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Optimal profits under environmental regulation: the benefits from emission intensity averaging

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Abstract

In this paper we analyze the economic effects of implementing EPA’s newly proposed regulations for carbon dioxide (\(\hbox {CO}_2\)) on existing U.S. coal-fired power plants using nonparametric methods on a sample of 144 electricity generating units. Moreover, we develop an approach for evaluating the economic gains from averaging emission intensities among the utilities’ generating units, compared to implementing unit-specific performance standards. Our results show that the implementation of flexible standards leads to up to 2.7 billion dollars larger profits compared to the uniform standards. Moreover, we find that by adopting best practices, current profits can be maintained even if an intensity standard of 0.88 tons of \(\hbox {CO}_2\) per MWh is implemented. However, our results also indicate a trade-off between environmental and profit gains, since aggregate \(\hbox {CO}_2\) emissions are higher with emission intensity averaging than with uniform standards.

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Notes

  1. See https://www.federalregister.gov/articles/2014/06/18/2014-13726/carbon-pollution-emission-guidelines-for-existing-stationary-sources-electric-utility-generating#h-9 for details.

  2. See Song et al. (2012) for a detailed review of the literature on nonparametric analysis of environmental efficiency.

  3. Zhang and Choi (2014) provide a survey on the use of directional distance functions in environmental efficiency analysis.

  4. In our analysis we refer to each generator located at coal-fired plants as a generating unit. Electric utilities are the companies which own the plants and may therefore be owning and operating multiple generating units.

  5. Note that our theoretical discussion can be easily extended to the case of more than two inputs and two outputs. For the sake of notational simplicity we restrict this presentation to our empirical specification.

  6. Emission (recuperation) factors indicate the amount of materials bound in one unit of inputs (outputs).

  7. See e.g. Greene (2008) for a discussion on issues with parametric models containing multiple outputs.

  8. A formal proof of that the equality constraint implies weak disposability of the technology can be found in Färe and Grosskopf (2004, pp. 49–51).

  9. See Färe and Grosskopf (2004) and Hampf and Rødseth (2015) for discussions on convex, variable returns to scale versions of the production models.

  10. The estimated technologies only satisfy the inactivity axiom if an inactive unit is part of the dataset, which is rarely the case given empirical data.

  11. See Welch and Barnum (2009) for a similar methodological approach to a cost and environmental analysis of power plants.

  12. Moreover, due to an optimization approach which is not based on distance functions, the problems discussed by Chen (2014) for the JP model do not arise.

  13. Note that if the ratio of averages is equal to s the average ratio can not be smaller than s since by Jensen’s inequality it follows that \(E(b/y)=E(b)\cdot E(1/y) \ge E(b)\cdot 1/E(y) =E(b)/E(y)\).

  14. For more detailed discussions on network technologies modeling subunits see e.g. Färe and Grosskopf (2000).

  15. Note that in line with the literature on profit efficiency we assume that the prices are not affected by the profit optimization. If demand and supply functions are known, endogenous models (see Johnson and Ruggiero 2011) could be estimated.

  16. See Heshmati et al. (2012) for a discussion of the issues when estimating power plant efficiency with heterogeneous technology sets.

  17. See Färe et al. (2013a) for a discussion on the reduction of the number of observations due to missing data from U.S. power plants.

  18. See Hampf and Rødseth (2015) for more details on the data.

  19. Note that the grid is evaluated for steps of 0.01 tons per MWh.

  20. We define the profits of the generating units given their inefficiencies as the business-as-usual profits.

  21. In principle, cost minimization implies allocating different standards to different fossil fuel types (that on average amount to the EPA standards), in order to equalize marginal abatement costs across different fuel types. Hence, if the fuel-specific abatement costs were known, it would be possible to assign fuel specific performance standards. The emission standard for coal will intuitively be higher than the EPA standard.

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Acknowledgments

We are grateful to Jens Krüger and two anonymous referees for valuable comments. Of course, all remaining errors are ours.

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Correspondence to Benjamin Hampf.

Appendix

Appendix

Proof of the equivalence of the JP and the MB model:

To start consider the profit optimization subject to the non-convex JP model:

(4.1)

In the optimum \(x^P=\sum _{j=1}^n x_j^{P} \lambda _j\) and \(y = \sum _{j=1}^n y_j \lambda _j\theta \) hold since \(x^P\) and y can be freely chosen and \(b=\sum _{j=1}^n b_j \lambda _j\theta \) by construction. Moreover, \(\theta \) can be set equal to one since y and b can be freely chosen. Replacing the modified equalities in the objective function and the regulatory constraint leads to:

(4.2)

The optimization problem under the non-convex MB model is given by:

(4.3)

In this formulation the slack on the good output \(\epsilon _y\) is removed and the equality replaced by an inequality since the output in our analysis (electricity) does not contain any materials. In the optimum \(\epsilon _x=\epsilon _b=0\) since \(x^P\) and b can be freely chosen. Hence, \(x^P=\sum _{j=1}^n x_j^{P} \lambda _j\) and \(b=\sum _{j=1}^n b_j \lambda _j\). Moreover, \(y=\sum _{j=1}^n y_j \lambda _j\) since y can be freely chosen. Replacing these equalities in the objective function and the regulatory constraint leads to:

(4.4)

Therefore, the JP and the MB model lead to the same results for the profit maximization.

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Hampf, B., Rødseth, K.L. Optimal profits under environmental regulation: the benefits from emission intensity averaging. Ann Oper Res 255, 367–390 (2017). https://doi.org/10.1007/s10479-015-2020-4

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