Callide Oxyfuel Project Research Articles

Current Activites for Commercialization of Oxyfuel Power Plant

IHI has been developing oxyfuel technology as one of the CO2 capture technologies from coal fired power plants since 1989. For the demonstration of oxyfuel combustion technology, IHI jointly formed and participated in “Callide Oxyfuel Project” with Australian and Japanese partners in 2008. In the Project, the applicability of the technology to an existing power plant, the reliability and the effectiveness for CCS were demonstrated through achievement of more than 10,000 hours oxyfuel operation and underground injection of CO2 that captured from oxyfuel coal power plant. After completion of the demonstration, additional tests were carried out in the laboratory and at the pilot-scale combustion test facilities in IHI’s Aioi Works. The additional test purpose is to check the performance of the equipment mostly used in current power plants in order for the technology to be flexibly applied to them. For example, the vertical type roller mill and the ESP were tested. In vertical type roller mill test, it was made clear that the effect of moisture concentrated in the flue gas in oxyfuel system was not so big for the pulverization of coal. In ESP test, it was clearly found that the dust collection efficiency in oxyfiring combustion is higher than that in airfiring combustion.

Analysis and Evaluation of Ash Deposits from the Coal-Fired Callide Oxyfuel Project

After the close of the Callide Oxyfuel Project, mature deposit samples were collected from the primary and secondary superheater tubes. These samples were studied with the aim of providing a description of deposits from an industry-scale oxy-fuel plant and to gain some understanding of the deposition mechanism involved in their formation. The deposits formed over a 3 year operating period, with both air and (more extensive) oxy-firing, including many air-to-oxy transitions, boiler starts and trips, and fired predominantly by a coal with Fe2O3 in ash analysis of about 10%. The mineral character of the coal is relatively simple with silicon and aluminum clays and silica and iron-containing siderite dominant. This character allows for the plotting of chemical analysis results in triangular phase diagrams used to interpret scanning electron microscopy with energy-dispersive X-ray spectroscopy analysis, with iron being associated with the slagging mechanisms. The deposits were unusual in that layers of iron-ri...

A comparative study on the design of direct contact condenser for air and oxy-fuel combustion flue gas based on Callide Oxy-fuel Project

Direct contact condenser is widely used in oxy-fuel combustion capture systems. Unusually high content of water vapor in the flue gas requires rigorous sizing procedures for the condenser design. Non-linear differential equations for humidity, gas and liquid temperatures were set up to understand the evaporation/condensation process in the condenser. A Quasi-Newton method was adopted to simultaneously solve discrete equations to avoid difficulty in convergence.This model was firstly verified with reported experiments in a packed bed condenser. The significant impacts of L/G ratio on condenser height, packing volume, condenser diameter are identified. The optimum L/G range is obtained by the wet bulb temperature and minimal decrease on packing volume, and this results in the L/G range of 2.5–5.2 and 4.3–6.7 for air and oxy-fuel combustion respectively. The condenser diameter and packing volume corresponding to the optimum L/G range for air-fuel combustion are approximately twice and four times of these for oxy-fuel combustion. While the packing height for air-fuel combustion is slightly lower than that for oxy-fuel combustion.By economic analysis, normalized total capital and annual costs for air-fuel combustion are approximately four times and twice of these for oxy-fuel combustion. The decrease of L/G ratio reduces the normalized total capital and annual costs for both air and oxy-fuel combustion and more significant for air-fuel combustion. Therefore, the L/G ratio is preferably obtained by the wet bulb temperature. This paper sheds light on the rigorous design method and the optimization of design parameters for direct contact condenser.

Current activities for commercialization of oxyfuel power plant

While the efforts to control global warming are being strengthened all over the world, expectations for CO2 Capture, Utilization and Storage (CCUS) technology for coal fired power plants are increasing. IHI has been working on development of oxyfuel-combustion technology since 1989 with the aim of easily capturing and storage CO2 emitted from coal fired power plants. For the demonstration of oxyfuel-combustion technology, IHI participated in the Callide Oxyfuel Project with collaboration between Australian and Japanese under the financial support of Australian, Queensland state and Japanese governments. In the project, the oxyfuel-combustion process was applied to the existing coal power plant in Queensland, Australia, and demonstration was carried out and successfully completed without any significant technical barrier to commercialization in March, 2015. In Oxyfuel-combustion, the coal-fired boiler is operated with an inlet O2 content of 27 vol% in order to achieve the same furnace heat transfer as in conventional air-firing. The first outcome of oxyfuel-combustion is a significant reduction in NOx production, typically 60% reduction, measured in mgNOx/MJcoal. The second outcome of oxyfuel-combustion is a reduction in the actual volumetric flow of flue gas, typically a 60% to 70% reduction in gas flow measured as m3/h, and a proportionate increase in the CO2 content of the flue gas from ~ 15 vol% (dry) in airfiring mode to 70 to 80 vol% (dry) in Oxyfuel mode. In addition, CO2 product from the Callide Oxyfuel Project was injected into the Paaratte formation in the Otway Basin (Victoria) to investigate the geochemical effects of CO2 (normal product) and CO2 with added impurities. The recent research and development about characteristics of roller mill and electrical precipitator using combustion test facilities for the flexibility of plant design and the current commercialization activities of oxyfuel power plant are introduced in this paper.

The geochemical effects of O2 and SO2 as CO2 impurities on fluid-rock reactions in a CO2 storage reservoir

Costs for CO2 capture could be reduced if CO2 gas impurities can be co-injected and do not adversely affect the long-term CO2 containment. This project, as a part of the Callide Oxyfuel Project, investigates the geochemical impacts of the CO2 impurities SO2 and O2 on mineral-fluid reactions in a siliciclastic reservoir. In a single-well push-pull field experiment CO2-saturated water with and without impurities was injected into the reservoir. The injection water was allowed to interact with minerals in the reservoir for three weeks, during which water was back-produced and sampled on three occasions. Four soluble tracers were added to the injection water to estimate the proportions of injection and formation water in the back-produced water. Redox state, speciation and reaction pathway modelling are used as part of the data interpretation. Once injected, SO2 (67ppm vol/vol, initially as a dissolved impurity in CO2) was dissolved and oxidised, leading to sulphate formation. The alkalinity of the injection water counteracted any substantial decrease in pH, which would otherwise occur due to sulphuric acid formation, thus inhibiting additional mineral dissolution. After being injected, O2 (6150ppm vol/vol, dissolved impurity in CO2) led to immediate oxidative dissolution of pyrite. Consequently, the SO42− concentration increased rapidly and dissolved iron is predicted to precipitate as hematite. Overall, the impact of CO2 impurities was minimal.

Reactive transport simulation to assess geochemical impact of impurities on CO2 injection into siliciclastic reservoir at the Otway site, Australia

It is generally recognized that the removal of impurities from CO2 obtained from coal-fired flue gas carbon capture systems can significantly increase the cost of Carbon Capture and Storage (CCS). During the period from September to December 2014, the CO2CRC in collaboration with Callide Oxyfuel Services Pty Ltd conducted a series of CO2 injection tests into the Paaratte formation (Otway Basin, Victoria, Australia) utilizing product CO2 (near food grade) and product CO2 with added impurities (nominal SO2: 67ppmv, O2: 6150ppmv and NOx: 9ppmv) from the Callide Oxyfuel Project. The purpose of the injection testing was to assess the geochemical effect of the CO2 injected with water on the siliciclastic reservoir. The geochemical test, which was designed and conducted by CO2CRC, consists of water production, Test 1 (injection of CO2-saturated water without impurities), and Test 2 (injection of CO2-saturated water with impurities). In this paper, 2-D radial reactive transport simulations of injection tests were carried out using TOUGHREACT, including: (1) simulation of the pre-injection period from Otway Stage 2B Test in 2011 to the start of the geochemical test; (2) simulations of the pure CO2 and the impure CO2 cases; (3) long-term simulation of the impure CO2 case; and (4) simulations of injection of CO2-saturated water with various impurity concentrations. The numerical model was able to reproduce the observed geochemical changes during the geochemical test. The results indicate that there were negligible differences between the pure CO2 and the impure CO2 cases for both changes in water chemistry and mineralogy, if SO2 or O2 was less than 1000ppmv. Based on this evaluation of both field test results and simulations, by extrapolation it is concluded that co-injection of impurity gases (up to 1000ppmv SO2 and 1000ppmv O2) with CO2 would have insignificant impacts on the reservoir at the Otway site. In the long-term simulation, the distribution area of residual gas in the reservoir was small and the pH of the formation water was near neutral after 1000 years. Moreover, it was predicted that the water disturbed by CO2 impurities would come close to the initial geochemical conditions in the long-term, and that it is highly probable that the long-term impact after 1000 years would become much less compared to the short-term impact in the test period. The method and model presented here was suitable for the Otway site test and would be applicable to other CO2 storage sites with similar conditions.

CO2 quality control in Oxy-fuel technology for CCS: SO2 removal by the caustic scrubber in Callide Oxy-fuel Project

Flue gas from Oxy-fuel combustion is enriched with CO2 and SO2. SO2 has significant impacts throughout the system. This paper primarily focuses on the operation characteristics of caustic scrubber for the removal of SO2 in Callide Oxy-fuel Project.Both gas and liquid sampling and analysis were carried out for the caustic scrubber which comprises two spray columns, the initial Quencher followed by the low pressure (LP) scrubber. Dynamic changes of gas and liquid species in two scrubbers have been obtained and several conclusions can be drawn.From gas analysis, it can be concluded that the Quencher had high capture efficiencies for SO2 (97%) and NO2 (77%), and low capture efficiencies for NO (32%). The Quencher captured most of the SO2 and NO2; the LP scrubber captured a limited amount of SO2 (1%) and NO2 (4%). Therefore, the LP scrubber is not a necessary component for capturing SO2.Liquid analysis gave consistent results with gas analysis in that the Quencher (0.011–0.037M) contained a 100 times higher concentration of Total S than that (0.0001–0.0006M) in the LP scrubber. The Total S existed in the form of S(IV) and S(VI) in the Quencher, and only in the form of S(VI) in the LP scrubber. The S(VI) ratio of 11% in the Quencher agreed with the reported 2–15% oxidation.SO2 concentration in gas phase can be correlated well with Total S in liquid, but not the effective ratio of Na+. Mass balance between gas and liquid Total S can be achieved.The long term storage of liquid samples is accompanied by pH changes and desorption of CO2 with exposure to the atmosphere. The final pH depends on the presence of HCO3−. In the presence of HCO3− in liquids, the final pH is around 8; in the absence of HCO3−, the final pH is around 4. The increase in pH to 8 is explained by desorption of CO2. The amount of CO2 desorbed is around 0.0614% of the amount of CO2 in the CPU.

Mercury and SO3 measurements on the fabric filter at the Callide Oxy-fuel Project during air and oxy-fuel firing transitions

The Callide Oxy-fuel Project is the world's largest operating oxy-fuel plant. This work details an experimental test campaign at the Callide Oxy-fuel Project monitoring mercury and SO3 levels exiting the fabric filter during transitions between air and oxy firing conditions. The measurements were taken using two custom built probes; the first allowing combined collection of SO3 and mercury over short time intervals; the second allowing on-line measurements of Hgtotal and Hg0 with SOx removal. Total mercury emissions in oxy-firing measured a maximum of 6–7μg/m3 of which 89% was in oxidised form (Hg2+). The use of low NOx burners had an overriding influence on the mercury measurements reducing the total mercury levels to 0.13 and 0.15μg/m3 (air, oxy respectively) with no Hg2+ being measured. The SO3 concentrations were also lower than expected, estimated at ∼0.5–0.8ppm (based on a practical estimate of 1% conversion of SO2). Overall mercury capture in either operating mode was estimated at 92–93% for the existing burners and 98–99% with the low NOx burners used (being 2 of the 4 burners operating). Total SOx captured from the flue gas was 16% in oxy-mode and 19% in air firing. These findings suggest that operational conditions have a primary impact on capture of Hg and SOx during transitions with a secondary impact of firing mode (i.e. air or oxy).

Operational results of oxyfuel power plant (Callide Oxyfuel Project)

In 2013, CO2 levels surpassed 400 ppm for the first time in recorded history. So, we are facing global warming due to the increase levels of atmospheric carbon dioxide (CO2). As a method of reducing CO2 emissions from the thermal power plants, there are carbon dioxide capture and storage (CCS) technologies. Oxyfuel combustion is one of the CO2 Capture technologies and IHI have developed it since 1989. Then, Callide Oxyfuel Project commenced to apply oxyfiring technology in an existing coal fired power plant and to demonstrate an oxyfuel power plant in March, 2008. Demonstration began in 2012 after existing boiler was retrofitted. During the demonstration for approximately three years, many tests were conducted and many data were collected for commercial use. As a result, we confirmed characteristics of oxyfiring such as total heat absorption, combustion characteristics, emissions of NOx, SOx, carbon-in-ash, operational flexibility from 15MWe (50%L) to 30MWe (100%L) and behavior of injected CO2 at the injection site. Total heat absorption of the boiler under oxyfiring was 2 to 3MW higher because of decreasing heat loss in flue gas and rising temperature of boiler feed water by a flue gas cooler. NO was decomposed in the furnace under oxyfiring because flue gas was recirculated. On the other hand, reaction between SO2 and absorbent such as Ca, Mg in ash was not so active regardless of high concentrated SO2 under oxyfiring. Carbon-in-ash was almost 40%~70% in oxyfirng compared with in airfiring because of longer residence time in the furnace. Operational flexibility is important to control oxyfiring operation and it was confirmed that oxyfiring can be operated as well as airfiring. In this paper, operational results are presented in Callide Oxyfuel Project.

Field measurements of NOx and mercury from oxy-fuel compression condensates at the Callide Oxyfuel Project

The Callide Oxyfuel Project (COP) is the world's largest operating oxy-fuel plant and has successfully demonstrated the retrofitting capability for oxy-fuel to capture CO2. The compression of the raw flue gas at the COP has also demonstrated that NOx and Hg can also be removed as part of the liquid condensate. This work presents field tests conducted on the condensates to determine the stability of captured NOx and Hg species when depressurised. These tests involved sampling liquid condensate directly into a customised aeration vessel and measuring the evolved gases over an 8–12h period. The low-pressure condensate (∼4bar) showed that 3–18% of captured NOx species and 0.5–1.2% of the Hg were volatile, while the high-pressure condensate (24bar) re-emitted 2–68% of captured NOx and 0.05–12.5% of the captured Hg. These tests showed that volatile Hg was related to volatile NOx and that this volatility of condensates changed with time as the compression plant operated from start-up. Equilibrium calculations of HNO2 in the gas and liquid phases supported the volatility measurements, suggesting that the rate of oxidation of HNO2 to HNO3 in the condensed phase is slow. Overall, the conditions which favoured NOx stability in the condensates, namely longer residence and higher pressure also favoured Hg stability. This work has shown that emissions from an oxy-fuel compression plant must include those emanating from depressurised condensates and suggest that the re-emitted species may not the same as in typical combustion flue gas, but the result of higher-pressure conversion.

Oxyfuel derived CO2 compression experiments with NOx, SOx and mercury removal—Experiments involving compression of slip-streams from the Callide Oxyfuel Project (COP)

Oxyfuel combustion is a CO2 capture technology which is approaching commercial demonstration. Of practical interest is the use of the compression circuit to allow low-cost cleaning options for various flue gas impurities. This work has focussed on three species – NOx SOx and Hg – and their removal during compression of “real” oxyfuel flue gas sampled as a slip stream from the demonstration Callide Oxyfuel Project. The flue gas slip stream was compressed using a bench-scale piston compressor developed to allow measurements of impurity concentrations after each compression stage using adjustable pressures. Several operating configurations were investigated including variable pressures from 5 to 30bar, interstage temperature changes and flow rate. Slip streams taken before and after SOx removal allowed the impact of mixed NOx/SOx gases to also be investigated. The results from the “real” oxyfuel flue gas experiments for the three species were similar to those performed in the laboratory using synthetic flue gas and reported previously. The capture of SO2 was found at be greater at low pressures than NOx capture, with 90% removal of SO2 by a pressure of 10bar, with NOx capture extending to higher pressures. The effect of residence time during compression had the greatest influence at higher pressures (>10bar) where the kinetic rate of NO oxidation to NO2 increases less with pressure increase. Capture of NOx was increased from 55% to 75% by doubling the residence time in the compressor and could be further extended to 83% by increasing back end pressure from 24bar to 30bar. Lowering the temperature during compression produced the greatest NOx and Hg capture. Overall, the results indicate that capture of mercury during compression occurred as a consequence of high pressure, longer residence time and concentration of NO2.

ICOPE-15-1036 Operational results of oxyfuel power plant : Callide Oxyfuel Project

ICOPE-15-1036 Operational results of oxyfuel power plant : Callide Oxyfuel Project

Operation Experiences of Oxyfuel Power Plant in Callide Oxyfuel Project

Callide Oxyfuel Project is the only demonstration project for oxyfuel power plant in the world and has been promoted at Callide-A power station in Queensland, Australia. Callide-A power plant, which is a retrofit of an existing power plant with a capacity of 30MWe, is now the largest operating oxyfuel power plant all over the world. Two air separation units (ASU) of 330 TPD and CO2 compression and purification unit (CPU) of 75 TPD that is about 10% capacity of total flue gas were newly installed. And the existing 30MWe boiler was modified to apply both air and oxufuel combustion. This demonstration is the key and important step for the large-scale oxyfuel power plant in the future and the various tests regarding the oxyfuel boiler and CPU have been performed. Main objectives of this project are to demonstrate the oxyfuel operation with CO2 capture and storage using the existing power plant and to obtain the design data and operation know-how for the commercialization. Callide-A oxyfuel boiler with power generation and CO2 purification unit from oxyfuel flue gas have been demonstrated and have given us the various operation results with some test parameters in the Project. Regarding the oxyfuel boiler, the heat absorbed rate, combustion characteristics, trace elements behaviour and plant operation flexibility have been confirmed at the different coal type and the different boiler inlet O2 concentration with the various power generation output through the commissioning and demonstration stage. In this paper, the operational experiences of the oxyfuel power plant in Callide Oxyfuel Project are introduced.

Toward the realization of CO2 zero-emission coal fired power plant using the oxyfuel technology ～ Progress of the Callide Oxyfuel Project ～

Toward the realization of CO₂ zero-emission coal fired power plant using the oxyfuel technology ～ Progress of the Callide Oxyfuel Project ～

Oxyfuel Combustion as CO2 Capture Technology Advancing for Practical use - callide Oxyfuel Project -

CCS, CO2 capture and storage, is one of the ways to keep CO2 concentration in atmosphere to be under certain value in order to mitigate the global warming and expectation for its practical use soars all over the world. IHI have developed the oxyfuel combustion technology as CO2 capture technology since 1989 and we have been going forward the Callide oxyfuel Project in Australia since 2008. In this paper, we introduce the progress of the Callide oxyfuel Project and the action toward the practical use of the oxyfuel combustion technology.

Realization of oxyfuel combustion for near zero emission power generation

Oxyfuel combustion is one of the promising carbon capture and storage (CCS) technologies for coal-fired boilers. In oxyfuel combustion, combustion gas is oxygen and recirculating flue gas (FGR) and main component of combustion gas is O2, CO2 and H2O rather than O2, N2 in air combustion. Fundamental researches showed that flame temperature and flame propagation velocity of pulverized cloud in oxyfuel combustion are lower than that in air with the same O2 concentration due to higher heat capacity of CO2. IHI pilot combustion test showed that stable burner combustion was obtained over 30% O2 in secondary combustion gas and the same furnace heat transfer as that of air firing at 27% O2 in overall combustion gas. Compared to emissions in air combustion, NOx emission per unit combustion energy decreased to 1/3 due to reducing NOx in the FGR, and SOx emission was 30% lower. However SOx concentration in the furnace for the oxyfuel mode was three to four times greater than for the air mode due to lower flow rate of exhaust gas. The higher SO3 concentration results that the sulphuric acid dew point increases 15–20°C compared to the air combustion. These results confirmed the oxyfuel pulverized coal combustion is reliable and promising technology for coal firing power plant for CCS.In 2008, based on R&D and a feasibility study of commercial plants, the Callide Oxyfuel Project was started in order to demonstrate entire oxyfuel CCS power plant system for the first time in the world. The general scope and progress of the project are introduced here. Finally, challenges for present and next generation oxyfuel combustion power plant technologies are addressed.

Coal power generation with in-situ CO2 capture–HyPr-RING method—Effect of ash separation on plant efficiency

Abstract In-situ CO 2 capture in coal utilization captures CO 2 during coal combustion or gasification such as Oxygen fuel combustion or HyPr-RING. coal gasification processes. Regarding Oxufuel combustion, Callide Oxyfuel Project has been being conducted as the world first project to apply the technology to an existing power plant, Callide A Power Station #4 unit (30MWe) with injection of captured CO 2 into the underground. This is a Japan-Australia collaboration project and JCOAL participates in it as a supporting collaborator. JCOAL also proposed a novel coal gasification method-,HyPr-RING (Hydrogen Production by Reaction-Integrated Novel Gasification). HyPr-RING method utilizes a chemical looping with the calcium cycle, in which CaO (or Ca(OH) 2 ) captures CO 2 during coal gasification completely to form CaCO 3 and release heat for gasification to produce near pure hydrogen in one gasifier. This paper introduces the current developing status of the HyPr-RING method, mainly including the experimental examination of the transition of sorbent particle size distribution, ash and sulfur concentration of materials at several locations of gasification and calcination system for the HyPr-RING process. And the plant cold gas efficiency which should be affected by ash separation was also analyzed. As the results, it was found that coal ash and sulfur concentrated highly in the process of calcination after cyclone. If it is possible, separate and remove ash and sulfur by applying devices like filter or/and cyclone separator, the plant coal gas efficiency may raise 2 points than that in the previous study in which a part of recycled sorbent was rejected without separation. One method for reducing CO 2 , the green house gas emissions is to capture CO 2 before it releases into the atmosphere and then sequestrate it. Active lime (main component, CaO) can be used to capture CO 2 in the exhaust gas or in the reactor from fossil fuels utilization effectively. That is calcium oxide (CaO) absorbs CO 2 to yield calcium carbonate (CaCO 3 ) (Eq.(1)), then the CaCO3 is thermally decomposed to CaO again and release nearly pure CO 2 (Eq. (2)) for sequestration. To obtain a nearly pure CO 2 stream from CaCO 3 decomposition, the heat for decomposing CaCO 3 can be supplied by combusting fossil fuels, such as coal and natural gas, in a calciner with oxygen fuel combustion. The oxygen diluted by CO 2 (CO 2 cycle) or H 2 O (steam cycle), in order to obtain near pure CO 2 stream from CaCO 3 decomposition. In our previous studies 4−6 , it was clarified that calcinations of limestone (main component, CaCO 3 ) in a fluidized bed calciner can be performed in CO 2 cycle atmosphere when the bed temperature was raised above 1293 K, whereas with 60% steam cycle in atmosphere, limestone can be decomposed at comparatively lower temperature, such as 1173 K. The decomposition conversions of the limestone were about 95% and 98%, in CO 2 cycle and in steam cycle atmospheres, respectively. Reducing the calcinations temperature of limestone was helpful to produce more than 30% active CaO as shown in previous study 4−6 . In this study, the energy of CaCO 3 calcination process by H 2 O (steam) cycle was analyzed and compared with CaCO 3 calcination process by CO 2 cycle. For process calculations, the mass and energy flows were calculated iteratively, based on the input and output balances, until err [(input-output)/input] was 2 O (steam) cycle calcination had calcination energy more about 3.6% than CO 2 cycle due to water evaporation latent heat loss, however, the calcination energy per active CaO was lowest for H 2 O (steam) cycle.

B110 STUDY RESULTS OF OXYFUEL COMBUSTION ON CALLIDE OXYFUEL PROJECT : ACTIVITIES TOWARD THE COMMERCIALIZATION OF OXYFUEL COMBUSTION SYSTEM(Combustion-3)

Oxyfuel combustion is expected to be one of the promising systems on CO_2 capture from pulverized-coal fired power plant, and enable the CO_2 to be captured in a more cost-effective manner compared to other CO_2 capture process from the power plant. The demonstration project (Callide Oxyfuel Project) on this field is now under way for applying oxyfuel combustion to an existing plant that is the power generation system in Callide-A power plant No.4 unit with a capacity of 30M We in Australia. One of main objectives of this project is to capture CO_2 from an actual power plant for CO_2 storage. At present, the studies toward the commercialization plant through this demonstration project on this area are implemented. In this paper, the activities for the approach on the commercialization for the oxyfuel combustion are mainly introduced and the current situation of Callide Oxyfuel Project is also outlined.

Carbon capture and storage—deelopments in Australia

Legal and non-legal developments in the carbon capture and storage (CCS) arena continue to gain momentum in Australia. On 22 November 2008 the Offshore Petroleum Amendment (Greenhouse Gas Storage) Act 2008 (Cth) (GGS Amendments) came into force. The GGS Amendments follow the amendment in February 2007 of the Convention on the Prevention of Marine Pollution by Dumping of Wastes and Other Matter 1972 and 1996 Protocol Thereto (London Protocol) which allows the storage of carbon dioxide under the seabed. The GGS Amendments amend the Offshore Petroleum Act 2006 (Cth) (OPA), which has now been renamed the Offshore Petroleum and Greenhouse Gas Storage Act 2006 (Cth) (Act), to establish a system of offshore titles that authorises the transportation, injection and storage of greenhouse gas (GHG) substances in geological formations under the seabed and manage the inevitable interaction with the offshore petroleum industry. In addition, the States of Queensland and Victoria have now enacted onshore CCS legislation. In September 2008, the Federal Government announced $100 million in funding for an Australian Global Carbon Capture and Storage Institute (AGCCSI), which will be an international hub for co-ordinating public and private sector funding of CCS research projects and will provide international policy and management oversight. The AGCCSI was formally launched on 16 April 2009. The goal of the AGCCSI is to deliver at least 20 commercial scale CCS plants around the world by 2020. There are numerous examples in Australia and internationally of CCS pilot projects underway with the goal of deploying CCS on a commercial scale. The Callide Oxyfuel Project in Central Queensland that began construction recently will retrofit an existing coal fired power station with a CCS facility, with plans for the oxyfuel boiler to be operational in the Callide A power plant by 2011.