Hedging Commodities Is Not Gambling When Done Right
Hedging commodities seems to be a recent interest among many companies I have talked with. There are significant discrepancies of what a hedge really is/should be. Hedging a product can be better worded as insuring an outcome within a certain degree. Those who tout profits and riches are not talking about hedging, but gambling/trading. Gambling/trading does have its own merit when done right, but for this blog I would like to focus on hedging.
Hedging should not be focused on the concept of making money. It should be focused much like insurance. One does not buy insurance to obtain wealth, but to protect against wealth destruction. A proper hedge should protect oneself, commensurate with the level of cost for the hedge. An analogy would be buying a low deductible versus a high deductible insurance. The decision to purchase is the function of perceived risk and financial stability. Another misstatement by many is the fact there could be “free” hedges. There are no free hedges as there are no free cakes.
When to hedge? Hedging makes sense when the product to hedge is not a core part or does not represent a large portion of your business profits. If it does represent a large portion of your business, it should not be represented as only as a hedge, since the product should represent a large core competence of your business. Your team should have a good understanding of the trend and the fundamental nature of the product and be able to effectively trade the product. In the case it represents a smaller portion of your total cost of business, designing an effective hedging program would be a worthy cause.
A hedging program should be tailored and incentivized to reduce volatility and offer a stable cost for projections of earnings. It should not be seen as a profit center. Hedging programs which get caught up in profits eventually becomes a trading program. The hedging program may produce positive results, but these profits should be saved for the rainy days when the hedging program produces negative results. The best hedge programs are systematic.
I have many years in the trading environment along with the corporate planning environment. My group at AEP was instrumental in designing the first approved hedging program by the public utility commission for our supply chains consumption of on-road diesel and gasoline. At All Energy Consulting we understand the energy markets and can effectively navigate you in deciding and designing a hedging program for the various energy commodities. Please contact us to help you evaluate and/or decide on a hedging program.
Your Energy Consultant,
614-356-0484
CERAweek 2012 Summary from the Outside
This years CERAweek marks my first year in almost 10 years in not going to CERAweek. I had the privilege to be invited and speak at CERAweek two times. The amazing thing about CERAweek is the shear size. I have seen it grown from the days in the Galleria area to now at the Hilton Convention Center hotel.
One of the values of being at CERAweek, which you cannot get from reading summaries, comes from the time to reacquaint yourself with your fellow energy colleagues. Also, one of things I always marveled at from being at CERAweek is the logistics of the staff to serve meals. When you attend CERAweek, it is not a buffet line – it is a three course meal for lunch and dinner.
In terms of content summary, Platts did a fine job summarizing many key points in their blog. In addition, twitter works out well when you search #CERAweek. The highlights, I believe, were noteworthy:
CERAweek Oil Day:
I have to agree with Iain Conn, group managing director and chief executive of BP’s worldwide refining and marketing group. Mr. Conn said refinery investments will continue happen in the Atlantic Basin, but it will be strategically done. He also specified he expected to see investments in facilities to take the condensates from the shale development and make products. Those who have been reading my blog will note I made that call early February.
A group made of a good aquiantance Marianne Kuh, Chief Economist ConocoPhillips, and my friend Frank Verrastro, senior vice president and program director at CSIS Energy and National Security Program; noted the high crude oil price is more of a function of actual demand growth, not only political uncertainty of Iran. I do agree with these points, but I still think monetary policy has influenced the price of oil as significantly as demand, if not more.
To prove my point, I have pulled annual oil prices, M2 money supply, and oil demand since 1981. I have graphed the information below. I also ran regressions on each of the variables to oil price. M2 money supply has a better R^2 with 0.61 vs. 0.48. Together they produce a rather strong correlation for an R^2 of 0.70. Another interesting outcome of this analysis is it shows for the first time the amount of M2 is now greater than 10% of the world demand expressed in millions of barrels/day. This started in 2009 as the FED aggressively moved to “save” the system.
CERAweek Gas Day:
There were several discussions of natural gas vehicles. I think it’s a clear choice for fleets to convert to natural gas. Mass transit vehicles should move towards CNG. There was discussion on a recent article in the Wall Street Journal by Robert McFarlane, served as President Reagan’s national security adviser from 1983-85. In the article Mr. McFarlane talks about methanol vehicles. Speakers at CERAweek disagreed with him largely on the premise of structural issues. I think the more valid concern would be the history and fate of MTBE. From what I have gathered methanol would be more toxic than MTBE. I do disagree in how we handle the MTBE issue – requiring MTBE then banning it. MTBE was a messenger to a problem that is still happening. MTBE gave you a mechanism to trace and track leaking gasoline. By eliminating MTBE you did not solve the real problem.
Apache CEO, Steven Farris, made remarks in regards to supplying utilities with long-term contracts, but with a floating gas price. Once again I have blogged about this before. It would be worthwhile to continue to watch this evolution. Many are trying to emulate coal contracts, but the reason and the value of contracting gas is not the same as it was with coal.
Of course it wouldn’t be gas day without a deluge of shale discussion and fracking concerns. Many speakers talked about transparency and the efficacy of fracking. I will have to agree here that it can be done in a responsible and safe way. It is a matter of regulators to effectively regulate, because there will always be bad actors.
My former consulting company, Purvin & Gertz, who got acquired by IHS had their own session at CERAweek. They spoke about the NGL markets. Once again I did note about the dynamics of what is going on in this market in my previous blogs. This is an exciting area, full of opportunities.
CERAweek Power Day:
For some reason, the day opened with a discussion of nuclear renaissance. I will have to agree with GE CEO Immelt – there has never been or will be a nuclear renaissance in the US. I will add the caveat – unless significant structural changes are made to our electric industry design. This country has cost-effective options whereas other countries do not (e.g. France, Japan, etc…).
I will have to differ with many of Alstoms thoughts. Alstom has been a very vocal and huge supporter of CERAweek for the past few years. They spoke many times during the conferences. I have read that they still are investing heavily in CCS. They believe the focus for clean energy should be on the technology side. Once again in my blogs, I elude to the point it is not the technology that is limiting “clean” energy; it is the business strategy and incentives. They also point out that gas generation should focus on bigger turbines with lower cost. Of course, that sounds ideal, but I think over the next 3 years the value proposition will be for more dynamic turbines versus bigger and efficient. I say this because of the need to serve the intermittent nature of wind.
FERC commission, Philip D. Moeller, discussed the point that the consumer needed to see the real price. I believe he is trying to point out the desire of real-time metering. However I will disagree with this since there are several ways to make pricing more transparent to the consumer. Rate design in itself does not hide the cost of power, since regulation comes with cost recovery. It is the actors behind the rate design that hide the true cost of power – as noted in my previous blog. Real-time pricing will change consumption, but the bulk of the impact could be done by having block metering – on and off-peak hours with no dynamic pricing, but a statement to the consumer. The hours between 7am-10pm will be more expensive than 10pm-7am. This method would come at a fraction of the cost and involve much less complexity. I do understand the value of the “smart” grid that it comes from other forms, such as reliability; but this is not how it is being sold to the consumer.
I couldn’t agree more with CEO and President Bruce Grewcock of Kiewet – “In a lot of jurisdictions, people are going to see rate shock when they see the true costs.” Once again this is not coming from a smart grid realtime perspective, but the fact that there has been an underinvestment by the utilities. Instead of focusing on true needs over the past years, we have focused on projects and mechanism of style (e.g. CCS, IGCC, fuel deferral, smart grid, etc…). Inefficiency in markets will always come back to haunt you.
We positively and evocatively challenge the current thinking involving any aspect of energy use. We look for projects that offer meaningful, transformative, with impactful outcome to the marketplace or society.
Independent analysis and opinions without a bias right is what we offer to our clients. Please consider and contact All Energy Consulting for your consulting needs.
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AEO 2012 Natural Gas Liquids (NGL) & Condensates: Glut of Supply
This blog is adding on top of our previous blog, discussing the latest release of the Annual Energy Outlook 2012 (AEO 2012) by the Energy Information Agency (EIA). Shale gas revolution encompasses not only natural gas, but a glut of liquids from condensates to natural gas liquids (NGL). Shale gas is not only impacting the natural gas markets, but has and will impact the chemicals and refining markets. The AEO 2012 shows an increase of only ~600 kbd of NGL from 2010 to 2020. This is a very conservative number. In terms of condensate, the AEO does not break it out, but crude oil and condensates grow only 1.3 mmbpd. In the write up, much of the growth is a function of tight oil not condensates. Once again, I believe this to be almost too conservative.
In order to justify this stance, one can examine the many recent assessments done by the USGS. Adding up just the Eagle Ford, Marcellus, and Permian assessments; the mean NGL technically recoverable volumes total over 6 billion barrels. According to USGS, they have places the condensates into the NGL category. Liquids are clearly driving the shale gas production. Gas is almost becoming a loss leader. As I discussed in my previous blog, there are multiple projects focused on expanding the infrastructure in order to monetize the NGLs coming from these shale plays. One of my estimates of NGL and condensate additional volumes for 2020 compared to 2010 would be an increase of 2 mmbpd.
With this much volume of light feedstock, the US refining markets will see a drastic change. A historical given was the crude slate was going to get heavier requiring more and more conversion capacity. With the amount of NGL and condensates, the US market could potentially see a pause to this belief is inevitable if not a reversal from this trend. Much of the refining capacity has been designed to process heavy crudes not light feedstock. Refining margins from a highly complex refinery will not be pretty. Perhaps many have come to this thinking with all the refining closures and selling announcements. Simple condensate splitters economics would not bode well either, as a surplus in naphtha will likely occur. NGL and condensates will need to find a home. A re-configuration of existing refineries will come at significant losses to the current owners. There will be winners. Those who have access to capital and can think outside the box will win. The consumers will also be a big beneficiary of refining margin compression.
We positively and evocatively challenge the current thinking involving any aspect of energy use. We look for projects that offer meaningful, transformative, with impactful outcome to the marketplace or society.
Independent analysis and opinions without a bias is what we offer to our clients. Please consider and contact All Energy Consulting when you need consulting services.
Your Energy Consultant,
Shale Gas Production so now what?
The enormous potential for natural gas production is the essence of the shale gas revolution. Many people are still spending much of their time quantifying it. For those in the commodity trading, planning, or business development space, I think it’s time to move on and examine the opportunities. Shale gas production will not be small. Perhaps it could be medium with potential regulations limiting the development. It may be extra-large if knowledge is increased and the players involved act appropriately. The next important question is where will it all go? As with any product that is introduced, you need to do some market assessment. I can with some certainty pronounce that the bulk of the new gas supply will go to the power market.
Following that premise, the next question will be how it will go to the power sector? The answer to this will vary. As a producer you need to know your customer and how exactly best to market to this new sector. Given my vast oil & gas experience along with my power utility experience I can be that bridge for you to understand what is involved in this transition. Letting nature/market takes its course for you will produce a very rocky outcome. Approaching the transition in a more strategic approach will allow you to unlock more value and avoid significant on-hands learning moments.
Inversely, as a power/utility company, moving to gas will require much consideration as the dynamic of the gas industry is much different than the coal industry. The lingo and the business strategies are almost polar opposites in some cases. The power and gas industry are currently not aligned in the advocacy position of energy policy (or lack of). This will need to change if this transition will be smooth and productive.
At AEC we can act as the bridge for you. We can pull the two sides together to produce a win-win situation. Please call us to learn, reaffirm, and give you a unique perspective on the situation. 614-356-0484 email [email protected]
Stranded Wet / Liquids Rich Gas from Shale Gas
Gas production from the shale gas revolution has not only added gas production, but petroleum liquids. This is seen in fields from Eagleford, Marcellus, to Utica. This added benefit has skewed the economics of natural gas production. Certainly these liquid rich plays have impacted the recent natural gas price capitulation. Producers are almost ignoring the natural gas price and just focusing on the liquid value-add as the petroleum markets maintain their strength.
However all is not well for the producers. The existing infrastructure in the Midwest is not design for all these liquids. The bulk of US refinery continues to be in the Gulf Coast. There are several projects underway and/or proposed to alleviate the pressure from stranded liquids in the region.
There is an ethane pipeline being built from Markwest Hydrocarbons Houston, Pa processing plant (just southwest of Pittsburgh) to Sarnia, Ontario to feed ethylene crackers owned by Imperial and Nova. Enterprise Products and Chesapeake recently announced an ethane pipeline that will take Marcellus and Utica ethane production to the Mont Belvieu, TX area and U.S. Gulf Coast ethylene crackers. El Paso is also evaluating converting the Texas Eastern natural gas transmission pipeline to an “ethane gas” pipeline that would move Marcellus and Utica ethane to North Louisiana in a gaseous form (can’t move as liquid because maximum pressure of the TE p/l is 750 psig), where they would build a cryo plant to convert the ethane back to a liquid, and a new pipeline that would transport the liquid ethane from the cryo plant to Dow and Westlake’s ethylene crackers in South Louisiana.
The final ethane takeaway solution is called “Mariner East” and is a joint project of Markwest Hydrocarbons and Sunoco that would take ethane by pipeline to Philadelphia, then load it on some old converted LNG vessels and ship it to the U.S. Gulf Coast for ethylene cracker consumption.
If you are participating in this area the first thing you need to do is evaluate the regional refineries. I could help you make a list of all the refineries, gather info on the current type of crudes they’re equipped to handle, call common carriers to get freight rates, calculate the value of the crude/condensate, etc. If your production is going to be significant, I can evaluate the various projects listed above for project viability and impact. I can also evaluate the worth of pursuing “if and where” a storage and barge terminal constructed on a river to transport to refiners that can be accessed by water.
