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Dive into the research topics where Henry W. Pennline is active.

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Featured researches published by Henry W. Pennline.


Journal of The Air & Waste Management Association | 2003

Separation and capture of CO2 from large stationary sources and sequestration in geological formations--coalbeds and deep saline aquifers.

Curt M. White; Brian R. Strazisar; Evan J. Granite; James S. Hoffman; Henry W. Pennline

Abstract The topic of global warming as a result of increased atmospheric CO2 concentration is arguably the most important environmental issue that the world faces today. It is a global problem that will need to be solved on a global level. The link between anthropogenic emissions of CO2 with increased atmospheric CO2 levels and, in turn, with increased global temperatures has been well established and accepted by the world. International organizations such as the United Nations Framework Convention on Climate Change (UNFCCC) and the Intergovernmental Panel on Climate Change (IPCC) have been formed to address this issue. Three options are being explored to stabilize atmospheric levels of greenhouse gases (GHGs) and global temperatures without severely and negatively impacting standard of living: (1) increasing energy efficiency, (2) switching to less carbon-intensive sources of energy, and (3) carbon sequestration. To be successful, all three options must be used in concert. The third option is the subject of this review. Specifically, this review will cover the capture and geologic sequestration of CO2 generated from large point sources, namely fossil-fuel-fired power gasification plants. Sequestration of CO2 in geological formations is necessary to meet the President’s Global Climate Change Initiative target of an 18% reduction in GHG intensity by 2012. Further, the best strategy to stabilize the atmospheric concentration of CO2 results from a multifaceted approach where sequestration of CO2 into geological formations is combined with increased efficiency in electric power generation and utilization, increased conservation, increased use of lower carbonintensity fuels, and increased use of nuclear energy and renewables. This review covers the separation and capture of CO2 from both flue gas and fuel gas using wet scrubbing technologies, dry regenerable sorbents, membranes, cryogenics, pressure and temperature swing adsorption, and other advanced concepts. Existing commercial CO2 capture facilities at electric power-generating stations based on the use of monoethanolamine are described, as is the Rectisol process used by Dakota Gasification to separate and capture CO2 from a coal gasifier. Two technologies for storage of the captured CO2 are reviewed—sequestration in deep unmineable coalbeds with concomitant recovery of CH4 and sequestration in deep saline aquifers. Key issues for both of these techniques include estimating the potential storage capacity, the storage integrity, and the physical and chemical processes that are initiated by injecting CO2 underground. Recent studies using computer modeling as well as laboratory and field experimentation are presented here. In addition, several projects have been initiated in which CO2 is injected into a deep coal seam or saline aquifer. The current status of several such projects is discussed. Included is a commercial-scale project in which a million tons of CO2 are injected annually into an aquifer under the North Sea in Norway. The review makes the case that this can all be accomplished safely with off-the-shelf technologies. However, substantial research and development must be performed to reduce the cost, decrease the risks, and increase the safety of sequestration technologies. This review also includes discussion of possible problems related to deep injection of CO2 . There are safety concerns that need to be addressed because of the possibilities of leakage to the surface and induced seismic activity. These issues are presented along with a case study of a similar incident in the past. It is clear that monitoring and verification of storage will be a crucial part of all geological sequestration practices so that such problems may be avoided. Available techniques include direct measurement of CO2 and CH4 surface soil fluxes, the use of chemical tracers, and underground 4-D seismic monitoring. Ten new hypotheses were formulated to describe what happens when CO2 is pumped into a coal seam. These hypotheses provide significant insight into the fundamental chemical, physical, and thermodynamic phenomena that occur during coal seam sequestration of CO2 .


International Journal of Environmental Technology and Management | 2004

Aqua ammonia process for simultaneous removal of CO2, SO2 and NOx

Kevin P. Resnik; James T. Yeh; Henry W. Pennline

Experimental research work in applying aqueous ammonia solution for the simultaneous reduction of acidic gaseous emission from fossil fuel-fired utility plants is currently being performed at the National Energy Technology Laboratory. The traditional monoethanolamine process for CO2 removal suffers the disadvantages of low carbon dioxide loading capacity, equipment corrosion, amine degradation by SO2 and O2 in flue gas, and high energy penalty during absorbent regeneration. The aqueous ammonia process can simultaneously remove CO2, SO2, NOx, plus HCl and HF that may exist in the flue gas. There could be oxidation of SO2 and NO prior to contacting the aqueous ammonia absorbent. Test results pertaining to the ammonia/carbon dioxide reaction in a semi-continuous reactor system are presented. The parametric effects of sparger design, reaction temperature, and ammonia concentration on gas loadings and absorption rates are discussed. Regeneration test results, including solution-cycling between the regeneration and absorption steps to determine a realistic loading capacity for the ammonia solutions are also presented.


International Journal of Greenhouse Gas Control | 2008

Performance of immobilized tertiary amine solid sorbents for the capture of carbon dioxide

McMahan L. Gray; K.J. Champagne; Daniel J. Fauth; John P. Baltrus; Henry W. Pennline

The capture of carbon dioxide (CO2) from a simulated flue gas stream was achieved by utilizing immobilized tertiary amine solid sorbents. The tertiary amine immobilized in these solid substrates was 1, 8 Diazabicyclo-[5.4.0]-undec-7-ene (DBU) and it has the stoichiometric capability of capturing carbon dioxide at a 1:1 R-NH2:CO2 molar ratio. This is a unique feature compared to other primary and secondary amines which capture CO2 at a 2:1 molar ratio, thus making the immobilized DBU solid sorbents competitive with existing commercially available sorbents and liquid amine-based capture systems. The immobilized DBU solid sorbents prepared in this study exhibit acceptable CO2 capture capacities of 3.0 mol CO2/kg sorbent at 298 K; however, at the critical operational temperature of 338 K, the capacity was reduced to 2.3 mol/kg sorbent. The DBU sorbents did exhibit acceptable stability over the adsorption/desorption temperature range of 298–360 K based on XPS and TGA analyses.


Archive | 1998

Sorbents for mercury removal from flue gas

Evan J. Granite; Richard A. Hargis; Henry W. Pennline

A review of the various promoters and sorbents examined for the removal of mercury from flue gas is presented. Commercial sorbent processes are described along with the chemistry of the various sorbent-mercury interactions. Novel sorbents for removing mercury from flue gas are suggested. Since activated carbons are expensive, alternate sorbents and/or improved activated carbons are needed. Because of their lower cost, sorbent development work can focus on base metal oxides and halides. Additionally, the long-term sequestration of the mercury on the sorbent needs to be addressed. Contacting methods between the flue gas and the sorbent also merit investigation.


Other Information: PBD: 1 Dec 2003 | 2003

A Review of Carbon Dioxide Selective Membranes: A Topical Report

David R. Luebke; Henry W. Pennline

Carbon dioxide selective membranes provide a viable energy-saving alternative for CO2 separation, since membranes do not require any phase transformation. This review examines various CO2 selective membranes for the separation of CO2 and N2, CO2 and CH4, and CO2 and H2 from flue or fuel gas. This review attempts to summarize recent significant advances reported in the literature about various CO2 selective membranes, their stability, the effect of different parameters on the performance of the membrane, the structure and permeation properties relationships, and the transport mechanism applied in different CO2 selective membranes.


Main Group Chemistry | 2008

Implications of mercury interactions with band-gap semiconductor oxides

Evan J. Granite; William P. King; Dennis C. Stanko; Henry W. Pennline

Titanium dioxide is a well-known photooxidation catalyst. It will oxidize mercury in the presence of ultraviolet light from the sun and oxygen and/or moisture to form mercuric oxide. Several companies manufacture self-cleaning windows. These windows have a transparent coating of titanium dioxide. The titanium dioxide is capable of destroying organic contaminants in air in the presence of ultraviolet light from the sun, thereby keeping the windows clean. The commercially available self-cleaning windows were used to sequester mercury from oxygen–nitrogen mixtures. Samples of the self-cleaning glass were placed into specially designed photo-reactors in order to study the removal of elemental mercury from oxygen–nitrogen mixtures resembling air. The possibility of removing mercury from ambient air with a self-cleaning glass apparatus is examined. The intensity of 365-nm ultraviolet light was similar to the natural intensity from sunlight in the Pittsburgh region. Passive removal of mercury from the air may re...


International Journal of Environmental Technology and Management | 2004

Capture of carbon dioxide by solid amine sorbents

McMahan L. Gray; Yee Soong; Kenneth J. Champagne; Henry W. Pennline; John P. Baltrus; Robert W. Stevens; Rajesh Khatri; Steven S. C. Chuang

The reaction of tetraethylorthrosilcate (TEOS) with y-aminopropyltriethoxysilane (APTS) has produced stable solid amine sorbents for the capture of carbon dioxide. The resulting amine-enriched silicon sorbent (SBA-15) has been proven to be competitive with existing environmental CO2 controlled life sorbents based on the immobilised amine technology. XPS analysis has indicated that the amine groups (N1s Peak) were incorporated onto the surfaces of this amine-based sorbent in the range of 7%. The performance of the SBA-15 was comparable to the commercially available immobilised amine sorbent (IAS).


Journal of The Air & Waste Management Association | 2003

Modeling Sorbent Injection for Mercury Control in Baghouse Filters: I—Model Development and Sensitivity Analysis

Joseph R.V. Flora; Richard A. Hargis; William J. O'Dowd; Henry W. Pennline; Radisav D. Vidic

Abstract A two-stage mathematical model for Hg removal using powdered activated carbon injection upstream of a bag-house filter was developed, with the first stage accounting for removal in the ductwork and the second stage accounting for additional removal caused by the retention of carbon particles on the filter. The model shows that removal in the ductwork is minimal, and the additional carbon detention time from the entrapment of the carbon particles in the fabric filter enhances the Hg removal from the gas phase. A sensitivity analysis on the model shows that Hg removal is dependent on the isotherm parameters, the carbon pore radius and tortuosity, the C/Hg ratio, and the carbon particle radius.


Main Group Chemistry | 2008

Surface characterization of Pd/Al2O3 sorbents for mercury capture from fuel gas

John P. Baltrus; Evan J. Granite; Dennis C. Stanko; Henry W. Pennline

The surface composition of a series of Pd/alumina sorbents has been characterized to better understand the factors influencing their ability to adsorb mercury from fuel gas. Both a temperature effect and a dispersion effect were found. Maximum adsorption of Hg occurred at the lowest temperature tested, 2048C, and decreased with increasing temperatures. Maximum adsorption of Hg on a per-atom basis of Pd is observed at low loadings of Pd (58.5% Pd) due to better dispersion of Pd at those loadings; a change in its partitioning occurs at higher loadings. The presence of H2S in the fuel gas acts to promote the adsorption of Hg through its association with Hg in the Pd lattice.


Chemical Engineering Communications | 1992

INTEGRATED TESTING OF THE NOXSO PROCESS: SIMULTANEOUS REMOVAL OF SO2 AND NO x FROM FLUE GAS

James T. Yeh; Warren T. Ma; Henry W. Pennline; John Leo Haslbeck; James I. Joubert; Frederick N. Gromicko

Abstract Parametric studies with the NOXSO process—a dry, regenerable flue gas treatment system that simultaneously removes SO2 and NOx from flue gas produced by the combustion of coal—were conducted. The reusable sorbent that was tested consisted of sodium carbonate impregnated on a high surface area γ-alumina sphere (1·6- mm nominal diameter). All process steps, including adsorption and regeneration, were integrated into a new 60-KWe-scale Life-Cycle Test Unit so that continuous, long-term operation of the total process could be experimentally evaluated. The effects of sorbent flow rate, temperature, inlet SO2 and NOx, concentrations, and sorbent residence time (fluid bed depth) on pollutant removal efficiencies in the absorption step were determined. Also, the impact of the type of regenerant gas, temperature, steam, excess regenerant gas, and diluent on the regeneration of the sorbent was investigated. Sorbent properties with respect to time on stream (cycles of operation) are also reported.

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Evan J. Granite

United States Department of Energy

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James S. Hoffman

United States Department of Energy

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Daniel J. Fauth

United States Department of Energy

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McMahan L. Gray

United States Department of Energy

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David R. Luebke

United States Department of Energy

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Richard A. Hargis

United States Department of Energy

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James T. Yeh

United States Department of Energy

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Kevin P. Resnik

United States Department of Energy

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Christina R. Myers

United States Department of Energy

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Richard R. Schehl

United States Department of Energy

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