Publications
192 results found
Korre A, Durucan S, Shi J, 2018, CO2 injection induced microseismicity around well KB-502 at in Salah and insights from reservoir history matching
© 2018 Society of Petroleum Engineers. All rights reserved. In the In Salah CO2 storage project in central Algeria, three long-reach horizontal injection wells (KB-501, KB-502 and KB-503) were used to inject the CO2, removed from the gas production stream, into the down-dip aquifer leg of the Carboniferous C10.2 gas reservoir. Between 2004 and 2011, over 3.8 million tonnes of CO2 have been stored in the c. 1.9km deep Carboniferous sandstone unit (C10.2) at the Krechba field. In a previous study by the authors, history matching of the (estimated) injection bottomhole pressure was carried out for KB-502 over the first injection period between April 2005 and July 2007. In the current work, history matching has been extended to the end of injection period in 2011. The obtained results are correlated with the reported induced microseismicity. The reservoir simulation results obtained have provided useful information which allows us to better interpret the recorded microseimicity induced by CO2 injection into a well.
Elahi N, Shah N, Korre A, et al., 2017, Multi-stage Stochastic Optimisation of a CO 2 Transport and Geological Storage in the UK, 13th International Conference on Greenhouse Gas Control Technologies, Publisher: Elsevier, Pages: 6514-6525, ISSN: 1876-6102
Deterministic whole system multi-stage optimisation frameworks provide valuable insights into the cost effective design and operation of CO 2 capture and storage (CCS) systems. However commercial deployment of CCS faces significant technical and economic uncertainties, which necessitate flexibility in system development strategies as well as coordination of all aspects of a CCS system across both time and space. This paper builds on a whole system dynamic CCS optimisation tool developed at Imperial College and presents a mixed integer linear programming approach for multi-stage multi-scenario stochastic optimisation of a spatially explicit integrated CCS system under uncertainty. The model provides great advantages through flexible strategies for all potential system state changes at every stage and early one-fit-for-all investment solutions that minimise financial loss and offer operational flexibility. The model is showcased through a case study set in the UK between 2015-2050 focusing on the techno-economic performance of the CCS value chain and considering uncertainties in the financial market and the storage capacity within a portfolio of Southern North Sea saline aquifer and depleted oil and gas fields.
Borda ES, Govindan R, Elahi N, et al., 2017, The development of a dynamic CO2 injection strategy for the depleted forties and Nelson oilfields using regression-based multi-objective programming, 13th International Conference on Greenhouse Gas Control Technologies, GHGT-13, Publisher: Elsevier, Pages: 3335-3342, ISSN: 1876-6102
An optimisation strategy to maximise the CO 2 storage capacity utilisation of a deep saline aquifer is presented in this paper. This was achieved by a scenario of simultaneous CO 2 injection and brine production within the Forties sandstone. The optimisation was performed using the SIMPLEX and Generalised Reduced Gradient algorithms and the assistance of surrogate modelling techniques. Results have shown that, by using five brine production wells producing up to 2.2 Mtonnes/year, the CO 2 storage capacity of the reservoir can be increased by 125% compared to when no brine production is used. It is also observed that pressure constraints are the main limiting factors controlling further CO 2 injection.
Farooqui NM, Liu Q, Maroto-Valer MM, et al., 2017, Understanding CO2-brine-wellbore cement-rock interactions for CO2 storage, 13th International Conference on Greenhouse Gas Control Technologies, GHGT-13, Publisher: Elsevier, Pages: 5206-5211, ISSN: 1876-6102
There is a need to improve our understanding of wellbore integrity by conducting investigations into the flow, geomechanical and geochemical properties of cement and reservoir rocks under conditions representative of subsurface temperatures and pressures at the wellbore. A series of composite cement-host rock core samples were prepared and subjected to baseline flow and mechanical properties testing to determine porosity, permeability, strength and elastic properties. The hydrothermal experiments conducted have shown that variations in the solution profiles of Ca, Mg, and Fe were due to the dissolution of CO 2 for all sets of samples. The dissolution of muscovite and montmorillonite from the composite core samples resulted in increasing concentrations of Na, K and S.
Govindan R, Si G, Korre A, et al., 2017, The assessment of CO2 backproduction as a technique for potential leakage remediation at the Ketzin pilot site in Germany, 13th International Conference on Greenhouse Gas Control Technologies, GHGT-13, Publisher: Elsevier, Pages: 4154-4163, ISSN: 1876-6102
As part of the license application, CO 2 storage projects must develop a corrective measures plan, which describes the steps that can be taken when the plume in the subsurface behaves in an unpredicted and undesired manner. One possible technique in the toolbox of corrective measures is CO 2 backproduction, which has the potential for both pressure management and plume steering in the reservoir. The feasibility of this technique has recently been tested during a field experiment at the Ketzin pilot site in Germany. In this paper, the authors describe an assessment of backproduction using coupled flow and geomechanical modelling. In line with the field observations, the simulation results obtained also suggest that it is a stable and promising remediation technique.
Mosleh MH, Durucan S, Syed A, et al., 2017, Development and characterisation of a smart cement for CO2 leakage remediation at wellbores, 13th International Conference on Greenhouse Gas Control Technologies, GHGT-13, Publisher: Elsevier, Pages: 4147-4153, ISSN: 1876-6102
This paper presents the results of the experimental investigations into the effectiveness of latex based "smart cement" in remediating wellbore related CO 2 leakage. Porosity, N 2 and CO 2 permeabilities, mechanical and elastic properties of the smart cement mixtures developed were determined using core samples. The effectiveness of the smart cement in reducing the cement permeability was assessed through a series of core flooding experiments and by comparing the results with those of Class G Portland cement. A full scale laboratory wellbore test rig was used to investigate the interactions between CO 2 and latex-cement at realistic wellbore conditions. Permeability response of the "smart cement" and microannulus were measured with N 2 and CO 2 at flow rates representative of likely CO 2 leakage rates at storage sites and the results are reported.
Nie Z, Korre A, Elahi N, et al., 2017, Real options analysis of CO2 transport and storage in the UK continental shelf under geological and market uncertainties and the viability of subsidies for market development, 13th International Conference on Greenhouse Gas Control Technologies, GHGT-13, Publisher: Elsevier, Pages: 6612-6622, ISSN: 1876-6102
Carbon capture and storage (CCS) stakeholders focusing on transport and storage aspects need to consider a wide range of risks and uncertainties, categorised as market, regulatory, geological and technical risks and uncertainties. This paper presents a real options based investment decision making framework which has been designed to consider these, optimise flexibility at network infrastructure level, and appraise the viability of subsidies for market development, so that investors or regulators can confidently and quantitatively evaluate incentives that can support CCS deployment at large scale. The paper describes the models developed for this purpose and demonstrates the application of the modelling framework for a realistically designed UK North Sea CO 2 storage network.
Mosleh MH, Govindan R, Shi JQ, et al., 2017, The use of polymer-gel remediation for CO2 leakage through faults and fractures in the caprock, 13th International Conference on Greenhouse Gas Control Technologies, GHGT-13, Publisher: Elseiver, Pages: 4164-4171, ISSN: 1876-6102
This paper presents the results of numerical modelling carried out to investigate the application of polymer-gel barriers for remediation of CO 2 leakage through faults or fracture zones in the caprock. The chemical flooding reservoir simulator UTCHEM was used for polymer-gel injections and assessment of the area of influence. Sensitivity analyses were performed to account for the effect of other crosslinkers other than chromium on the kinetics of gelation process. Subsequently, a numerical model of a saline aquifer was setup to carry out the reservoir simulations of CO 2 injection into a storage reservoir using Schlumberger's Eclipse 300 (E300) software. The amount of CO 2 leaked into a shallower formation through a sub-seismic fault was monitored and CO 2 injection was temporarily stopped for leakage remediation. The injection of polymer-gel solution was simulated and the area of influence and volume of polymer-gel needed were estimated for a number of scenarios. CO 2 injection was then resumed and the efficiency of the polymer-gel treatment was assessed for each scenario.
Govindan R, Elahi N, Korre A, et al., 2017, A statistical learning approach to model the uncertainties in reservoir quality for the assessment of CO2 storage performance in the lower Permian Rotliegend Group in the Mid North Sea High Area, 13th International Conference on Greenhouse Gas Control Technologies, GHGT-13, Publisher: Elsevier, Pages: 4637-4642, ISSN: 1876-6102
It has been identified that the Rotliegend sandstone reservoir in the Mid North Sea High region, in the UK Quadrants 27-29, has a large-scale CO 2 storage potential of national importance. In this paper, the authors develop a reservoir model using extensive datasets available from seismic interpretations and core analysis. An advanced statistical learning approach was applied to characterise the uncertainties in the spatial distribution of reservoir quality. The model was used to assess the CO 2 injection performance and the preliminary results obtained thusfar indicate promise in the available storage capacities.
Cao W, Shi JQ, Durucan S, et al., 2017, Modelling the influence of heterogeneity on microseismic characteristics in longwall coal mining, 51st US Rock Mechanics / Geomechanics Symposium, Publisher: American Rock Mechanics Association, Pages: 680-689
Mining-induced microseismicity has been extensively used to evaluate the potential for rock bursts and coal and gas outbursts in underground coal mines. In a research project completed a few years ago, it was observed that characteristics of microseismicity around a longwall working panel were fairly consistent over the monitoring period until a heterogeneous zone with a relatively high coal strength was reached. The current research presented in this paper aims at achieving a better understanding of the effect of heterogeneity on microseismic activity in longwall coal mining. A microseismicity modelling approach which combines deterministic stress and failure analysis together with a stochastic fracture slip evaluation was used to simulate the evolution of microseismicity induced by the progressive face advance passing through a heterogeneous zone. The heterogeneous zone was taken into account by varying the material strength of the elements within the high strength zone and the fracture attributes within this zone. Results have shown that both the high rock strength of coal lithotype and low fracture intensity within this zone contribute to the decrease in seismic event counts, and that the increase in energy released results from the combined effects of increased stress drops and slipped fracture sizes when the high strength zone is approached.
Si G, Durucan S, Shi JQ, et al., 2017, Key parameters controlling slotting operations to stimulate gas drainage performance in low permeability coal seams, Pages: 447-456
Coal mining is extending to deeper and deeper levels, facing ever increasing coal seam methane contents and much higher methane emissions at production districts. The low permeability nature of coal seams exacerbates with the stress increase at deeper levels. This growing challenge is often not addressed effectively by the current gas drainage methods applied in coal mines. In recent years, slotting via hydraulic or mechanical force along underground gas drainage boreholes, as a general solution to stimulate low permeability coal reservoirs, has attracted increasingly attention. However, the role of prevailing stress state, coal properties, and slot geometry are the critical parameters to be considered in slotting operations. There has been no systematic research on assessing these key parameters and understanding the sensitivity of individual parameters in affecting slotting performance. By quantitatively assessing a series of numerical modelling scenarios, this paper aims at identifying the key parameters controlling slotting operation, analysing the sensitivity of individual parameters, and optimising slotting operation. Internal friction angle, slot diameter and the ratio of the maximum principal stress to minimum principal stress have been identified as the top three parameters affecting slotting performance.
Shi JQ, Rubio RM, Durucan S, 2016, An improved void-resistance model for abandoned coal mine gas reservoirs, International Journal of Coal Geology, Vol: 165, Pages: 257-264, ISSN: 0166-5162
Previous studies have shown that the gas pressure behaviour of some abandoned coal mines may be described with the aid of a simple conceptual model, the so called void-resistance model. In this study, an improved void-resistance model has been developed and validated using previously collected data. Two model parameters, i.e. an apparent source/sink pressure and a time constant, which control the gas pressure behaviour during recharge and under certain gas production conditions, are defined. It has been shown that the two parameters can be determined via linear regression through analysing the historical abandoned mine gas pressure data during recharge. The void-resistance model developed has been successfully applied to analyse the historical pressure data recorded at two abandoned coal mines in Europe.
Babaei M, Govindan R, Korre A, et al., 2016, Calculation of pressure- and migration-constrained dynamic CO2 storage capacity of the North Sea Forties and Nelson dome structures, International Journal of Greenhouse Gas Control, Vol: 53, Pages: 127-140, ISSN: 1750-5836
This paper presents a numerical simulation study of CO2 injection into the Forties and Nelson dome structures in the North Sea. The study assumes that these structures are fully depleted of their remaining hydrocarbon and brine has replaced their pore space, and therefore the structures can be treated as saline aquifers. Under this assumption, the objective is to calculate the dynamic CO2 storage capacity of the Forties and Nelson structures and design an injection scenario to enhance storage utilisation. In doing so, first, a detailed geological model of the dome structures and their surrounding aquifer is developed to represent the lithological facies associations and attribute them with petrophysical properties. The geological model is calibrated in terms of the surrounding aquifer support using the hydrocarbon production data. The dynamic storage capacity is subsequently estimated by numerical simulation of the two-phase (brine and CO2) process. Key performance indicators (KPIs), such as the pressure build-up and regional mass fraction of CO2, are used to constrain the injection scenarios that consequently result in the best capacity utilisation of the storage structures. In our model of fully brine saturated dome structures, based on specific constraints, namely <0.1% of the total gaseous CO2 outside the dome into an upper pressure unit and 66% of the initial hydrostatic pressure as the allowable increase in the bottom-hole pressure, we obtained a dynamic capacity of 121 million tonnes for the Forties structure and 24 million tonnes for the Nelson structure. These values are subject to change when a three phase model of residual oil, gas and water is considered in simulations.
Babaei M, Pan I, Korre A, et al., 2016, CO2 storage well rate optimisation in the Forties sandstone of the Forties and Nelson reservoirs using evolutionary algorithms and upscaled geological models, International Journal of Greenhouse Gas Control, Vol: 50, Pages: 1-13, ISSN: 1750-5836
Optimisation is particularly important in the case of CO2 storage in saline aquifers, where there are various operational objectives to be achieved. The storage operation design process must also take various uncertainties into account, which result in adding computational overheads to the optimisation calculations. To circumvent this problem upscaled models with which computations are orders of magnitude less time-consuming can be used. Nevertheless, a grid resolution, which does not compromise the accuracy, reliability and robustness of the optimisation in an upscaled model must be carefully determined. In this study, a 3D geological model based on the Forties and Nelson hydrocarbon fields and the adjacent saline aquifer, is built to examine the use of coarse grid resolutions to design an optimal CO2 storage solution. The optimisation problem is to find optimal allocation of total CO2 injection rate between existing wells. A simulation template of an area encompassing proximal-type reservoirs of the Forties-Montrose High is considered. The detailed geological model construction leads to computationally intensive simulations for CO2 storage design, so that upscaling is rendered unavoidable. Therefore, an optimal grid resolution that successfully trades accuracy against computational run-time is sought after through a thorough analysis of the optimisation results for different resolution grids. The analysis is based on a back-substitution of the optimisation solutions obtained from coarse-scale models into the fine-scale model, and comparison between these back-substitution models and direct use of fine-scale model to conduct optimisation.
Korre A, Durucan S, Pan I, 2016, A systems based approach for financial risk modelling and optimisation of the mineral processing and metal production industry, Computers and Chemical Engineering, Vol: 89, Pages: 84-105, ISSN: 0098-1354
Large scale engineering process systems are subject to a variety of risks which affect the productivity and profitability of the industry in the long run. This paper outlines the short comings of the current methods of risk quantification and proposes a systems engineering framework to overcome these issues. The functionality of the developed model is illustrated for the case of mineral processing and metal production industries using a copper ore processing and refined metal production case study. The methodology provides a quantitative assessment of the risk factors and allows the opportunity to minimise financial losses, which would help investors, insurers and plant operators in these sectors to make appropriate risk hedging policies. The models developed can also be coupled with evolutionary or swarm based algorithms for optimising the systems. A numerical example is illustrated to demonstrate the validity of the proposition.
Mosleh MH, Govindan R, Shi JQ, et al., 2016, Application of polymer-gel solutions in remediating leakage in CO<inf>2</inf>storage reservoirs, 78th EAGE Conference and Exhibition
Copyright 2016, Society of Petroleum Engineers. The application of crosslinked gels has seen widespread use within the petroleum industry to divert fluid flow and remediate leakage at wells. The current study aimed at investigating the effectiveness of polymer-gel treatment in remediating a potential CO 2 leakage site in the subsurface. This paper presents a brief summary of the results of laboratory characterisation work carried out on polymer gels, which involved characterisation of several polymer-gel systems with respect to their working and gelation times and conducting core flooding experiments on reservoir rocks to characterise their permeability reduction behaviour. The chemical flooding reservoir simulator, UTCHEM, was used to simulate polymer injection and its subsequent gelation process in the saline aquifer model. Parameters such as polymer concentration, polymer to crosslinker ratio and pH, and their influence on the gelation process and the area of influence have been investigated. The results have shown that lower polymer to crosslinker ratios lead to a relatively higher gel concentration. On the other hand, higher polymer to crosslinker ratios result in a relatively higher area of influence, which is mainly due to the decreased viscosity and slower gelation rate. It was also found that, as the concentration of H + in the injection stream increases, the rate of crosslinking decreases and the lower viscosity polymer slug migrates to the far-field region of the reservoir formation.
Durucan S, Korre A, Andrianopoulos E, et al., 2016, Coupled thermo-chemical-mechanical modelling of cavity growth and farfield geomechanical assessment in underground coal gasification
Durucan S, Shi JQ, De La Torre Guzman J, et al., 2016, Reservoir geomechanics helps improve CO <inf>2</inf> storage performance and risk assessment, Pages: 47-55
A coupled flow-geomechanical modelling study has been carried out in an effort to match the flowing bottomhole pressures and InSAR surface uplift time series at the three injection wells over the seven years CO 2 injection period at In Salah. The surface deformation data covers the entire period of monitoring from July 2003 to January 2012. It is believed that a structural feature controls the dynamic pressure and geomechanical behaviour at both injection wells KB-502 and KB-503, and that CO 2 injection has caused tensile opening of pre-existing fractures/faults in the area. This insight was incorporated by introducing a fracture/fault zone with a dynamic transmissibility into the coupled flow-geomechanical model. Using forward coupled flow-geomechancial modelling, both the injection pressure behaviour and the geomechanical response at the ground surface have been largely reproduced. Research findings helped assess the overall performance of the site and potential for the migration of CO 2 within the storage complex.
Durucan S, Shi JQ, de La Torre Guzman J, et al., 2016, Reservoir geomechanics helps improve CO<inf>2</inf>storage performance and risk assessment, EUROCK2016, Pages: 47-56
© 2016 Taylor & Francis Group, London. A coupled flow-geomechanical modelling study has been carried out in an effort to match the flowing bottomhole pressures and InSAR surface uplift time series at the three injection wells over the seven years CO 2 injection period at In Salah. The surface deformation data covers the entire period of monitoring from July 2003 to January 2012. It is believed that a structural feature controls the dynamic pressure and geomechanical behaviour at both injection wells KB-502 and KB-503, and that CO 2 injection has caused tensile opening of pre-existing fractures/faults in the area. This insight was incorporated by introducing a fracture/fault zone with a dynamic transmissibility into the coupled flow-geomechanical model. Using forward coupled flowgeomechancial modelling, both the injection pressure behaviour and the geomechanical response at the ground surface have been largely reproduced. Research findings helped assess the overall performance of the site and potential for the migration of CO 2 within the storage complex.
Mosleh MH, Govindan R, Shi JQ, et al., 2016, Application of polymer-gel solutions in remediating leakage in CO<inf>2</inf>storage reservoirs, 78th EAGE Conference and Exhibition
The application of crosslinked gels has seen widespread use within the petroleum industry to divert fluid flow and remediate leakage at wells. The current study aimed at investigating the effectiveness of polymer-gel treatment in remediating a potential CO 2 leakage site in the subsurface. This paper presents a brief summary of the results of laboratory characterisation work carried out on polymer gels, which involved characterisation of several polymer-gel systems with respect to their working and gelation times and conducting core flooding experiments on reservoir rocks to characterise their permeability reduction behaviour. The chemical flooding reservoir simulator, UTCHEM, was used to simulate polymer injection and its subsequent gelation process in the saline aquifer model. Parameters such as polymer concentration, polymer to crosslinker ratio and pH, and their influence on the gelation process and the area of influence have been investigated. The results have shown that lower polymer to crosslinker ratios lead to a relatively higher gel concentration. On the other hand, higher polymer to crosslinker ratios result in a relatively higher area of influence, which is mainly due to the decreased viscosity and slower gelation rate. It was also found that, as the concentration of H + in the injection stream increases, the rate of crosslinking decreases and the lower viscosity polymer slug migrates to the far-field region of the reservoir formation.
Durucan S, Korre A, Shi J-Q, et al., 2016, The Use of Polymer-gel Solutions for CO2 Flow Diversion and Mobility Control within Storage Sites, Energy Procedia, Vol: 86, Pages: 450-459, ISSN: 1876-6102
This paper presents a study on the use of polymer-gel technology as an option to remediate non-conformal flow behaviour of CO2 within the storage reservoir. Several polymer-gels with crosslinkers were tested. The rheology, gelation and working times of these polymer-gels at various concentrations were characterised under different temperatures representative of CO2 storage reservoirs. Laboratory core flooding experiments were then carried out on high permeability core samples to test the suitability of polymer-gel solution for flow through and containment of CO2 in porous media. The core samples saturated with brine were subjected to polymer-gel injection. Core sample permeability for CO2 was then measured and the change in CO2 permeability of the sample before and after polymer-gel injection was noted. Reservoir simulations for different scenarios of flow diversion were carried out using the permeability reduction results from the laboratory work on a realistic reservoir model with faults and high permeability channel structures.
Andrianopoulos E, Korre A, Durucan S, et al., 2016, Coupled Thermo-Mechanical-Chemical modelling of underground coal gasification, Editors: Kravanja, Bogataj, Publisher: ELSEVIER SCIENCE BV, Pages: 1069-1074
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Shi J-Q, Durucan S, 2015, Near-exponential relationship between effective stress and permeability of porous rocks revealed in Gangi's phenomenological models and application to gas shales, International Journal of Coal Geology, Vol: 154-155, Pages: 111-122, ISSN: 1872-7840
A number of theoretical models, as well as empirical equations obtained by fitting specific experimental data, have been developed to describe the relationship between effective stress and permeability of intact and fractured porous rocks. It has been found that most experimental data can be fitted using exponential equations. In this study the modified power law equations by Gangi for intact and fractured rocks are revisited to evaluate their applicability for modeling experimental permeability data which display exponential or near-exponential effective stress dependency. It has been shown that Gangi's power law equations for both intact and fractured rocks can be approximated, over the range of effective stresses of practical interest, by exponential equations with compressibilities that are related to the physical properties of the rock. The significance of this work is that it has provided further theoretical evidence for the apparent exponential relationship between effective stress and permeability. Moreover, it allows for more vigorous theoretical equations to be applied with the easiness of empirical exponential equations. This is demonstrated by applying the models to the experimental permeability data for six gas shales reported recently.
Si G, Durucan S, Jamnikar S, et al., 2015, Seismic monitoring and analysis of excessive gas emissions in heterogeneous coal seams, International Journal of Coal Geology, Vol: 149, Pages: 41-54, ISSN: 0166-5162
Uncontrolled and excessive gas emissions pose a serious threat to safety in underground coal mining. In a recently completed research project, a suite of monitoring techniques were employed to assess the dynamic response of the coal seam being mined to longwall face advance at Coal Mine Velenje in Slovenia. Together with continuous monitoring of gas emissions, two seismic tomography measurement campaigns and a microseismic monitoring programme were implemented at one longwall top coal caving panel. Over 2000 microseismic events were recorded during a period of four months. Over the same period, there also was a recorded episode of relatively high gas emission in the same longwall district. In this paper, a detailed analysis of the processed microseismic data collected during the same monitoring period is presented. Specifically, the analysis includes the spatial distribution of the microseismic events with respect to the longwall face advance, the magnitude of the energy released per week and its temporal evolution. Examination of the spatial distribution of the recorded microseismic events has shown that most of the microseismic activity occurred ahead of the advancing face. Furthermore, the analysis of the gas emission and microseismic monitoring data has suggested that there is a direct correlation between microseismicity and gas emission rate, and that gas emission rate tends to reach a peak when seismic energy increases dramatically. It is believed that localised stress concentration over a relatively strong xylite-rich zone and its eventual failure, which was also identified by the seismic tomography measurements, may have triggered the heightened microseismic activity and the excessive gas emission episode experienced at the longwall panel monitored.
Andrianopoulos E, Korre A, Durucan S, 2015, Chemical Process Modelling of Underground Coal Gasification and Evaluation of Produced Gas Quality for End Use, Energy Procedia, Vol: 76, Pages: 444-453, ISSN: 1876-6102
The chemical process at the heart of Underground Coal Gasification (UCG) is the engineered injection of a blend of gasification (normally O2, air, H2O) agents into the coal resource. Established surface gasifier chemical modelling principles are adapted for modelling UCG processes. Model configurations developed in Aspen Plus are used to simulate the Linked Vertical Wells and the Controlled Retractable Injection Point gasifier layouts. Sensitivity analyses were conducted to investigate the effect of operational parameters and performance indicators. Model outputs were validated using reported UCG trial results. The gasification designs developed could form the basis for developing an integrated UCG model.
Si G, Jamnikar S, Lazar J, et al., 2015, Monitoring and modelling of gas dynamics in multi-level longwall top coal caving of ultra-thick coal seams, part I: Borehole measurements and a conceptual model for gas emission zones, International Journal of Coal Geology, Vol: 144-145, Pages: 98-110, ISSN: 1872-7840
Si G, Shi J-Q, Durucan S, et al., 2015, Monitoring and modelling of gas dynamics in multi-level longwall top coal caving of ultra-thick coal seams, Part II: Numerical modelling, International Journal of Coal Geology, Vol: 144-145, Pages: 58-70, ISSN: 1872-7840
Manzoor S, Korre A, Durucan S, et al., 2015, Environmental and human health risk assessment of amine emissions from post combustion power plants, Publisher: AMER CHEMICAL SOC, ISSN: 0065-7727
Manzoor S, Korre A, Durucan S, et al., 2014, Atmospheric Chemistry Modelling of Amine Emissions from Post Combustion CO2 Capture Technology, 12th International Conference on Greenhouse Gas Control Technologies (GHGT), Publisher: Elsevier, Pages: 822-829, ISSN: 1876-6102
Emissions from post combustion CO2 capture plants using amine solvents are of concern due to their adverse impacts on the human health and environment. Potent carcinogens such as nitrosamines and nitramines resulting from the degradation of the amine emissions in the atmosphere have not been fully investigated. It is, therefore, imperative to determine the atmospheric fate of these amine emissions, such as their chemical transformation, deposition and transport pathways away from the emitting facility so as to perform essential risk assessments. More importantly, there is a lack of integration of amine atmospheric chemistry with dispersion studies. In this work, the atmospheric chemistry of the reference solvent for CO2 capture, monoethanolamine, and the most common degradation amines, methylamine and dimethylamine, formed as part of the post combustion capture process are considered along with dispersion calculations. Rate constants describing the atmospheric chemistry reactions of the amines of interest are obtained using theoretical quantum chemistry methods and kinetic modeling. The dispersion of these amines in the atmosphere is modeled using an air-dispersion model, ADMS 5. A worst case study on the UK's largest CO2 capture pilot plant, Ferrybridge, is carried out to estimate the maximum tolerable emissions of these amines into the atmosphere so that the calculated concentrations do not exceed guideline values and that the risk is acceptable.
Shi J-Q, Pan Z, Durucan S, 2014, Analytical models for coal permeability changes during coalbed methane recovery: Model comparison and performance evaluation, INTERNATIONAL JOURNAL OF COAL GEOLOGY, Vol: 136, Pages: 17-24, ISSN: 0166-5162
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- Citations: 42
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