Cogeneration computer model assessment: Advanced cogeneration research study

Cogeneration computer simulation models to recommend the most desirable models or their components for use by the Southern California Edison Company (SCE) in evaluating potential cogeneration projects was assessed. Existing cogeneration modeling capabilities are described, preferred models are identified, and an approach to the development of a code which will best satisfy SCE requirements is recommended. Five models (CELCAP, COGEN 2, CPA, DEUS, and OASIS) are recommended for further consideration

Specifications for modelling fuel cell and combustion-based residential cogeneration device within whole-building simulation programs

This document contains the specifications for a series of residential cogeneration device models developed within IEA/ECBCS Annex 42. The devices covered are: solid oxide and polymer exchange membrane fuel cells (SOFC and PEM), and internal combustion and Stirling engine units (ICE and SE). These models have been developed for use within whole-building simulation programs and one or more of the models described herein have been integrated into the following simulation packages: ESP-r, EnergyPlus, TRNSYS and IDA-ICE. The models have been designed to predict the energy performance of cogeneration devices when integrated into a residential building (dwelling). The models account for thermal performance (dynamic thermal performance in the case of the combustion engine models), electrochemical and combustion reactions where appropriate, along with electrical power output. All of the devices are modelled at levels of detail appropriate for whole-building simulation tools

Electric utility forecasting of customer cogeneration and the influence of special rates

Cogeneration, or the simultaneous production of heat and electric or mechanical power, emerged as one of the main components of the energy conservation strategies in the past decade. Special tax treatment, exemptions from fuel use restrictions, and regulatory policy changes were crafted to encourage its more wide-spread adoption in anticipation of higher energy conversion efficiencies. The expansion of cogeneration still faces a broad spectrum of problems, current and future: environmental restrictions; capital constraints; fuel prices; utility rates and future utility economics; and the difficulties of management.The most debated issue has been the reform of rates between individual cogenerators and the local electric utility. Many of the major cogeneration studies in the late 1970's urged an analysis of the exact impact from current electric utility rates upon cogeneration project economics (1,2,3). The changes mandated by the Public Utilities Regulatory Policy Act of 1978 (PURPA) are now reaching the final implementation stage and the cogeneration projects of the mid- 1970s are nearing completion. To better understand the relationship between utility rates, the economics of cogeneration, and its potential development, the New England Electric System and the Massachusetts Institute of Technology Energy Laboratory Utility Systems Group began a study to refine methods for forecasting cogeneration in a specific utility service area with special attention devoted to the utility rates (4).This paper surveys the insights gained from this effort, which is now nearing completion. Many of the central issues reflect conditions in New England, but this analysis should provide an approach for examining the question in other regions as well. Since the project has not undergone complete review, however, this paper reflects the opinions of the author alone

A Simple Solution for the Thorny Problem of Park Protection: Focusing on Alternatives

116 pages (includes illustrations). Contains footnotes and references. Contains 3 attachments: 1) Article titled, No Park Is an Island: A Simple Solution for the Thorny Problem of Park Protection, by David Mastbaum, from Resource Law Notes, Natural Resources Law Center. 2) Paper titled, National Park Service War Work: December 7, 1941 to June 30, 1944 prepared by National Park Service. 3) Paper titled, An Alternative to the Allen-Warner Valley Energy System: A Technical and Economic Analysis, by The Environmental Defense Fund, July 1980

Adaptive Nonlinear Optimization Methodology For Installed Capacity Decisions In Distributed Energy/Cooling Heat And Power Applications.

Evaluation of potential cooling, heating and power (CHP) applications requires an assessment of the operations and economics of a particular system in meeting the electric and thermal demands of a specific end-use facility. Given the electrical and thermal load behavior of a facility, the tariff structure for grid-supplied electricity, the price of primary fuel (e.g., natural gas), the operating strategy and characteristics of the CHP system, and an assumed set of installed CHP system capacities (e.g., installed capacity of prime mover and absorption chiller), one can determine the cost of such a system as compared to reliance solely on traditional, grid-supplied electricity and on-site boilers. It has been shown previously in the literature that net present value cost savings of CHP systems exhibit a concave behavior with respect to installed capacity, and thus, an optimum size exists for a given application. To date, current capacity selection techniques either utilize simple enumeration of candidate choices, heuristic multipliers of the base or peak demand, or apply optimization algorithms on aggregated or averaged demand data. None of these approaches are likely to result in economic optimality. This research utilizes hour-by-hour operation simulation of CHP systems to calculate life-cycle net present value (NPV) savings. Based on maximizing an NPV cost savings objective function, a nonlinear optimization algorithm is used to determine economically optimal CHP system equipment capacities. This research contributes an improved mechanism that will identify economic optimum capacities for CHP system equipment, thereby producing optimal cost benefits and potentially avoiding economic losses

Distribution automation applications of fiber optics

Motivations for interest and research in distribution automation are discussed. The communication requirements of distribution automation are examined and shown to exceed the capabilities of power line carrier, radio, and telephone systems. A fiber optic based communication system is described that is co-located with the distribution system and that could satisfy the data rate and reliability requirements. A cost comparison shows that it could be constructed at a cost that is similar to that of a power line carrier system. The requirements for fiber optic sensors for distribution automation are discussed. The design of a data link suitable for optically-powered electronic sensing is presented. Empirical results are given. A modeling technique that was used to understand the reflections of guided light from a variety of surfaces is described. An optical position-indicator design is discussed. Systems aspects of distribution automation are discussed, in particular, the lack of interface, communications, and data standards. The economics of distribution automation are examined

Hydrogen and fuel cell technologies for heating: A review

The debate on low-carbon heat in Europe has become focused on a narrow range of technological options and has largely neglected hydrogen and fuel cell technologies, despite these receiving strong support towards commercialisation in Asia. This review examines the potential benefits of these technologies across different markets, particularly the current state of development and performance of fuel cell micro-CHP. Fuel cells offer some important benefits over other low-carbon heating technologies, and steady cost reductions through innovation are bringing fuel cells close to commercialisation in several countries. Moreover, fuel cells offer wider energy system benefits for high-latitude countries with peak electricity demands in winter. Hydrogen is a zero-carbon alternative to natural gas, which could be particularly valuable for those countries with extensive natural gas distribution networks, but many national energy system models examine neither hydrogen nor fuel cells for heating. There is a need to include hydrogen and fuel cell heating technologies in future scenario analyses, and for policymakers to take into account the full value of the potential contribution of hydrogen and fuel cells to low-carbon energy systems

A review of the Energy Productivity Center's Least-Cost Energy Strategy study

The Mellon Institute's Energy Productivity Center (EPC) has recently completed a study asking the question, "How would the nation have provided energy services in 1978 if its capital stock had een reconfigured to be optimal for actual 1978 energy prices?" Interest in this question is motivated by the unanticipated increases in oil prices since 1973. If policy makers are to learn from history it is important to know what would have happened if the increases in energy prices had been foreseen and if the nation had taken full advantage of that knowledge to minimize costs.EPC concludes that if the 1978 capital stock had been transformed in conformance with a least-cost principal for providing energy services, then, given actual 1978 energy prices and energy service demands, per capita energy service costs would have been reduced by 17%. Market shares of the various energy types would also have been affected substantially. For example, while the gas share of total energy service demand would have increased slightly from actual 1978 levels, the share of purchased electricity would have fallen from 30% to 17% of total energy service demand, and improvements in energy efficiency would have increased from 10% to 32%.EPC's findings have received considerable attention, both from the press and from policy makers. EPC interprets its results as indicating "... the direction in which we coul move to begin realizing some of the benefits of a least-cost strategy." The purpose of this report is to assess and evaluate the EPC methodology, data base, and results. Here we briefly summarize our principal findings

Exploring New Energy Choices for California: The 1980-81 Report to the Legislature

State law requires that the California Energy Commission develop and coordinate a program of research and development (R&D) in energy supply, consumption, and conservation and the technology of siting research and development priority to those forms of research and development (Public Resources Code Section 25601). Accordingly, the Commission\u27s R&D program addresses a number of energy-re ated matters, including expansion and accelerated development of alternative sources of energy, such as geothermal, wind and solar resources, improved methods of energy conservation, increased energy efficiency in existing thermal electric and hydroelectric facilities, and advanced methods of energy demand forecasting. The statute further directs the Commission to submit to the Governor and the Legislature, an integrated program of proposed R&D and technical assistance projects ••• and describe in detail the progress of its programs. (Public Resources Code Section 25604). In June 1979, the Commission released the 1979/80 R&D Report to the Legislature, Exploring New Energy Choices for California, which described the progress of the past, present and proposed research and development activities in achieving state energy program goals and priorities. That report established the historical development and progress of the Commission\u27s R&D program and presented an item-by-item description of each Commission project which can be characterized as an R&D activity. As such, the 1979/80 report will serve as the base document for historical and policy purposes. This report responds to this mandate by presenting the rationale for the Commission\u27s current and proposed R&D and commercialization program activities and supplementing the program descriptions provided in the proposed Energy Commission Budget for Fiscal Year 1980-81. The 1980/81 annual report also updates the information in last year\u27s report by highlighting significant program changes that may have occurred and identifying future program directions. For a more complete description of the evolution of the Commission\u27s R&D activities, we refer the reader to Volumes I and II of last year\u27s annual report