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| Fig. 1: Average monthly wholesale electricity prices in California, 1998-2001. The figure illustrates the rapid escalation of wholesale electricity prices beginning in early 2000. (Image source: A. Liang, after Bushnell. [4]) |
Between 2000 and 2001, California experienced one of the most severe energy crises in U.S. history, resulting in rolling blackouts, utility bankruptcies, and an estimated $40-45 billion in economic losses. While the goal of Assembly Bill 1890 (AB 1890) was to lower electricity prices by introducing competition into the retail electricity market, its structural flaws, combined with supply constraints and market manipulation, triggered a collapse that exposed vulnerabilities in deregulated power markets.
For nearly a century, Californias electricity sector was dominated by three investor-owned utilities (IOUs): Pacific Gas and Electric (PG&E), Southern California Edison (SCE), and San Diego Gas and Electric (SDG&E). These vertically integrated monopolies controlled generation, transmission, and distribution, with rates regulated by the California Public Utilities Commission (CPUC).
By the early 1990s, industrial customers argued that electricity prices were inflated due to high capital costs from nuclear power investments, long-term contracts, and excess capacity. In 1994, the CPUCs Blue Book proposed restructuring the industry to create a competitive wholesale electricity market. Two years later, AB 1890 was enacted, introducing two key institutions: California Power Exchange (CalPX), which managed the day-ahead electricity market, and the California Independent System Operator (CAISO), which oversaw real-time grid operations.
To promote competition, IOUs were required to divest generation assets and purchase nearly all their electricity through CalPX. Retail rates, however, were frozen at approximately $65/MWh for up to four years. Policymakers expected wholesale market prices to remain around $30/MWh. [1]
While the fixed retail price initially seemed attractive, it proved unsustainable once wholesale market prices began to surge. In 1999, average wholesale prices hovered around $30/MWh. By mid-2000, prices exceeded $300/MWh, an increase of 900%. [1] Fig. 1 shows the rapid escalation of average wholesale electricity prices from 1998 through 2002.
As Fig. 1 illustrates, wholesale prices remained stable until early 2000, then spiked dramatically through the summer of 2000 and winter of 2001. This created a widening gap between wholesale purchase costs and the retail price freeze, forcing utilities to sell electricity at steep losses.
The market design of AB 1890 created conditions ripe for manipulation. Because IOUs were required to buy most power through CalPX, generators could bid strategically. FERC's 2003 investigation documented multiple generators engaging in economic withholding and strategic bidding practices that amplified price volatility. These tactics, while profitable to traders, deepened shortages and amplified price volatility across the grid.
By late 2000, PG&E and SCE were paying $400/MWh in the wholesale market but could charge only $65/MWh at retail, losing nearly $50 million per day. Between 2000 and 2001, wholesale power costs in California rose from $7.4 billion to roughly $27 billion per year. [2] PG&E filed for bankruptcy in April 2001, reporting over $9 billion in debt.
In December 2000, repeated Stage 3 Emergencies led to rolling blackouts affecting millions of residents and businesses. FERC implemented wholesale price caps and market mitigation measures in mid-2001, after which prices began to stabilize. Subsequent FERC reports concluded that both supply shortages and flawed market rules enabled generators to exercise market power beyond competitive levels. [3]
The California energy crisis revealed how incomplete deregulation and poor market design can destabilize essential infrastructure. A combination of rigid retail price freezes, mandatory power purchases through centralized markets, inadequate oversight, and strategic supply withholding created a system vulnerable to manipulation.
Beyond the $40-45 billion economic cost, the crisis undermined public trust in energy liberalization and triggered widespread reconsideration of how electricity markets should be structured. The core lesson is that deregulation must be accompanied by safeguards: flexible retail pricing, transparent bidding, diversified procurement, and vigilant regulatory monitoring.
As demand for clean and reliable electricity continues to grow, California's experience underscores that market efficiency and consumer protection must evolve together.
© Anne Liang. The author warrants that the work is the author's own and that Stanford University provided no input other than typesetting and referencing guidelines. The author grants permission to copy, distribute and display this work in unaltered form, with attribution to the author, for noncommercial purposes only. All other rights, including commercial rights, are reserved to the author.
[1] F. A. Wolak, "Diagnosing the California Electricity Crisis," Electr. J. 16, No. 7, 11 (2001).
[2] J. L. Sweeney, The California Electricity Crisis (Hoover Institution Press, 2002).
[3] S. Borenstein, "The Trouble With Electricity Markets: Understanding California's Restructuring Disaster," Journal of Economic Perspectives 16, No. 1, 191 (Winter 2002).
[4] J. Bushnell, "California's Electricity Crisis: A Market Apart?" Energy Policy 32, 1045 (2004).