AndreaBozzo/ceres-open-data-index huggingface dataset:
Investigation of Combined S02/N0x Removal by Ceria Sorbents

Simultaneous removal of S02 and NOX using a regenerable solid sorbent will constitute  an important improvement over the use of separate processes for the removal of these two pollutants from stack gases and possibly eliminate several shortcomings of the individual S02  and NOX removal operations.  Recent studies at PETC considered cerium oxide as an   alternate sorbent to CUO.    The present study aims to determine the effects of ammonia on ihe sulfation of the  sorbent and to obtain a rate expression for the regeneration of alumina-supported CeOa  sorbents. In the past quarter the effect of cerium content of the sorbent on its performance  through four sulfation-regeneration cycles were investigated and the analysis of the  economics of a commercial scale ceria process wcs sub-contracted to TECOGEN.     It was found that all ceria sorbents did not show any capacity loss after the first cycle  and, in fact, their performance improved slightly after the third cycle. Increasing cerium  loading appears to reduce the S/Cc ratio to about 2 as monolayer coverage is approached.  It was found that the sulfation rate for the sorbents containing 9.28% and 7.64% cerium were  first order with respect to cerium oxide up to 90% conversion. The sorbents containing 4.39%  and 1.59 showed first order kinetics up to only about 40% conversion. The effects of product  layer diffusion and gas phase diffusion are currently being considered for these sorbents.

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Investigation of Combined S02/N0x Removal by Ceria Sorbents

Simultaneous removal of S02 and NOx using a regenerable solid sorbent will  constitute an important improvement over the use of separate processes for the removal  of these two pollutants from stack gases and possibly eliminate several shortcomings of  the individual S02 and NOx removal operations.  Recent studies at PHC considered  cerium oxide as an alternate adsorbent to CuO.  The present study aims to determine the effects of ammonia on the sulfation of the  sorbent and to obtain a rate expression for the regeneration of alumina-supported CeOz  sorbents. In the past quarter the effect of fly-ash, ammonia, and water on the sulfation of  the sorbent was investigated. The analysis of the economics of a commercial scale ceria  process has been sub-contracted to TECOGEN. This work has been completed and the  report has been received.

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Blast Furnace Granular Coal Injection Projection

This 1997 annual report describes the Blast Furnace Granular Coal Injection project being implemented at the Burns Harbor Plant of Bethlehem Steel Corporation. The project is receiving cost-sharing from the U.S. Department of Energy (DOE), and is being administrated by the Morgantown Energy Technology Center in accordance with the DOE Cooperative Agreement No. DE-FC21-91MC27362.  This installation is the first in the United States to use British Steel technology1*2 that uses granular coal to provide a portion of the fuel requirements of blast furnaces. The project will demonstrate/assess a broad range of technical and economic issues associated with the use of coal for injection into blast furnaces. To achieve the progmm objectives, the demonstration project is divided into the following three Phases:  Phase I -  Design Phase II -   Construction Phase III -  Operation  Preliminary Design (Phase 1) began in 1991 with detailed design commencing in 1993. Construction at the Burns Harbor Plant (Phase II) began in August 1993 and was completed at the end of 1994. The demonstration test program (Phase III) started in the fourth quarter of 1995.

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Slag Characterization and Removal Using Pulse Detonation Technology During Coal Gasification

The main activity in the first quarter of 1998 was concentrated on understanding the detonation code, so that it can be linked with the in-house CFD code NPARC for simulation. The objective is to obtain the velocity and pressure distribution inside the detonation tube and compare with the experimental data that we have obtained from the experiments. Once the code is validated, the simulation will be extended to obtain the pressure and velocity fields in the large chamber, i.e., outside the exit of the detonation tube where the slag samples are attached.

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Commercial-Scale Demonstration of the Liquid Phase Methanol (LPMEOH) Process

he Liquid Phase Methanol (LPMEOW) Demonstration Project at Kingsport Tennessee, is a $213.7 million cooperative agreement between the U.S. Department of Energy (DOE) and Air Products Liquid Phase Conversion Company, L.P. (the Partnership) to produce methanol from coal-derived synthesis gas (syngas). Air Products and Chemicals, Inc. (Air Products) and Eastman Chemical Company (Eastman) formed the Partnership to execute the Demonstration Project. The LPMEOEP Process Demonstration Unit was built at a site located at the Eastman coal-to-chemicals complex in Kingsport.  The LPMEOHW Demonstration Facility completed its first year of operation on 02 April 1998. The LPMEOW Demonstration Facility also completed the longest continuous operating run (65 days) on 21 April 1998.  Catalyst activity, as defined by the ratio of the rate constant at any point in time to the rate constant for freshly reduced catalyst (as determined in the laboratory autoclave), was monitored throughout the reporting period. During a six-week test at a reactor temperature of 225oC and Balanced Gas flowrate of 700 KSCFH, the rate of decline in catalyst activity was steady at 0.29-0.36% per day. During a second one-month test at a reactor temperature of 220oC and a Balanced Gas flowrate of 550-600 KSCFH, the rate of decline in catalyst activity was 0.4% per day, which matched the pefiorrnance at 225"C, as well as the 4-month proof-of-concept run at the LaPorte AFDU in 1988/89.  Beginning on 08 May 1998, the LPMEOW Reactor temperature was increased to 235oC, which was the operating temperature tier the December 1997 restart with the fresh charge of catalyst (50'Yo of design loading). The flowrate of the primary syngas feed stream (Balanced Gas) was also increased to 700-750 KSCFH. During two stable operating periods between 08 May and 09 June 1998, the average catalyst deactivation rate was 0.8% per day. Due to the scatter of the statistical analysis of the results, this test was extended to better quanti& the catalyst aging behavior. During the reporting perio~ two batches of fresh catalyst were activated and transferred to the reactor (on 02 April and 20 June 1998). The weight of catalyst in the LPMEOW Reactor has reached 80% of the design value.  At the end of the reporting period, a step-change in the pressure-drop profile within the LPMEOW Reactor and an increase in the pressure of the steam system which provides cooling to the LPMEOW Reactor were observed. No change in the calculated activity of the catalyst was detected during either of these transients. These parameters will be monitored closely for any additional changes.

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Design and Fabrication of the First Commercial-Scale Liquid Phase Methanol (LPMEOH) Reactor

The Liquid Phase Methanol (LPMEOHT) process uses a slurry bubble column reactor to convert synthesis gas (syngas), primarily a mixture of carbon monoxide and hydrogen, to methanol. Because of its superior heat management the process can utilize directly the carbon monoxide (CO)-rich syngas characteristic of the gasification of coal, petroleum coke, residual oil, wastes, or other hydrocarbon feedstocks.  The LPMEOHM Demonstration Project at Kingsport, Tennessee, is a $213.7 million cooperative agreement between the U.S. Department of Energy (DOE) and Air Products Liquid Phase Conversion Company, L.P., a partnership between Air Products and Chemicals, Inc. and Eastman Chemical Company, to produce methanol from coal-derived syngas. Construction of the LPMEOH~ Process Demonstration Plant at Eastman's chemicals-from-coal complex in Kingsport was completed in January 1997. Following commissioning and shakedown activities, the fwst production of methanol from the facility occurred on April 2, 1997. Nameplate capacity of 260 short tons per day (TPD) was achieved on April 6, 1997, and production rates have exceeded 300 TPD of methanol at times.  This report describes the design, fabrication, and installation of the Kingsport LPMEOEFM reactor, which is the first commercial-scale LPMEOEPM reaetor ever built. The vessel is 7.5 feet in diameter and 70 feet tall with design conditions of 1000 psig at 600 `F. These dimensions represent a significant scale-up from prior experience at the DOE-owned Alternative Fuels Development Unit in LaPorte, Texas, where 18-inch and 22-inch diameter reactors have been tested successfidly over thousands of hours. The biggest obstacles discovered during the scale- up, however, were encountered during fabrication of the vessel. The lessons learned during this process must be considered in tailoring the design for future sites, where the reactor dimensions may grow by yet another factor of two.

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Enahancing the Use of Coals by Gas Reburning - Sorbent Injection Volume 5 - Guideline Manual

The purpose of the Guideline Manual is to provide recommendations for the application of combined gas reburning-sorbent injection (GR-SI) technologies to pre-NSPS boilers. The manual includes design recommendations, performance predictions, economic projections and comparisons with competing technologies. The report also includes an assessment of boiler impacts. Two full-scale demonstrations of gas reburning-sorbent injection form the basis of the Guideline Manual.   Under the U.S. Department of Energy's Clean Coal Technology Program (Round 1), a project was completed to demonstrate control of boiler emissions that comprise acid rain precursors, specifically oxides of nitrogen (NOX) and sulfur dioxide (S02). Other project sponsors were the Gas Research Institute and the Illinois State Department of Commerce and Community Affairs.   The project involved demonstrating the combined use of Gas Reburning and Sorbent Injection (GR-SI) to assess the air emissions reduction potential of these technologies.. Three potential coal-fired utility boiler host sites were evaluated: Illinois Power's tangentially-fired 71 MWe (net) Hennepin Unit W, City Water Light and Power's cyclone- fired 33 MWe (gross) Lakeside Unit #7, and Central Illinois Light Company's wall-fired 117 MWe (net) Edwards Unit #1. Commercial demonstrations were completed on the Hennepin  and Lakeside Units. The Edwards Unit was removed from consideration for a site  demonstration due to retrofit cost considerations.   Gas Reburning (GR) controls air emissions of NOX. Natural gas is introduced into the furnace hot flue gas creating a reducing reburning zone to convert NOX to diatomic nitrogen (N,). Overfire air is injected into the furnace above the reburning zone to complete the combustion of the reducing (fuel) gases created in the reburning zone. Sorbent Injection (S1) consists of the injection of dry, calcium-based sorbents into furnace hot flue gas to achieve S02 capture.  At each site where the techno!o@es were to be demonstrated, petiormance goals were set to achieve air emission reductions of 60 percent for NO. and 50 percent for SO2. These performance goals were exceeded during long term demonstration testing. For the tangentially fired unit, NOX emissions were reduced by 67.2% and S02 emissions by  52.6%. For the cyclone-fired unit, NOX emissions were reduced by 62.9% and SOZ emissions by 57.9%.

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Improved Oil Recovery In Fluvial Dominated Deltaic Reservoirs of Kansas - Near Term

Common oil field problems exist in fluvial dominated deltaic reservoirs in Kansas. The problems are poor waterflood sweep efficiency and lack of reservoir management. The poor waterflood sweep efficiency is due to (1) reservoir heterogeneity, (2) channeling of injected water through high permeability zones or fractures, and (3) clogging of injection wells due to solids in the injection water. In many instances the lack of reservoir management results from (1) poor data collection and organization, (2) little or no integrated analysis of existing data by geological and engineering personnel, (3) the presence of multiple operators within the field, and (4) not identifying optimum recovery techniques. Two demonstration sites operated by different independent oil operators are involved in this project. The Stewart Field is located in Finney County, Kansas and is operated by PetroSantander, Inc. This field was in the latter stage of primary production at the beginning of this project and is currently being waterflooded as a result of this project. The Nelson Lease (an existing waterflood) is located in Allen County, Kansas, in the N.E. Savonburg Field and is operated by James E. Russell Petroleum, Inc. The objective is to increase recovery efficiency and economics in these types of reservoirs. The technologies being applied to increase waterflood sweep efficiency are (1) in situ permeability modification treatments, (2) infill drilling, (3) pattern changes, and (4) air flotation to improve water quality. The technologies being applied to improve reservoir management are (1) database development, (2) reservoir simulation, (3) transient testing, (4) database management, and (5) integrated geological and engineering analysis.

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Healy Clean Coal Project

The Healy Clean Coal Project, selected by the U.S. Department of Energy under Round 111 of the Clean Coal Technology Program, has been constructed and is currently in the Phase 111 Demonstration Testing. The project is owned and financed by the Alaska  Industrial Development and Export Authority (AIDEA), and is cofunded by the U.S. Department of Energy. Construction was 100% completed in mid-November of 1997,  with coal firing trials starting in early 1998. Demonstration testing and reporting of the  results will take place in 1998, followed by commercial operation of the facility. The  emission levels of nitrogen oxides (NOx), sulfur dioxide (S02), and particulate from this 50-megawatt plant are expected to be significantly lower than current standards.

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Clean Coal III Project: Blast Furnace Granular Coal Injection Project Trial 1 Report - Blast Furnace Granular Coal Injection - Results with Low Volatile Coal

This report describes the first coal trial test conducted with the Blast Furnace Granular Coal Injection System at Bethlehem Steel Corporation's Burns Harbor Plant. This demonstration project is divided into three phases:  Phase I - Design  Phase II - Construction  Phase III - Operation  The design phase was conducted in 1991-1993. Construction of the facility began in August 1993 and was completed in late 1994. The coal injection facility began operating in January 1995 and Phase III began in November 1995.  The Trial 1 base test orI C furnace was carried out in October 1996 as a comparison period for the analysis of the operation during subsequent coal trials.

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Commercial-Scale Demonstration of the Liquid Phase Methanol (LPMEOH(TM)) Process

The Liquid Phase Methanol (LPMEOHT") demonstration project at Kingsport, Tennessee, is a $213.7 million cooperative agreement between the U.S. Department of Energy (DOE) and Air Products Liquid Phase Conversion Company, L. P. (the Partnership). Air Products and Chemicals, Inc. (Air Products) and Eastman Chemical Company (Eastman) formed the Partnership to execute the Demonstration Project. A demonstration unit producing 80,000 gallons per day (260 tons-per-day) of methanol from coal-derived synthesis gas (syngas) was designed, constructed, and is operating at a site located at the Eastman complex in Kingsport. The Partnership will own and operate the facility for the four-year demonstration period.  This project is sponsored under the DOE's Clean Coal Technology Program, and its primary objective is to "demonstrate the production of methanol using the LPMEOWM Process in conjunction with an integrated coal gasification facility." The project will also demonstrate the suitability of the methanol produced for use as a chemical feedstock or as a low-sulfur dioxide, low-nitrogen oxides alternative fiel in stationary and transportation applications. The project may also demonstrate the production of dimethyl ether (DME) as a mixed coproduct with methanol, if laboratory- and pilot-scale research and market verification studies show promising results. If implemented, the DME would be produced during the last six months of the four-year demonstration period.  The LPMEOITM process is the product of a cooperative development effort by Air Products and the DOE in a program that started in 1981. It was successfdly piloted at a 10 tons-per- day (TPD) rate in the DOE-owned experimental unit at Air Products'LaPorte, Texas, site. This demonstration project is the culmination of that extensive cooperative development effort.

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Commercial-Scale Demonstration of the Liquid Phase Methanol (LOMEOH(TM)) Process

The Liquid Phase Methanol (LPMEOH) Demonstration Project at Kingsport, Tennessee, is a $213.7 million effort being conducted under a cooperative agreement between the U.S. Department of Energy (DOE) and Air Products Liquid Phase Conversion Company, L.P. (the Partnership). Air Products and Chemicals, Inc. (Air Products) and Eastman Chemical Company (Eastman) formed the Partnership to execute the Demonstration Project. A demonstration unit producing 80,000 gallons per day (260 tons-per-day (TPD)) of methanol from coal-derived synthesis gas (syngas) was designed, constructed, and began a four-year operational period in April of 1997 at a site located at the Eastman complex in Kingsport. The Partnership will own and operate the facility for the four-year demonstration period.  This project is sponsored under the DOE's Clean Coal Technology Program, and its primary objective is to "demonstrate the production of methanol using the LPMEOH?M Process in conjunction with an integrated coal gasification facility." The project will also demonstrate the suitability of the methanol produced for use as a chemical feedstock or as a low-sulfur dioxide, low-nitrogen oxides alternative fiel in stationary and transportation applications. The project may also demonstrate the production of dimethyl ether (DME) as a mixed coproduct with methanol, if laboratory- and pilot-scale research and market verification studies show promising results. If implemented, the DME would be produced during the last six months of the four-year demonstration period.  The LPMEOJYM process is the product of a cooperative development effort by Air Products and the DOE in a program that started in 1981. It was successfidly piloted at a 10-TPD rate in the DOE-owned experimental unit at Air Products'LaPorte, Texas, site. This Demonstration Project is the culmination of that extensive cooperative development effort.

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Enhancing the Use of Coals by Gas Reburning - Sorbent Injection Volume 5 - Guideline Manual

The purpose of the Guideline Manual is to provide recommendations for the application of combined gas reburning-sorbent injection (GR-SI) technologies to pre-NSPS boilers. The manual includes design recommendations, performance predictions, economic projections and comparisons with competing technologies. The report also includes an assessment of boiler impacts. Two full-scale demonstrations of gas reburning-sorbent injection form the basis of the Guideline Manual. Under the U.S. Department of Energy's Clean Coal Technology Program (Round 1), a project was completed to demonstrate control of boiler emissions that comprise acid rain precursors, specifically oxides of nitrogen (NOX) and sulfur dioxide (S02). Other project sponsors were the Gas Research Institute and the Illinois State Department of Commerce and Community Affairs. The project involved d,emonstrating the combined use of Gas Reburning and Sorbent Injection (GR-SI) to assess the air emissions reduction potential of these technologies.. Three potential coal-fired utility boiler host sites were evaluated: Illinois Power's tangentially-fired 71 MWe (net) Hennepin Unit #1, City Water Light and Power's cyclone- fired 33 MWe (gross) Lakeside Unit #7, and Central Illinois Light Company's wall-fired 117 MWe (net) Edwards Unit #1. Commercial demonstrations were completed on the Hennepin and Lakeside Units. The Edwards Unit was removed from consideration for a site demonstration due to retrofit cost considerations. Gas Reburning (GR) controls air emissions of NOX. Natural gas is introduced into the furnace hot flue gas creating a reducing reburning zone to convert NOX to diatomic nitrogen (N,). Overfire air is injected into the furnace above the reburning zone to complete the combustion of the reducing (fuel) gases created in the reburning zone. Sorbent Injection (S1) consists of the injection of dry, calcium-based sorbents into furnace hot flue gas to achieve S02 capture. `At each site where the technologies were to be demonstrated, performance goals were set to achieve air emission reductions of 60 percent for NOX and 50 percent for S02. These performance goals were exceeded during long term demonstration testing. For the tangentially fired unit, NO, emissions were reduced by 67.2?40 and SOZ emissions by 52.6Y0. For the cyclone-fired unit, NO, emissions were reduced by 62.9% and SOZ emissions by 57.9Y0.

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Post-Injection Geophysical Evaluation of the Winding Ridge Site CRADA 98-F012, Final Report

Acid mine drainage (AMD) from underground mines is a major environmental problem. The disposal of coal combustion by-products (CCB) is also a major national problem due to the large volumes produced annually and the economics associated with transportation and environmentally safe disposal. The concept of returning large volumes of the CCB to their point of origin, underground mines, and using the typically alkaline and pozzolanic attributes of the waste material for the remediation of AMD has been researched rather diligently during the past few years by various federal and state agencies and universities. As the result, the State of Maryland initiated a full-scale demonstration of this concept in a small, 5-acre, unmapped underground mine located near Friendsville, MD.  Through a cooperative agreement between the State of Maryland and the U.S. Department of Energy, several geophysical techniques were evaluated as potential tools for the post-injection evaluation of the underground mine site. Three non-intrusive geophysical surveys, two electromagnetic (EM) techniques and magnetometry, were conducted over the Frazee Mine, which is located on Winding Ridge near Friendsville, MD. The EM surveys were conducted to locate ground water in both mine void and overburden. The presence of magnetite, which is naturally inherent to CCB'S due to the combustion process and essentially transparent in sedimentary rock, provided the reason for using magnetometry to locate the final resting place of the CCB grout.

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