Natural Gas Feed Research Articles

Design of an energy hub based on natural gas and renewable energy sources

SUMMARY This paper presents a simulation model for an energy hub consisting of natural gas (NG) turbines as the main sources of energy (including both electricity and heat) and two renewable energy sources—wind turbines (WTs) and photovoltaic (PV) solar cells. The hub also includes water electrolyzers for hydrogen production. The hydrogen serves as an energy storage medium that can be used in some transportation applications, or it can be mixed with the NG feed stream to improve the emission profile of the gas-turbine unit. The capacity of the designed hub is meant to simulate and replace the coal-fired Nanticoke Generating Station with a NG-fired power plant. Therefore, the aim of this work is to develop a simulated model that combines different energy generation technologies, which are evaluated in terms of the total energy produced, the cost per kWh of energy generated, and the amount of emissions produced. The proposed model investigates the benefits, both economic and environmental, the technological barriers, and the challenges of energy hubs by developing several scenarios. The simulation of these scenarios was done using General Algebraic Modeling System (GAMS®). Although the software is strongly known for its optimization capability, the mixed complementary problems solver makes it a strong tool for solving equilibrium problems. Excess energy produced during off-peak demand by WTs and PV solar cells was used to feed the electrolyzer to produce H2 and O2. The proposed approach shows that a significant reduction in energy cost and greenhouse gas emissions were achieved, in addition to the increased overall efficiency of the energy hub. Out of the examined three scenarios, Scenario C appeared to be the most feasible option for a combination of renewable and non-renewable technologies as it did not only produce hydrogen, but also provided electricity at relatively lower prices. Copyright © 2013 John Wiley & Sons, Ltd.

Direct conversion of natural gas into COx-free hydrogen and MWCNTs over commercial Ni–Mo/Al2O3 catalyst: Effect of reaction parameters

A commercial hydrotreating nickel molybdate/alumina catalyst was used for the direct conversion of natural gas (NG) into COx-free hydrogen and a co-valuable product of multi-walled carbon nanotubes (MWCNTs). The catalytic runs were carried out atmospherically in a fixed-bed flow reactor. The effect of reaction temperature between 600 and 800°C, and dilution of the NG feed with nitrogen as well as pretreatment of the catalyst with hydrogen were investigated. At a reaction temperature of 700°C and dilution ratio of NG/N2=20/30, the optimum yield of H2 (∼80%) was obtained with higher longevity. However, using the feed ratio of NG/N2=30/20, the optimum yield of MWCNTs was obtained (669%). X-ray diffraction pattern for the catalyst after the reaction showed that the MWCNTs were grown on the catalyst at all reaction temperatures under study. TEM pictures revealed that the as-grown MWCNTs at 600, 650 and 800°C are short and long with a low graphitization degree. At 700°C a forest of condensed CNTs is formed, whereas both carbon nanofibers and CNTs were formed at 750°C.

Study of natural gas feed preheater failed tubes

The 103-B bare and finned tubes in the convection zone of the Natural Gas Feed Preheater, were ruptured with significant bulging at the vicinity of the crack. The heavy scale and soot deposits at the inner surface of the tubes were locally present over the crack region. It was observed from the thermal data and operational history that the preheater was being operated over the design limits. The visual observation and metallurgical investigation at the vicinity of cracks confirmed that the stress rupture was due to creep phenomenon by the intrinsic microstructure degradation of the tube materials.

High temperature failure of natural gas feed burner pipe

The degradation of AISI 310 austenitic stainless steel pipe, which was used at high temperature in carbonaceous reducing atmosphere, was investigated in this work. In order to examine the causes of failure, various techniques including on-site investigation, optical microscopy, scanning electron microscopy, energy dispersive spectroscopy, X-ray diffraction, metallography, and micro-hardness measurement were carried out. Scale separation and spallation were only observed at the internal surface of the pipe as a result of overheating service condition at the tip portion. The scale separation and spallation caused nozzle block and subsequent furnace shutdown. Growth of carbide precipitates and disintegration of alloys into dusts of coke and particles suggested carburization and metal dusting failure. It is recommended to monitor service temperature periodically at the tip portion. The service temperature should not exceed the designed value. Careful control of oxidizing/carburizing burning condition is strongly advised. Material selection is also discussed as an alternative means of failure prevention.

Effect of multi-stream heat exchanger on performance of natural gas liquefaction with mixed refrigerant

A thermodynamic study is carried out to investigate the effect of multi-stream heat exchanger on the performance of natural gas (NG) liquefaction with mixed refrigerant (MR). A cold stream (low-pressure MR) is in thermal contact with opposite flow of two hot streams (high-pressure MR and NG feed) at the same time. In typical process simulation with commercial software (such as Aspen HYSYS®), the liquefaction performance is estimated with a method of minimum temperature approach, simply assuming that two hot streams have the same temperature. In this study, local energy balance equations are rigorously solved with temperature-dependent properties of MR and NG feed, and are linked to the thermodynamic cycle analysis. The figure of merit (FOM) is quantitatively examined in terms of UA (the product of overall heat transfer coefficient and heat exchange area) between respective streams. In a single-stage MR process, it is concluded that the temperature profile from HYSYS is difficult to realize in practice, and the FOM value from HYSYS is an over-estimate, but can be closely achieved with a proper heat-exchanger design. It is also demonstrated that there exists a unique optimal ratio in three UA’s, and no direct heat exchanger between hot streams is recommended.

Analysis of a Micro Gas Turbine Fed by Natural Gas and Synthesis Gas: MGT Test Bench and Combustor CFD Analysis

In recent years, the interest in the research on energy production systems fed by biofuels has increased. Gaseous fuels obtained through biomass conversion processes such as gasification, pyrolysis and pyrogasification are generally defined as synthesis gas (syngas). The use of synthesis gas in small-size energy systems, such as those used for distributed micro-cogeneration, has not yet reached a level of technological maturity that could allow a large market diffusion. For this reason, further analyses (both experimental and numerical) have to be carried out to allow these technologies to achieve performance and reliability typical of established technologies based on traditional fuels. In this paper, a numerical analysis of a combustor of a 100-kW micro gas turbine fed by natural gas and biomass-derived synthesis gas is presented. The work has been developed in the framework of a collaboration between the Engineering Department of the University of Ferrara, the Istituto Motori - CNR (Napoli), and Turbec S.p A. of Corporeno di Cento (FE). The main features of the micro gas turbine Turbec T100, located at the Istituto Motori - CNR, are firstly described. A decompression and distribution system allows the feeding of the micro gas turbine with gaseous fuels characterized by different compositions. Moreover, a system of remote monitoring and control together with a data transfer system has been developed in order to set the operative parameters of the machine. The results of the tests performed under different operating conditions are then presented. Subsequently, the paper presents the numerical analysis of a model of the micro gas turbine combustor. The combustor model is validated against manufacturer performance data and experimental data with respect to steady state performance, i.e., average outlet temperature and emission levels. A sensitivity analysis on the model capability to simulate different operating conditions is then performed. The combustor model is used to simulate the combustion of a syngas, composed of different ratios of hydrogen, carbon monoxide, methane, carbon dioxide and water. The results in terms of flame displacement, temperature and emission distribution and values are analyzed and compared to the natural gas simulations. Finally, some simple modifications to the combustion chamber are proposed and simulated both with natural gas and syngas feeding.

Catalytic reforming of natural gas for hydrogen production in a pilot fluidized-bed membrane reactor: Mapping of operating and feed conditions

A fluidized-bed membrane reformer was operated in two independent laboratories to map various operating conditions, to investigate the effects of changing the composition of the natural gas feed stream and to verify earlier experimental trials. Two feed natural gases were tested, containing either 95.5 or 90.1 mol% of methane (3.6 or 9.9 mol% of other gaseous higher hydrocarbons). Experimental tests investigated the influence of total membrane area, reactor pressure, permeate pressure and natural gas feed rates. A permeate-H 2-to reactor natural gas feed molar ratio >2.3 was achieved with six two-sided membrane panels under steam reforming conditions and a pressure differential across the membranes of 785 kPa. The total cumulative reforming time reached 395 h, while hydrogen purity exceeded 99.99% during all tests.

터보 팽창기를 활용한 NGL 회수공정 최적화에 대한 연구

본 연구에서는 전처리 공정을 거친 천연가스로부터 에탄 이상의 성분을 회수하기 위한 탈메탄탑에 대한 전산모사와 공정 최적화를 수행하였다. 전처리된 천연가스는 탈메탄탑 상부의 차가운 기상류와의 열교환 및 프로판 냉동 사이클이 포함된 예냉공정을 거친 후에 기상과 액상이 분리된다. 기상은 터보 팽창기를 거치면서 생산되는 동력을 residue gas의 압력을 높이기 위한 압축기에 전달한 후에 부분적으로 응축되어 탈메탄탑 상부로 주입된다. 액상류는 줄-톰슨 팽창 밸브를 거친 후 더욱 냉각되어 탈메탄탑의 중간부로 주입된다. 원료 대비 에탄의 회수율은 75% 이상으로 정하였으며, 탈메탄탑의 탑저에서 에탄에 대한 메탄의 몰비는 0.015로 정하였다. 한편 프로판 냉동 사이클의 heat duty를 최소화시키기 위해서 원료를 분리하여 side reboiler와 열교환시킴으로써 냉열의 일부 회수할 수 있었다. In this study, simulation and optimization works for a demethanizer column have been performed to obtain ethane and heavier products from a pretreated natural gas stream. Pretreated natural gas feed stream is partially condensed after being precooled by exchanging heat with demethanizer top vapor stream and by using an external refrigeration cycle with a propane refrigerant. Vapor stream is furtherly cooled and partially condensed through a turbo-expander and the power generated from the expansion of turbo-expander was delivered to the compressor for the residue gas compression. Liquid stream is being cooled by Joule-Thomson expansion valve and is fed to the middle section of the demethanizer. Ethane recovery percent for feed natural gas was set to 75% and methane to ethane molar ratio was fixed as 0.015. Propane refrigeration heat duty was reduced by splitting the feed stream and to exchange heat with side reboiler.

터보 팽창기를 활용한 NGL 회수공정에서 최적의 탈메탄탑의 운전압력 결정을 통한 냉동 소요동력 최소화에 대한 연구

본 연구에서는 전처리 공정을 거친 천연가스로부터 에탄 이상의 성분을 회수하기 위한 탈메탄탑에 대한 전산모사와 공정 최적화를 수행하였다. 전처리된 천연가스는 탈메탄탑 상부의 차가운 기상류와의 열교환 및 프로판 냉동 사이클이 포함된 예냉공정을 거친 후에 기상과 액상이 분리된다. 기상은 터보 팽창기를 거치면서 생산되는 동력을 residue gas의 압력을 높이기 위한 압축기에 전달한 후에 부분적으로 응축되어 탈메탄탑 상부로 주입된다. 액상류는 줄-톰슨 팽창 밸브를 거친 후 더욱 냉각되어 탈메탄탑의 중간부로 주입된다. 원료 대비 에탄의 회수율은 80% 이상으로 정하였으며, 탈메탄탑의 탑저에서 에탄에 대한 메탄의 몰비는 0.0119로 정하였다. 한편 프로판 냉동 사이클의 heat duty를 최소화시키기 위해서 원료를 분리하여 side reboiler와 열교환시킴으로써 냉열의 일부를 회수할 수 있었다. 【In this study, simulation and optimization works for a demethanizer column have been performed to obtain ethane and heavier products from a pretreated natural gas stream. Pretreated natural gas feed stream was partially condensed after being precooled by exchanging heat with demethanizer top vapor stream and by using an external refrigeration cycle with a propane refrigerant. Vapor stream was cooled further and partially condensed through a turbo-expander. The power generated from the expansion of turbo-expander was delivered to the compressor for the residue gas compression. Liquid stream was cooled by Joule-Thomson expansion valve and was fed to the middle section of the demethanizer. Recovery percent of ethane for feed natural was set to 80% and methane to ethane molar ratio was fixed as 0.0119. On the other hand, some of the cold heat could be recovered by splitting the feed stream and by exchanging heat with side reboiler in order to reduce the heat duty in the propane refrigeration cycle.】

천연가스 액화를 위한 캐스케이드 냉동사이클의 전산모사에 대한 연구 [2]: 다단 캐스케이드 냉동 사이클에 적용

In this paper, simulation works for a multi-stage cascade refrigeration cycle using propane, ethylene and methane as refrigerants have been performed for the liquefaction of natural gas using Peng-Robinson equation of state built-in PRO/II with PROVISION release 8.3. The natural gas feed compositions were supplied from Korea Gas Corporation and the flow rate was assumed to be 5.0 million tons per annual. Supply temperature for propane refrigerant was fixed as -40 o

천연가스 액화를 위한 캐스케이드 냉동사이클의 전산모사에 대한 연구 [1

Abstract In this paper, simulation works for a cascade refrigeration cycle using propane, ethylene and methane as a refrigerant have been performed for the liquefaction of natural gas using Peng-Robinson equation of state built-in PRO/II with PROVISION release 8.3. The natural gas feed compositions were supplied from Korea Gas Corporation and the flow rate was assumed to be 5.0 million tons per annual. Supply temperature for propane refrigerant was fixed as -40 o C, that for ethylene refrigerant as -95 o C, and that for methane refrigerant as -155 o C. Natural gas was finally cooled and liquefied to -162 o C by Joule-Thomson expansion. Conclusively, 91.64% by mole of the natural gas liquefaction ratio was obtained through a cascade refrigeration cycle and Joule-Thomson expansion. Key Words : Cascade refrigeration, Peng-Robinson equation of state, Refrigerant, liquefied natural gas 본 연구는 국토해양부 LNG플랜트사업단의 연구비지원에 의해 수행되었습니다. * 교신저자 : 조정호(jhcho@kongju.ac.kr)접수일 10년 11월 30일 수정일 (1차 10년 12월 23일, 2차 10년 12월 30일) 게재확정일 11년 01월 13일

In-situ CO2 capture in a pilot-scale fluidized-bed membrane reformer for ultra-pure hydrogen production

A novel pilot fluidized-bed membrane reformer (FBMR) with permselective palladium membranes was operated with a limestone sorbent to remove CO2in-situ, thereby shifting the thermodynamic equilibrium to enhance pure hydrogen production. The reactor was fed with methane to fluidize a mixture of calcium oxide (CaO)/limestone (CaCO3) and a Ni-alumina catalyst. Experimental tests investigated the influence of limestone loading, total membrane area and natural gas feed rates. Hydrogen-permeate to feed methane molar ratios in excess of 1.9 were measured. This value could increase further if additional membrane area were installed or by purifying the reformer off-gas given its high hydrogen content, especially during the carbonation stages. A maximum of 0.19 mol of CO2 were adsorbed per mole of CaO during carbonation. For the conditions studied, the maximum carbon capture efficiency was 87%. The reformer operated for up to 30 min without releasing CO2 and for up to 240 min with some degree of CO2 capture. It was demonstrated that CO2 adsorption can significantly improve the productivity of the reforming process. In-situ CO2 capture enhanced the production of hydrogen whose purity exceeded 99.99%.

Plant flexibility of a pre-combustion CO2 capture cycle

Abstract The aim of the paper is to investigate plant flexibility for a pre-combustion cycle. That is, answering the question: how flexible is the plant to changes in operating conditions? Steady-state off-design simulations was the key component of the plant flexibility analysis. Specifically, part load behavior and dual-fuel operation of the integrated reforming combined cycle (IRCC) were studied. The idea of the plant was to use hydrogen-rich decarbonized fuel as the primary fuel and natural gas as back-up fuel. If a problem would occur in the reforming, water-gas shift, or CO 2 capture processes there might be a need to switch to a natural gas feed for the gas turbine. This led to design challenges for the heat recovery steam generator (HRSG). The design of the HRSG for the IRCC process was different from an HRSG design in a natural gas combined cycle (NGCC) plant because of the significant amount of steam production from the heat generated in the reforming process. In addition, preheating (within the HRSG) of some of the process streams could add to the complexity in HRSG design. For the concepts studied it was of importance to maintain a high net plant efficiency on both fuels. Therefore the HRSG design had to be a compromise between NGCC and IRCC operation modes. In the analysis performed, part load behavior was good with efficiency reductions from base load operation comparable to that of the reference combined cycle plant. Based on the analysis performed in the present work, it was possible to operate a complex plant like an IRCC at loads down to 60 gas turbine load while capturing 85% of the CO 2 . During start-up and operation at lower loads, CO 2 would not be captured. The investigation was done by using process simulation tools Aspen Plus by AspenTech and GT PRO/GT MASTER by Thermoflow.

A novel system for the production of pure hydrogen from natural gas based on solid oxide fuel cell–solid oxide electrolyzer

In this paper, a novel process for the production of pure hydrogen from natural gas based on the integration of solid oxide fuel cells (SOFCs) and solid oxide electrolyzer cells (SOECs) is presented. In this configuration, the SOFC is fed by natural gas and provides electricity and heat to the SOEC, which carries out the separation of steam into hydrogen and oxygen. Depending on the system layout considered, the oxygen available at the SOEC anode outlet can be either mixed with the SOFC cathode stream in order to improve the SOFC performance or regarded as a co-product. Two configurations of the cell stack are studied. The first consists of a stack with the same number of SOFCs and SOECs working at the same current density. In this case, since in typical operating conditions the voltage delivered by the SOFC is lower than the one required by the SOEC, the required additional power is supplied by means of an electric grid connection. In the second case, the electricity balance is compensated by providing additional SOFCs to the stack, which are fed by a supplementary natural gas feed. Simulations carried out with Aspen Plus show that pure hydrogen can be produced with a natural gas to hydrogen LHV-efficiency that is about twice the value of a typical water electrolyzer and comparable to that of medium-scale reformers.

HyGenSys: a Flexible Process for Hydrogen and Power Production with Reduction of CO2Emission

This paper presents the latest development of HyGenSys, a new sustainable process and technology for the conversion of natural gas to hydrogen and power. The concept combines a specific steam reforming reactor-exchanger with a gas turbine. The heat necessary for the steam reforming reaction comes from hot pressurized flue gases produced in a gas turbine instead of a conventional furnace. Thanks to this high level of heat integration, the overall efficiency is improved and the natural gas consumption is reduced which represents an advantage with regard to economics and CO<sub>2<sub/> emission reduction. In addition to the efficient HyGenSys process scheme itself, the technology of the reactorexchanger also offers a high level of heat integration for even more energy saving.Two main alternatives are examined in order to meet two different requirements. The first one, named HyGenSys-0, focuses on the hydrogen production for the refining and petrochemical application. The second one named HyGenSys-1, concerns the centralized power production with pre-combustion CO<sub>2<sub/>capture. In that case, the produced hydrogen is fully used to fuel a power gas turbine. HyGenSys-1 has been developed and optimised in CACHET, a European Community funded project. The CACHET electrical power objective was 400 MW at the minimum.HyGenSys-0 and HyGenSys-1 are described in detail with challenges and advantages compared to existing technologies.For both alternatives, the heart of the technology is the reactor-exchanger. The reactor-exchanger design relies on an innovative arrangement of bayonet tubes that allows, at large scale, multiple heat exchanges between hot pressurized flue gas, natural gas feed and hydrogen rich stream produced.

Design and exergetic analysis of a novel carbon free tri-generation system for hydrogen, power and heat production from natural gas, based on combined solid oxide fuel and electrolyser cells

The Solid Oxide Cells (SOCs) are able to operate in two modes: (a) the Solid Oxide Fuel Cells (SOFCs) that produce electricity and heat and (b) the Solid Oxide Electrolyser Cells (SOEC) that consume electricity and heat to electrolyse water and produce hydrogen and oxygen. The present paper presents a carbon free SOEC/SOFC combined system for the production of hydrogen, electricity and heat (tri-generation) from natural gas fuel. Hydrogen can be locally used as automobile fuel whereas the oxygen produced in the SOEC is used to combust the depleted fuel from the SOFC, which is producing electricity and heat from natural gas. In order to achieve efficient carbon capture in such a system, water steam should be used as the SOEC anode sweep gas, to allow the production of nitrogen free flue gases. The SOEC and SOFC operations were matched through modeling of all components in Aspenplus™. The exergetic efficiency of the proposed decentralised system is 28.25% for power generation and 18.55% for production of hydrogen. The system is (a) carbon free because it offers an almost pure pressurised CO 2 stream to be driven for fixation via parallel pipelines to the natural gas feed, (b) does not require any additional water for its operation and (c) offers 26.53% of its energetic input as hot water for applications.

Syngas and a separate nitrogen/argon stream via chemical looping reforming – A 140 kW pilot plant study

A dual circulating fluidized bed pilot plant was operated in chemical looping reforming conditions at a scale of 140 kW fuel power with natural gas as fuel. A nickel-based oxygen carrier was used as bed material. The pilot plant is equipped with an adjustable cooling system. Three experimental campaigns have been carried out at 747 °C (1020 K), 798 °C (1071 K) and 903 °C (1176 K), respectively. In each campaign, the global stoichiometric air/fuel ratio was varied step-wise between 1.1 and the minimum value possible to keep the desired operating temperature when the cooling is finally switched off. The results show that the fuel reactor exhaust gas approaches thermodynamic equilibrium. The residual amount of methane left decreases with increasing fuel reactor temperature. Further, the oxygen in the air reactor can be completely absorbed by the solids as soon as the air reactor operating temperature is higher than 900 °C (1173 K). Even though no steam was added to the natural gas feed no carbon formation was found for global excess air ratios larger than 0.4.

Inherent Safety Analysis of a Propane Precooled Gas-Phase Liquified Natural Gas Process

Refrigeration is widely used in chemical and petrochemical industries and in the liquefaction of gases including natural gas (LNG). There are many commercial processes being used in the LNG industries. These processes are energy intensive and require large capital investment. Conventional refrigeration processes such as the single mixed refrigerant process and the cascade refrigerant process operate by evaporation of the refrigerant. Gas-phase refrigeration processes have one important advantage over these processes and this is their very low hydrocarbon inventory. However, precooling the natural gas feed stream with a conventional propane refrigeration system significantly improves the efficiency of the gas phase refrigeration process. However, due to the propane precooling cycle, the liquid hydrocarbon inventory in the process increases, and hence, the hazard potential of the overall process increases. Therefore, there is a tradeoff between the energy efficiency and the inherent safety of the process. T...

Catalytic combustion of VOC in a counter-diffusive reactor

This paper presents the results of an experimental investigation on the performance of a counter-diffusive radiant heater used for the combustion of methane and BTEX compounds. The effect of natural gas feed rate on its fractional conversion was studied and it was found that as the feed rate increases the conversion drops, owing to a lack of oxygen for combustion. The effect of oxygen deficiency was confirmed by increasing the air circulation rate in front of the catalyst pad using a fan. The effect of oxygen limitation was also verified by addition of increasing concentrations of pentane to the reactor that led to reduced methane conversion. Suitability of counter-diffusive radiant heater for treatment of natural gas dehydration process effluent was investigated by addition of water, pentane and toluene to the natural gas used as reactor feed. It was found that presence of water does not have a significant negative impact on catalyst activity when added as a vapour, and when other hydrocarbons are present in the feed stream, complete hydrocarbon conversion can be achieved by satisfying the oxygen demand.

Modelling and Optimization of Primary Steam Reformer System Case Study: the Primary Reformer PT Petrokimia Gresik Indonesia

Steam reforming of hydrocarbons has been in use as the principal process for the generation of hydrogen and synthesis gas needed in the Ammonia production in petrochemical industries. Optimal operation of existing steam reformers is crucial in view of the high energy consumption and large value addition involved in the process. The economic objective of the process is determined by the cost of gas (Methane), the cost of steam and additional fuel. An optimum steam to gas ratio is expected from an optimum process control. This can be applied on ratio control parameter for natural gas feed. In addition, steam Carbon Ratio is used to decrease coke formation in catalyst reformer. This paper presents the model identification and optimization of reforming control system of an industrial Primary Reformer at PT. Petrokimia Gresik (One of the fertilizer petrochemical industry in Indonesia). The reformer model has been approximated in the form of Takagi-Sugeno-Kang fuzzy inference system, with architecture in neural-network model. ANFIS (Adaptive Neuro-Fuzzy Inference System) has been utilized to determine NARX or ARX parameters model describing the dynamic of Industrial operational data have been used for training and validating the model. The optimization problem has been addressed through the utilization of Constrained Nonlinear Programming. The aim is to find the optimal process and ratio controller parameters to achieve the maximum Hydrogen formation. For a maximum fixed production rate of hydrogen produced by the unit, minimization of methane feed rate is chosen as the objective function to meet processing requirements. Keywords : Hydrocarbons, Model identification, ANFIS Normal 0 false false false IN X-NONE X-NONE /* Style Definitions */ table.MsoNormalTable {mso-style-name:Table Normal; mso-tstyle-rowband-size:0; mso-tstyle-colband-size:0; mso-style-noshow:yes; mso-style-priority:99; mso-style-parent:; mso-padding-alt:0cm 5.4pt 0cm 5.4pt; mso-para-margin-top:0cm; mso-para-margin-right:0cm; mso-para-margin-bottom:10.0pt; mso-para-margin-left:0cm; line-height:115%; mso-pagination:widow-orphan; font-size:11.0pt; font-family:Calibri,sans-serif; mso-ascii-font-family:Calibri; mso-ascii-theme-font:minor-latin; mso-hansi-font-family:Calibri; mso-hansi-theme-font:minor-latin; mso-bidi-font-family:Times New Roman; mso-bidi-theme-font:minor-bidi; mso-fareast-language:EN-US;}