US Natural Gas Demand Outlook

US Natural Gas Demand Outlook

Natural gas demand outlook is probably more uncertain than the production side of natural gas.   The natural gas production is limited on the upside by the technology capability and infrastructure.  To the production downside, there is some political constraints.   However, the variability for natural gas demand is likely more uncertain as the upside could be quite high with exports, revitalization of the US manufacturing base, and the power sector increases.   All of these variables involve the economy and the political willingness to act.

Whenever one starts with fundamental analysis, it is always good to take a trip down memory lane.   Of recent, the largest impact to demand occurred in the winter of 2011-2012.  Examining the winter residential demand, the volume has been at its lowest  since the winter of 1986-1987.   This was a drop of 3.2 BCF/D compared to the 5 year average.  The significance of this mild winter is comparable to the supply disruption that occurred from Katrina in 2005.   Therefore, it is very important to put that into context that the 2011-2012 was the once in one hundred year winter.   The impact of such event should and has been felt for multiple years similar to the Katrina impact.   The timing of the winter with the coincided shale gas production has led us to observe low gas prices over the last two years.  I would contend without this winter impact, we likely might not have observed the prices below $3/mmbtu.  The Katrina impact took about 18 months for the market to come back to fundamental balance.   The disruption of 2011-2012 winter should be done by this year.   The remaining bearish impacts will be directly with a function of shale gas production.

Another demand for natural gas which cannot be avoided, given it now represents the largest demand sector for natural gas, the power sector.   A historical phenomenon for natural gas demand was the rise of natural gas demand in the power sector which occured with one of the largest price rise.   From 2002 to 2008, we observed a 15% annualized growth of natural prices while demand in the power sector grew nearly 4% on annualized basis.   Most people outside the energy space do not realize this.   The reason this happened was the incremental load growth had to be met and the spare capacity in the markets came from the over build out of gas units in the later 90’s and early 2000’s.   Load growth was averaging 1.2% from 1998-2008.  The rising price of natural gas demand would not stop gas being used in the power sector.   Therefore the load growth was expected to add around 1 Bcf/d of gas demand each year.   This also played a crucial part in natural gas price collapse.   As load growth has been stymied since the 2008 financial collapse.   Three areas are driving the lack of growth one economic, the other, the push on energy efficiencies initiatives and the huge renewable development.   Renewable growth is likely to slow down, now that gas prices are putting damper on renewable economics.   Energy efficiencies still have room to alter the demand landscape, but the big unknown is the economic recovery.

As noted in the previous report on the challenges in the power sector, the growth is far from the trend line.   Will there be a reversion to the mean trend line?   Will low natural gas price stimulate not just natural gas demand for the raw material but will it generate electrical demand from a manufacture revival?  For the base case, I have decided to take a conservative approach to revert demand back to the trend line as if it was going to get reset.  In addition, due to the $9 billion energy efficiency market, I have trimmed load growth by 0.5% similar to the EIA load forecast of 0.58%.  Counterbalancing the load reduction is the increase retirements.  Without load growth much of the old units whether coal or other types of unit cannot afford their fixed cost to operate.  Therefore we still see incremental power demand will add 1 Bcf/d of natural gas demand each year in the outer years.

The other major power story is the coal retirements due to environmental requirements.  EPA mercury rules hit in 2015, but plants can apply for a year extension and so far no plants have been denied an extension.   Basically the rules force existing coal plants to be fully controlled (scrubber, SCR, bag house/ precipitator).  This can cost as much as a brand new combined cycle plant.   Natural gas will likely need to make up a good portion of those unit retirments.   However, many have simply multiplied the retirement times a gas heat rate to come up with the gas demand impact.   This is bad math.   The coal units do not operate at all hours that would require a gas unit.   During many hours, a coal unit fleet will be at minimum operation level which could be around 40-60% of full capacity in order for the fleet to be ready for the on-peak hours.  Off-peak hours amount to 43% of the year.  Many of these hours will actually be made up by the existing coal fleet, so their requirement to run at minimum would be reduced.

Based on some of my models, I anticipate the number to represent 30% of gas demand.   In total, in 2016 we could see an increase of 3 bcf/d driven by the coal retirements from the MATS ruling.   Both the demand growth and coal retirements continue to make the power sector the most important piece in the puzzle with much subject to change given EPA rules.   For those engaged in natural gas, it is important to monitor this situation.   All Energy Consulting can help you out with our power modeling outsourcing option.   A more detailed breakout of the power gas demand will be available in the final report and presentation available if you email David K. Bellman .   The report will dive into the load outlook and renewable competition.

The next major category for natural gas is the use of the raw material for chemical manufacturing and LNG exports.  They are somewhat connected.   As I reported in my comments to the DOE – we need to realize the use of our natural resources which will add significantly more to the bottom line economics than to export the product only to buy the products back.   However, I am cognizant on the inability of the political process to make it worthwhile to bring manufacturing back into competitive setup in the US.   I do believe there will be a compromise needed between the corporate culture and the unions.   There needs to be a balance and I believe it can be done through new businesses not established companies.   I suspect many established companies are supporting the LNG project and the pipeline build up to deliver products to their sunken investments in the Gulf versus constructing new plants at the source.  For the base, I have a higher outlook than EIA largely because I believe there will be balance between imports from Canada.  An optimal US economic benefit of LNG would be the LNG exports equal to the amount being imported from Canada.  It would be more of economic gain to export Canadian LNG than to let the Canadians export their own LNG.   Based on history this would amount to 3.5 Bcf/d..    BHP is projecting11 Bcf/d export from the US by 2030 .

If LNG approach the 11 Bcf/d figure there will be a demand price response.   If the global market of gas demand is not growing proportionally to the increase some of the LNG investors may be hit with big losses.  The reason I state this is the understanding of the Middle East.   The mentality of the Middle East cannot be ignored.  They have and will manage the market with the focus on market share.   The experience in 1998 cannot be forgotten.   This was my 15 minutes of fame in which I was published in many national magazines predicting the crude oil collapse.   The basis all came from the fact the supply demand balances showed a large expansion of supply when the demand dropped out from underneath producers as Asia was the growth everyone built for.   Saudi Arabia at the time constrained production but eventually lost too much market share and decided to show the world the value of being constrained and as I estimated, the market went below $10/bbl.  I think for those who are looking into LNG export from the US need to examine the Middle East.   Market share erosion is not taken lightly. Qatar can easily add more capacity now if it wanted to but similar to Saudi Arabia for oil, it is managing the market. However, the management comes with a fee of maintaining market share. I, therefore, promoted some LNG exports but with foreign investors. This will put them into a take or pay situation vs. leaving US investors holding the debt on a non-used asset. If you think shale gas production which on average likely cost greater than $1/mmbtu even with oil considerations can compete with countries like Qatar with gas production cost less than $0.50/mmbtu, you will be in for a rude awakening.  Shell pulled out of a gas to liquids (GTL) project in the US Gulf as a result of this concern. , A supporting news for LNG export volumes is Qatar is investing in US LNG with ExxonMobil.,

Another hidden demand is the exports to Mexico.  I expect Mexico will not be able to get their act together to manage their resource.   It will be much easier for them to build pipeline and import the natural gas from the US.   I expect this will be a surprise demand source in many of the models.  EIA doesn’t have exports crossing 2 Bcf/d till past 2030.  It would not be a surprise to me to see it cross over closer to 2020.

Similar to the supply side, we have a much higher demand than the EIA when we add all these factors together.  The final price outlook is  that gas prices are expected to be range bound in 2014-2015.   With the coal retirement and manufacturing uptick in 2016 we will likely see prices moving strongly up.  Then LNG exports hitting in 2018 and beyond would likely give another boost.   The real insight will be from the high and low side development of both the supply and demand demonstrating an upside and downside risk.   The likely asymmetric relationship can show a great trade opportunity.

A complete report for the Natural Gas Outlook with graphs and excel tables are available with a presentation, in which I will include a report with a high and low gas price developed using the key variables discussed above.  If interested please email dkb@allenergyconsulting.com

Your Fundamental Energy Consultant,

David K. Bellman

614-356-0484

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