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Midwest Independent Transmission System Operator, Inc. (MISO) is a nonprofit regional transmission organization (RTO) that oversees electricity production and transmission across 13 states and 1 Canadian province. MISO also operates an electronic exchange for buying and selling electricity for each of its five regional hubs.

MISO oversees two types of markets. The forward market, which is referred to as the day-ahead (DA) market, allows market participants to place demand bids and supply offers on electricity to be delivered at a specified hour the following day. The equilibrium price, known as the locational marginal price (LMP), is determined by MISO after receiving sale offers and purchase bids from market participants. MISO also coordinates a spot market, which is known as the real-time (RT) market. Traders in the RT market must submit bids and offers by 30minutes prior to the hour for which the trade will be executed. After receiving purchase and sale offers for a given hour in the RT market, MISO then determines the LMP for that particular hour.

The existence of the DA and RT markets allows producers and retailers to hedge against the large fluctuations that are common in electricity prices. Hedge ratios on the MISO exchange are estimated using various techniques. No hedge ratio technique examined consistently outperforms the unhedged portfolio in terms of variance reduction. Consequently, none of the hedge ratio methods in this study meet the general interpretation of FASB guidelines for a highly effective hedge.

We consider the partial hedging of stochastic electricity load pattern with static forward strategies. We assume that the company under consideration maximizes the risk adjusted expected value of its electricity cash flows. First, we calculate an optimal hedge ratio and after that we use this hedge ratio to solve the optimal hedging time. Our results indicate, for instance that agents with high load volatility hedge later than agents that have low load volatility. Moreover, negative correlation between forwards and electricity load pattern postpones the hedging timing.

The forward curve dynamics in the Nordic electricity market is examined. Six years of price data on futures and forward contracts traded in the Nordic electricity market are analysed. For the forward price function of electricity, we specify a multi‐factor term structure models in a Heath‐Jarrow‐Morton framework. Principal component analysis is used to reveal the volatility structure in the market. A two‐factor model explains 75 per cent of the price variation in our data, compared to approximately 95 per cent in most other markets. Further investigations show that correlation between short‐ and long‐term forward prices is lower than in other markets. We briefly discuss possible reasons why these special properties occur, and some consequences for hedging exposures in this market.

This chapter focuses on the common occurrence of wholesale electricity prices that fall below the cost of production. This “negative pricing” in effect represents payment to high-volume consumers for taking excess power off the grid, thus relieving overload. Occurrences of negative pricing have been observed since the wholesale electricity markets have been operating, and occur during periods of low demand, while generators are being kept in reserve for rapid engagement when demand increases (it is expensive and time-consuming to shut down generators and then restart them, so they are often kept in “spooling mode”). In such situations power production may temporarily exceed demand, potentially overloading the system. When the federal government began subsidizing the construction of wind generation projects, with regulations in place requiring transmission grids to accept all of the electricity produced by the wind generators, negative pricing became more frequent.

This chapter examines the efficiency of the Midcontinent Independent System Operator (MISO), Inc., electricity exchange following its major expansion in terms of market participants and geographic scope in 2014. Specifically, hourly day-ahead (forward) and real-time (spot) prices from 2014 to 2016 reveal that forward premiums are prevalent despite the increase in market size. Furthermore, these forward premiums do not adhere to Bessembinder and Lemmon’s (2002) commonly used general equilibrium model for electricity forward premia. A technical trading rule based on the relationship between day-ahead prices across hubs that was found to be profitable prior to MISO’s expansion still produces economically and statistically significant returns after the exchange’s growth.

This study aims to formulate a mechanism design in the derivatives market, summarizing a framework to set up the Brazilian electricity futures market.

This exploratory study formulates a mechanism design in the derivatives market, summarizing a framework to set up the Brazilian electricity futures market.

The results show a positive economic outcome for the creation of the Brazilian futures electricity market.

The main feature in this work is to summarize a framework to set up the Brazilian electricity futures market applying mechanism design, applicable in other countries. The features of the mechanism are the space of expected results (Z), the strategies to survey the environmental space (θ) and the mechanism design – messages space (M).

The purpose of this paper is to investigate the gaming equilibrium among fossil‐fueled generation companies (GenCos), wind generation companies, the grid company and customers participating in an emission trading (ET) market and the day‐ahead electricity market.

The complementarity method is used in this work to obtain the Nash equilibrium. By combining the Karush‐Kuhn‐Tucker (KKT) conditions of each kind of market participants with market clearing and consistency conditions, a mixed linear complementarity problem could be established.

Simulation results show that: the enforcement of ET could increase the share of generation outputs of wind generation units, and decrease the emissions from fossil‐fueled generation units; the bilateral contracts between GenCos and customers could limit the ability of exercising market power by GenCos; and when the emissions allowances allocated by the government shrink, the price of emissions allowance will increase and as the result the dispatching order of fossil‐fueled generation units will change, and the shares of generation outputs from wind generation units and combined‐cycle gas turbines increase. However, it should be mentioned that because the cost of wind generation is still very high, the increase of the share from wind generation units in the electricity market should mainly rely on cost reduction rather than the enforcement of ET.

The original contribution and the value of this study lie in developing a model framework to explore the gaming equilibrium that thermal and wind generating plants both play in the emissions trading environment and electricity market.

This paper seeks to analyze stylized statistical properties of the recent traded asset CO₂ emission allowances, for spot and futures returns, examining also the relation linking convenience yield and risk premium, for the German European Energy Exchange (EEX) between October 2005 and October 2009.

The study was conducted through empirical estimations of CO₂ allowances risk premium, convenience yield, and their relationships.

Future prices from an ex-post perspective are examined to show evidence for significant negative risk premium, or a positive forward premium. A positive relationship between risk premium and time-to-maturity is found. Both financial concepts are found to be negatively affected by spot price volatility. Convenience yield is positively influenced by CO₂ price, while influencing the risk premium positively.

From a financial perspective, allowances seem to be producing the desired effects in terms of environmental policies, although a lot more remains to be done. The presence of risk premium and convenience yield makes it clear that agents act in this commodity market according to risk consideration. Results change depending on phase and futures contracts used for the determination of both financial terms, indicating that uncertainties over the future of EU-ETS seem to be decreasing.

Previous research has mainly focused on the first phase of the EU-ETS (2005-2007), whereas this paper extends the analysis period here. The paper finds some opposite results compared with previous commodities theories and designs some policy implications, given the results attained.

The purpose of this paper is to present the Business Strategy Assessment Model (BSAM) approach, in an attempt to explore the principle dynamics of an energy‐economic system with emphasis on the private actors' point of view and the impact different policy instruments may have on the decisions of private actors with different characteristics.

In the BSAM model, investment decisions under consideration depend on their perceived financial value. Basis for the financial valuation of an investment option is formed by simulating market dynamics with alternative price scenarios. The outputs include: investment strategies, derived as a function of the (uncertain) state vector of future market conditions and risk premium, calculated by contrasting the expected net present value for the optimal timing of the investment and the expected net present value of an immediate investment generation module of the BSAM, while both of these outputs are estimated for each available technology option.

Different models make different assumptions shedding light upon different aspects of the socio‐economic systems they attempt to analyze and hitherto, no such model succeeds in incorporating all the perceptions that are driving the integration of energy policies. BSAM is based on the notion that a convergence between policy evaluation and business strategy assessment models could be truly beneficial for regulators that aim to derive effective energy policies. Both the algorithm adopted and the structure of the modules of BSAM facilitate the analysis of complex interactions in a firm's decision making process, and even more the what‐if analyses needed for alternative policy measure evaluation.

Setting the framework for a modelling approach that incorporates the role of risk‐return perceptions of private actor's with diverse features, portfolio effects, path dependence and agent competition, into appraising energy and climate policies, and suggest that the heterogeneous world of investors requires reflexive assessment techniques. Above and beyond, understanding the drivers and triggers of firm's investment strategies will allow improving the effectiveness of energy policies.