammonia plants based on natural gas roughly emit 1.8 t CO2 per t NH3, and even lower numbers are achieved nowadays. Coal-based plants on the other hand emit approx. 3.2 t CO2 per t NH3, due to the high carbon content of the coal.
I am old enough to have experienced a change in thinking among oil and gas (O&G) executives and professionals — from a general skepticism, or even denial, to a more open mind toward climate change and carbon emissions. Perhaps arising as a late and uncomfortable reaction to scientific consensus and demands from consumers, shareholders, and the government, the energy industry nevertheless has come to acknowledge the impact it has on the environment and is taking proactive steps to counter the impact. This change in thinking also represents a business opportunity. O&G and service companies have a unique competence in dealing with the large uncertainty and extreme capital intensity of energy projects. They are experienced in scaling up technologies and developing cost-effective solutions. As such, they can make a big difference in a low-carbon and renewable future. In what some might view as a paradox, O&G practitioners can become the champions of the energy transition.
- North America > Central America (0.30)
- South America > Chile (0.25)
- South America > Bolivia (0.25)
- South America > Argentina (0.25)
Abstract Most major economies around the world have committed to meeting ambitious net zero targets by 2050. As a versatile, clean and safe energy carrier, hydrogen is expected to play a crucial role in the transition to net zero. Large-scale, economic production of low carbon hydrogen is essential for the mass decarbonisation process, and this is especially true for hard-to-abate sectors such as the steel, cement and chemical industries, as well as dispatchable power, domestic heating and transport. To accelerate the energy transition, Johnson Matthey (JM) has developed a unique carbon capture and storage (CCS)-enabled hydrogen production process that economically delivers very low carbon intensity hydrogen, commonly known as ‘blue’ hydrogen. The flowsheet combines a gas-heated reformer (GHR) and autothermal reformer (ATR), and provides a more energy efficient process than both conventional steam methane reforming (SMR) and flowsheets that deploy a stand-alone ATR, ultimately resulting in a higher hydrogen yield and reducing natural gas consumption. JM's GHR-ATR blue hydrogen technology makes decarbonisation via CCS easier and cheaper than using an SMR. By delivering a CO2 capture rate of over 95%, the technology provides significant benefits compared with SMR and alternative ATR technologies. Compared with conventional SMR, JM's GHR-ATR blue hydrogen technology demonstrates: Natural gas consumption – 10% lower CO2 produced – 10% less Capital cost for the CO2 capture system – 75% lower Use of JM's unique GHR-ATR blue hydrogen technology will future-proof and de-risk projects by minimising the impact of rising feedstock, CO2 transmission and storage costs, as well as potential governmental schemes for carbon taxation. This process will enable hard-to-abate sectors to reduce Scope 1 and Scope 2 emissions by decarbonising their operations, accelerate the energy transition by producing clean hydrogen for consumers, ensure the viability of the plant for the future, and demonstrate commitment to sustainability. JM's GHR-ATR blue hydrogen technology has been selected for deployment by HyNet North-West, the United Kingdom's first low carbon hydrogen plant. The 300 MW plant is expected to be built in the UK in 2026 (pending the final investment decision), and will provide hydrogen to industrial and eventually domestic customers.
ExxonMobil has awarded a contract to Technip Energies for front-end engineering and design (FEED) of its planned low-carbon hydrogen, ammonia, and carbon capture facility destined for Baytown, Texas. A final investment decision for the project is expected by 2024. The facility is expected to produce 1Bcf/D of low-carbon hydrogen, making it the largest low-carbon hydrogen project in the world at planned startup in 2027–2028. More than 98% of the associated CO2 produced by the facility, or around 7 million metric tonnes per year, is slated to be captured and permanently stored. The carbon capture and storage network being developed for the project will be made available for use by third-party CO2 emitters in the area in support of their decarbonization efforts.
Abstract The challenge of meeting ever-pressing energy demand and reducing GHG emissions presents a significant challenge. One of the recent trends in the energy transition is hydrogen, which is experiencing unseen support from various stakeholders. Hydrogen roadmaps and net-zero strategies announced by governments and companies indicate that demand for low-carbon hydrogen will increase significantly. Therefore, it is essential to establish a reliable supply of low-carbon hydrogen. In our previous work, we have shown that Kazakhstan is located between the two largest hydrogen markets - China and Europe. Natural gas can be a feedstock material for low-carbon hydrogen, which is also known as blue hydrogen. Kazakhstan holds the 16th largest natural gas reserves in the world. Nevertheless, finding feedstock natural gas for hydrogen in Kazakhstan can be challenging. In 2020, the gross natural gas production in Kazakhstan reached 55.1 bcm of natural gas of which 34.8 bcm and 20.3 bcm are commercial and reinjected volumes, respectively. Commercial volumes are tightly used for rising domestic market and export. Reinjection volumes are also tightly used to maintain the production of oil in the largest hydrogen reservoirs of the country - Tengiz, Kashagan and Karachaganak. In our work, we propose an approach to use reinjected gas volumes for large-scale hydrogen production while keeping the oil production targets in the largest fields as before. CO2 emissions resulting from the hydrogen production would be used to replace currently reinjected natural gas in maintaining reservoir pressure. CO2 can decrease the viscosity of the reservoir fluid, thus enhancing oil recovery (EOR). This work presents the viability of the concept in the example of the Kashagan field by showing the material balance of both surface and subsurface processes. Several development scenarios were which also involved coproduction of elemental sulfur and methanol. Blue hydrogen production was modeled in Aspen Hysys v12.1.
- Asia > Kazakhstan > West Kazakhstan Region (0.41)
- North America > United States > Texas (0.28)
- Asia > Kazakhstan > Atyrau Region > Caspian Sea (0.25)
- Energy > Renewable > Hydrogen (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (0.70)
- North America > United States > Texas > Permian Basin > Yeso Formation (0.99)
- North America > United States > Texas > Permian Basin > Yates Formation (0.99)
- North America > United States > Texas > Permian Basin > Wolfcamp Formation (0.99)
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