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A "Shocking" Shut-in Scenario for Canadian Natural Gas

Canada is full of natural gas.

The country's gas storage market is near capacity, in fact -- much earlier than normal in the current gas injection season.

One scenario -- which no one wants -- has storage completely filling up... something that has never happened before. 

What would happen to the price of natural gas in Canada, and who's most vulnerable in this scenario?

In the U.S., analysts are talking about theoretical full storage just before withdrawal season starts. 

In Canada, though, the issue is much more pressing—still hypothetical, but certainly still possible..

“If storage did get full, it would only be for 1-2 months in a worst case scenario,” says Geoff Ready, an energy analyst at Haywood Securities in Calgary.  “The market will correct itself but there could be some price shocks.”

Canada produces 12-14 billion cubic feet per day (bcf/d) of natural gas (down from 17 bcf/d five years ago), and exports roughly 6 bcf/d to the US at this time of year.  It currently uses 3 bcf/d in-country, for a total of 9 bcf/d.  That means roughly one third of Canadian gas production would need to get shut in, in a worst case scenario of full Canadian gas storage.

But even though only one third of the gas is shut in, that would take the pricing for the rest of the market down to an unknown number—potentially close to zero.  (Processing and transportation costs are already taking profit margins close to, or even under zero, for some Canadian producers.)

However, several trends are working in the Canadian producers’ favour recently.

One is that exports to the US trend up during the summer to help with the air conditioning/power demand there.

Second is that while natural gas production in the US has risen steadily for a few years, and remained steady in the face of lower prices, Canadian production has been declining for years, and just this year, production has already declined over 2 bcf/d so far.

The third trend:  there is private storage of gas that is not accounted for in official statistics, and that is being used as well.  There is thought to be 400 bcf of gas storage in Alberta, where most gas is produced.

Finally, Canada is already shipping a lot of gas into US storage.

But just like in the US, Canadian gas producers sometimes don’t really want to shut in production, says Ready.

“Economics should determine whether more production is shut-in, however optics sometimes win over economics.” He says some public companies don’t want to show a production decrease on their quarterly report and will produce or even drill uneconomic wells to avoid this.

To illustrate the optics effect he points to Whitecap Resources (WCP-TSX) as doing the prudent thing—reducing capital expenses (capex, the industry calls it), and lowering production guidance.  Economics says the stock should have gone up by doing the “right thing” in the face of weakening commodity prices —but it went down as much as  16% after its announcement.  (Whitecap is even one of the junior market darlings.)

Another sign Canada is getting closer to full storage is that the Canadian AECO price differential is widening from the US gas price at Henry Hub (The US has several natural gas “hubs” where prices are set).  AECO was only 25 cents per mcf (thousand cubic feet of gas) lower three months ago; now it’s 50 cents lower.

Canadian brokerage firm National Bank explains: “…with Alberta storage levels still well ahead of last year’s levels at this time of year, more Alberta gas has to make its way to export markets, which means Alberta gas has to price itself at a greater discount to those export markets to incentivize the transportation.” (italics mine–KS)

But there’s a small likelihood of seeing huge gas shut-ins in Canada without full storage.  That doesn’t bode well for Canadian producers, as prices will continue to sink.  How low does the price go in advance of this?  Canada has already seen just over $1.60 per thousand cubic feet of gas (mcf). Processing and transportation costs can eat up most if not all of that for producers, leaving them with no positive cash flow just on operating costs.

If you amortize all-in costs per mcf, the industry needs triple that price to make money.

For now, full storage is theoretical, even in Canada.  But what happens to them when the underground storage caverns can’t hold a single more molecule of gas… and basically one third of Canadian production potentially can’t find a home?

(Gas storage is so expensive — it’s only used by big utilities and consumers of gas; it’s only used by the large producers, and even then not a lot.)

Angle Energy (NGL-TSX) President Heather Christie Burns said the recent strike at Canadian Pacific gave the industry a dry run (pardon the pun) on what would happen.

“Some products, like natural gas liquids, get to market via rail transport.  Had the strike gone on any longer, we would have seen production curtailment mandated by processing facilities declaring force majeure.

“They tell you they will use their best efforts (to take whatever production they can) and (producers) have to shut in field production.  This strike was short-lived, so no impact to production was experienced.

“In the storage situation, the producer shut-ins mandated by facilities and/or pipelines would be similar.  Also, in the hierarchy of gas production the government would prioritize associated gas from oil wells over gas wells.”

Dave Haskett is the President of Alberta based Patriot Energy Marketing Inc. Junior and intermediate level producers contract with companies like Patriot to get the best price they can for their gas in the market every day.  He says the industry has been here before, but adds that everybody is watching storage in both Canada and the US very closely.

“In the event the markets for natural gas are increasingly limited, and storage facilities are full, then producers would be forced to shut in. Every producer and producing field has price points.  The decision to shut in wells or shut in an entire production field is based purely on the financial metrics of individual companies,” says Haskett.

“While we have not seen a situation where all storage facilities are completely full, we will, in all likelihood be going into this winter with storage at record levels.”

Haskett adds that the other significant impact will be to pipeline companies such as TransCanada Pipeline Company (TCPL) — whose mainline from Empress Alberta into the East has been well under its capacity.

“This was a terrible winter for TCPL in terms of its volume delivered into the Eastern Canadian and US markets. Looking ahead it would appear that TCPL will have another dismal year in terms of the utilization of its pipeline capacity unless we get a very cold and early winter.

“With respect to a completely full storage scenario in my 32 years we’ve never had a season where that happens.  We’ve never filled every cavern to the brim,” he says. He added, however, that if Canada gets a mild winter like the one just past, the storage situation “gets really ugly.”

So who is the most vulnerable here? Junior producers – especially those focused primarily on natural gas.  They will most likely be forced to shut in more production — particularly if their production is behind a third-party gas plant and the operator elects to shut the plant in due to economics, or the junior has a small working interest and his larger partner elects to shut in wells or a producing field.

For now, this situation is hypothetical. But it’s not a scenario that anyone in the industry wants to see occur. The impact is enormous for storage operators, pipeline companies and natural gas producers, which all employ thousands of people.

One final note – AECO basis is suffering here for the balance of the summer and even through calendar 2013. There are growing concerns that West storage in general – not just Alberta but also US western storage facilities – will start to approach historical maximums earlier than the rest of the continent’s storage facilities.

If this happens, West prices will have to fall relative to other continental market hubs in order to justify the transportation of gas to these more distant markets. This creates some real risk for AECO prices, especially over the balance of the summer season.

By. Keith Schaefer

Publisher, the Oil & Gas Investments Bulletin




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Leave a comment
  • Chuck on July 18 2012 said:
    While it is clear that we have at the very least a seasonal overproduction problem, it is annoying to see 'breathless catastrophism' articles that imply that when storage is full, no producer will be able to sell their gas. That problem will be serious for incremental new producers, but for existing producers with long-term pipeline transport and delivery contracts, many of which are fixed price, the problem will be much less severe. Their customers will still be consuming the gas they contracted for. It takes quite awhile for contracts to expire and prices to be renegotiated, and big consumers usually want more price predictability than the spot market offers.
  • Dave on July 21 2012 said:
    Gee, maybe we could slow down and save some CNG for future generations??? Even with further climate change it'll still be chilly here in winter. Maybe Canada needs a long term national energy policy beyond drill baby drill and sell it all to China?
  • gar on July 21 2012 said:
    Like many Canadians i am so tired of listening to the opposition to the pipeline predicting great oil spills in the waters off B.C . Every day of the year ships traverse these waters carrying up to 250,000 gallons of fuel. We have never had a serious spill. If we Canadians were suddenly faced with the middle east shutting off the tap and we were paying ten dollars a liter it would not take long to see these twits demand a pipeline.Also the great farce about the aboriginals being keepers of the land. Visit a few northern reserves and you will see pollution at its best.

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