Clean Power Plan Assessment from a Market and Engineering Perspective

Clean Power Plan Assessment from a Market and Engineering Perspective

There are many reviewing the recent EPA – Clean Power Plan.   Many argue from a policy perspective and rarely actually review the details and the numerical results.  In this discussion, I will share with you my initial takeaway from reading the 645 Clean Power Plan along with hundreds of other pages in the Technical Source Document (TSD) plus the Excel files supplied.  In addition, I did use my Power Market Analysis (PMA) model to validate and cross check some of the results.

Let me first give some background to those who do not know me.   I am a Chemical Engineer from the University of Texas at Austin (hook’em horns) by training, however I have spent most of my professional life in analyzing and understanding energy markets (Purvin & Gertz (now IHS), Deloitte Consulting, American Electric Power).  Please don’t hold the American Electric Power experience as a foretold bias on coal.   I have served on the National Renewable Energy Laboratory (NREL) technical advisory panel so I do know the issues and trends of renewable power.   My fellow panel members would vouch for my impartial attitude.  I am a numbers person who holds not personal bias other than the desire to optimize the numbers.   Truth be told, I was a leader in the AEP organization in terms of indicating the need to diversify and support gas investments even as gas markets were soaring, as my groups long-term forecast indicated prices to settle between $5-7/mmbtu for my entire tenure at AEP (2002-2010), to the angst of many AEP colleagues.  My forecasts are not driven by personal biases or political motivation, but the desire to understand and know the markets.  I live by the University of Texas motto “The Truth shall set you free”.

I have approached the Clean Power Plan Assessment in a similar fashion.   I am opened minded on the need and societal desires to be cleaner.   Striving to have a positive or the least negative impact on the earth will always be a good intention.     As long as people are clear on the cost and potential gains, I would not challenge the path society has chosen.

There is so much one can note on a 645 page plan.   The document was repetitive in several places – the ironic thing is on page 581 there is a note on the Paperwork Reduction Act.   I was taking my own notes as I read the document.   My notes ended at 17 pages.   I have reorganized my thoughts to hit the most impactful points first.

I think the very first thought that should rush into everyone minds is the rate focus EPA has.   The EPA, compared to many of the previous emission reduction goals, is now pushing a rate based target (lb/MWh) vs. a tonnage limit as seen in SO2, NOx, and even the initial HG program.   They do offer the option of mass based target, but clearly favor the rate based approach.  This took many nights to truly understand and absorb all the nuances as to why this is the case.  The first thing in order to understand this approach is to understand the rule is focused on EXISTING units and those recently under constructed.  This is a key issue on why the buildings of new gas plants are not listed as an option for Best System of Emission Reduction (BSER).  Currently the new gas plants will likely be limited by section 111(b) of the Clean Air Act (CAA).  “In January 2014, under the authority of CAA section 111(b), the EPA proposed standards for emissions of CO2 from newly constructed fossil fuel-fired electric steam generating units (utility boilers and integrated gasification combined cycle [IGCC] units) and for natural gas-fired stationary combustion turbines.”  The limits proposed for new gas plants would be an achievable solution for 24 states.  The other states will have to go lower than gas plants.   For this reason, I suspect the gas plants were not a BSER solution nor were they discussed for more than a few paragraphs.

The rate method also allows an “easy” way to give value and credit to EE and renewable projects.  There seems to be some conflict in allowing this given the plan currently notes: “Based on the EPA’s application of the BSER to each state, the EPA is proposing to establish, as part of the emission guidelines, state-specific goals,expressed as average emission rates for fossil fuel-fired EGUs.”  However by allowing EE and Renewables to modify the rate calculation, it seems to have conflicted with the above statement.  The argument is made that EE and renewable generation can be attributed to the affected EGU.  “A MWh crediting or adjustment approach implicitly assumes that the avoided CO2 emissions come directly from the particular affected EGU (or group of EGUs) to which the credits are applied”

EPA spent much time focused on their BSER suggestions laid out in four blocks:

“1. Reducing the carbon intensity of generation at individual affected EGUs through heat rate improvements.

2. Reducing emissions from the most carbon-intensive affected EGUs in the amount that results from substituting generation at those EGUs with generation from less carbon-intensive affected EGUs (including NGCC units under construction).

3. Reducing emissions from affected EGUs in the amount that results from substituting generation at those EGUs with expanded low- or zero-carbon generation.

4. Reducing emissions from affected EGUs in the amount that results from the use of demand-side energy efficiency that reduces the amount of generation required.

Based on that evaluation, the EPA proposes that the combination of all four building blocks is the BSER”

The EPA first BSER seems to be somewhat of a red herring.   They spent quite some effort only to conclude a small impact.   I oversaw a paper on power plant efficiency for the National Petroleum Council Hard Truths.  A very similar conclusion is shown in that only a few percentages are likely to come from an existing unit improvement.  This impact is the smallest by many percentages compared to blocks 2-4.  I do have concerns in their extrapolation for opportunities for improvement in the existing US coal fleet.   In their spreadsheet model, they take 2012 generation and assume a 6% improvement.  The issue I quickly see with this math is the fact the likely remaining coal units that are running after 2020+ are likely the best of the best coal units to begin with.   These coal units did not get to be the best ignoring best practices, therefore the remaining coal units will have much less opportunity to improve heat rates compared to the units that will likely be retiring (From EPA own analysis 72 GW 2016 to 101 GW by 2030 (cumulative)).

The second block is the most interesting block in my mind.  It is also the second most impactful of the blocks only few percentages away from #3.   When dispatched is discussed, one should quickly jump to market conditions.   A dispatch of power plants is largely driven by load and fuel commodity price relationships.   The first issue, largely perhaps by coincidence and unintentional is their use of 2012 data.   Out of all the years one could choose, 2012 is probably the LEAST likely year in the future in terms of commodity price relationships.  The spread between coal and gas prices was less than $0.40/mmbtu.  Nowhere in the forecast is this price spread being predicted.  In the models being used, the spread is closer to $3/mmbtu.  This produces an abnormal level of coal generation to start their calculation of targeted rate.  In order to get gas units to perform in the 70% utilization range, retirement of existing coal unit and/or the spread of the fuel cost need to narrow.    Using a carbon cost will narrow the economics.   I did run a 2016 carbon case with $30/ton, and it did produce NGCC utilization rates close to 70%.  Therefore there is an agreement with the statement “For the scenario reflecting a 70 percent NGCC utilization rate, comparison to the business-as-usual case indicates that the average cost of the CO2 reductions achieved over the 2020-2029 period was $30 per metric ton of CO2”.   What I will be concerned with is the statement “Projected wholesale electricity price increases over the same period were less than seven percent in both cases, which similarly is well within the range of historical electric price variability”   I think they are referring to the gas price change impact due to more demand.  However the question really should be the impact of making the gas units 70% utilized which is done by adding the $30/ton carbon cost.  The 7% increase would seem very unreal with the math of only dispatching difference and carbon of $30/ton.   When I model 2016 with and without $30/ton carbon, it results in significant price increases.  PJM-West prices rise 50%.  In terms of total system impact, the 2016 case without carbon is showing total US energy revenue for all the plants of $168 Billion.   Adding carbon increases the energy revenue to $253 Billion, an increase of 51%.   It is possible to lower the cost as certain markets are closed system and may not pass the cost directly to the consumer.  However, market principle for the majority markets would apply and this is increasing as more utilities de-regulate their generation.  Another potential for price increase mitigation could be if they model more than block 2 and included renewables.  Renewable PPA deals do collapse the wholesale market, but those cost show up on the retail prices.  However they discussed this in the block 2 discussion.  There are regions where prices move up only 17%, but, on average, prices are up 50%.   This brings up another can of worms in terms of state impacts from one to another.  Out of the hub reporting I am looking at, Indiana will be the biggest hit.  I am at loss to understand the minimal discussion of energy price impact of $30/ton carbon cost.  A true impact study should show the case where coal units are running and then adding carbon cost to essentially push out coal units should be the comparison.  They do note the multi-pollutant benefits, counter to that they should also identify the multi-pollutant cost by modeling a business as usual case (no MATS, CSAPR, CPP, etc…).

There is much to digest here so I will pause before discussing blocks 3 & 4.

We can help the policy discussion in terms of running independent assessment and help develop strategies to best plan for the future.  Please contact us 614-356-0484 or dkb@allenergyconsulting.com

Your Inspired Energy Consultant,

 

David


David K. Bellman
Founder & Principal
All Energy Consulting LLC
“Independent analysis and opinions without a bias.”
614-356-0484
dkb@allenergyconsulting.com
blog: http://allenergyconsulting.com/blog/category/market-insights/

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