Harper: "The politics of ruthlessness"

[Asher]

You clearly have no idea about the logistics of shipping oil and its inherent cost.

If you don't get the oil from Canada, you have to get it from overseas. That will raise the cost of oil because it raises the cost of transportation.

It's also much worse for the environment, so I'm amused by all of this anti-pipeline American hysteria.

[Tupac Shakur]

No, it won't.

[Asher]

Yes, it will.

Google the cost per barrel of oil per 1000km on pipeline, rail, and tanker. Compare them.

Also compare the prices of WTI and Brent.

You seem to assume there is a global price for oil. There is not. The reason there is not is the logistics of transportation and the impact it has on price. There is a huge spread on oil prices right now.

Again, the high-level market theory you guys are employing is not at all relevant to the realities of the oil market.

[Asher]

For example, a general rule of thumb is any time you need to transfer from tanker or railcar, it adds $5 per barrel cost vs a pipeline.

[Tupac Shakur]

Second only to pipelines in terms of efficiency, the average cost of oil transport by tanker amounts to only two or three United States cents per 1 US gallon (3.8 L).

http://en.wikipedia.org/wiki/Oil_tanker

The cost of transporting overseas oil to the US is essentially nil.

[Asher]

Second only to pipelines in terms of efficiency, the average cost of oil transport by tanker amounts to only two or three United States cents per 1 US gallon (3.8 L).

http://en.wikipedia.org/wiki/Oil_tanker

The cost of transporting overseas oil to the US is essentially nil.

That is completely and utterly false. It's a bogus reference, so I can only assume it's not taking into account transferring and holding costs because that's the only way it could possibly make sense. And in such a case, it's misleading. It's probably a figure from a tanker leasing company.

[Tupac Shakur]

Sure it is.

[Asher]

The cost of WTI would go up by about $15 per barrel if more had to be brought in via the Gulf then trucked/railed around the nation.

I'm not going to even bother citing that, I know it offhand and you can find it if you google.

Again, look at the WTI vs Brent pricing spread before talking about this further.

[giblets]

In fact, it only costs around two to four cents per gallon to transport oil using a typical tanker.

http://science.howstuffworks.com/transport/engines-equipment/oil-tanker.htm

Probably more lies and propaganda from the oil tanker mafia.

[Tupac Shakur]

The cost of WTI would go up by about $15 per barrel if more had to be brought in via the Gulf then trucked/railed around the nation.

Why exactly do you think that Canadian oil that's pipelined down to the Gulf for refining before being trucked/railed around the nation is any cheaper than tanker oil?

[Asher]

http://science.howstuffworks.com/tra...oil-tanker.htm
Probably more lies and propaganda from the oil tanker mafia.

Actually, it very likely is from some tanker leasing company's PR department or marketing materials.

Why do you think they give the metrics in gallons when the industry uses barrels? 1 barrel = 31 gallons.

That is very likely the rate the tanker company charges. What that rate does not include is the bulk of the expense: the transferring & storage charges.

[Asher]

Why exactly do you think that Canadian oil that's pipelined down to the Gulf for refining before being trucked/railed around the nation is any cheaper than tanker oil?

Because I know the people who have done the financial models. It's absolutely much cheaper to get oil via pipeline from Canada than it is shipping it in from the gulf.

[Tupac Shakur]

Yeah, I'm going to need some evidence before I believe you over everything else I've ever read about the oil industry and the efficiency of modern shipping.

[giblets]

Actually, it very likely is from some tanker leasing company's PR department or marketing materials.

Why do you think they give the metrics in gallons when the industry uses barrels? 1 barrel = 31 gallons.

That is very likely the rate the tanker company charges. What that rate does not include is the bulk of the expense: the transferring & storage charges.

Suuuuuure it is. It's inconceivable that the writer of the article decided to use gallons because the reader is probably more familiar with that unit of measurement. Because, you know, the reader is really likely to give a **** about what measure the industry is using.

[Asher]

This may provide some background. It shows how much impact the pipelines from Canada have on US oil prices. It's actually driving down US prices compared to overseas prices, by ~$10 on average. Why is that?

http://www.theoildrum.com/node/7519

Why are WTI and Brent Oil Prices so Different?

Posted by Gail the Actuary on February 22, 2011 - 6:34am
Topic: Economics/Finance
Tags: brent, oil prices, west texas intermediate, wti[list all tags]

We have all heard at least a partial explanation as to why West Texas Intermediate (WTI) and Brent prices are so far apart. We have been told that the Midwest is oversupplied because of all of the Canadian imports, and the crude oil cannot get down as far as the Gulf Coast, because while there is pipeline capacity to the Midwest, there isn’t adequate pipeline capacity to the Gulf Coast. I have done a little research and tried to add some more context and details. For example, the opening of two pipelines from Canada (one on April 1, 2010 and one on February 8, 2011) seems to be contributing to the problem, as is rising North Dakota oil production.

There are two pipelines (Seaway – 430,000 barrels a day capacity and Capline – 1.2 million barrels a day capacity) bringing oil up from the Gulf to the Midwest. It is really the conflict between the oil coming up from the Gulf and the oil from the North that is leading to excessive crude oil supply for Midwest refineries and the resulting lower price for WTI crude oil at Cushing. Demand for output from the refineries remains high though, so prices for refined products remains high, even as prices for crude oil are low. This mismatch provides an opportunity for refiners to make high profits.

There are various ways of fixing the problem. Bringing less oil up from the Gulf would seem to be part of the solution. Conoco Phillips, one of the owners of the Seaway pipeline (and an owner of Midwest refineries), says it is not interested in reversing it. But lower prices by themselves would seem to result in less oil being shipped through the pipelines up from the Gulf, and may at least partially fix the problem.

Trucking and rail transportation of oil to the Gulf Coast may also be part of the solution, but arranging this may take some time, because of the large quantities involved. If shipping by train or truck is worked out, I would expect that the price of WTI will move closer to Brent, to reflect the additional shipping cost involved, perhaps $10 or $15 a barrel. The availability of this solution should help to cap the spread between West Texas Intermediate and Brent.

Rising Production in North Dakota and Canada

Underlying all of this is rising oil production in “PADD2″ (the EIA’s designation for the Midwest, which includes the Bakken in North Dakota) and also rising imports into PADD2 of crude oil from western Canada.

Figure 2 shows the oil imported into PADD2 from Canada. While imports have been rising since 1990, there has been no spectacular recent rise in the amount of oil coming into the US from Canada. A closer look at the last eight months (shown in Figure 3, below) shows that there have been ups and downs, which I will later show correspond to the timing of pipeline closures and operation at reduced pressure because of spills.

The production that appears to be increasing rapidly is production from the Bakken region in North Dakota.

This graph includes all of PADD2. North Dakota is about half of the total, and the only rapidly growing portion. The graph shows production only through November 2010, but it is no doubt higher in December, January, and February. (For more on the Bakken, see my recent post Is Shale Oil the Answer to Peak Oil.)

Thus, it appears that US PADD2 production has recently increased by a high percentage, but relative to a low base, while imports from Canada are generally rising, although not necessarily by very much recently. Both would tend to put pressure on Midwest refinery capacity, if the area were already up against limits, but probably not otherwise.
Midwest Refinery Capacity

We have all heard that these Midwest refining capacity is inadequate. EIA doesn’t give much history of refinery capacity by region, but apparently, the Midwest at one time had more capacity than it does now.

Currently, the Midwest has about 18% of US refining capacity, amounting to about 3.3 million barrels a day. Imports from Canada from Figure 2 or 3 would appear to be about 1.3 million barrels a day, and PADD 2 production would appear to be about 800,000 barrels a day, making a total of roughly 2.1 million barrels a day. This is not enough oil to supply Midwest refineries, and the reason for pipelines from the Gulf. Consumption of oil products in the Midwest is about 4.9 million barrels a day, considerably more than it refines, so the Midwest also depends on imports of oil products from other parts of the country for its needs.

There are two crude pipelines from the Gulf to the Midwest. The Seaway Pipeline with a capacity of 430,000 barrels a day brings oil up from the Gulf coast to Cushing, while the Capline pipeline, with a capacity of 1,200,000 barrels a day, brings crude from Louisiana to Southern Illinois. It is the conflict of the crude oil coming from the North with the crude oil coming from the South that is causing the oversupply of crude oil to Midwest refineries.

It should be noted that some refineries have been set up to handle very heavy oil from Canada, and others have not. There are also other differences in refineries that make some better for some types of crude oil than for other types. Because of this, even if the total amount of crude oil were to match up precisely with the available Midwest capacity, there might still be refineries with not enough crude and others with too much.

According to EIA data, PADD2 (Midwest) refineries are running at 95% of capacity, while other refineries are running at much lower percentages of capacity. Some of the other “PADDs” are running at 75% of refinery capacity–too low to make a profit. The level of refinery utilization tends to vary by the time of year–this is an unusual time for utilization to be so high. If utilization is high now, a “normal” summer rise in utilization would not really be possible. So effectively “maxing out” at refinery utilization seems to be part of the problem.

Since the buyers of crude oil are generally refineries, if they have all the oil they can take, they are not going to bid very much for more crude oil, except perhaps out in the future, when they aren’t so overbooked, and this seems to be the pattern we are seeing for West Texas Intermediate.

Figure 7 shows that it is not all that unusual for the industry to run at 95% utilization of operable capacity. US overall utilization of US refineries is down considerably since the 1995 to 2005 period. There is clearly plenty of capacity in the US, outside of PADD2, if oil could get transported to the right location.
Pipeline Issues

Part of the problem seems to be pipeline issues–particularly new pipelines that don’t go to the Gulf. There are really two new pipelines. The first is Enbridge’s Alberta Clipper Line. It opened in April 2010 and carries up to 450,000 barrels a day from Hardisty, Alberta to Superior, Wisconsin. From there, it is added to existing US pipelines.

The Enbridge Alberta Clipper is the red line (labeled with a “1″), connecting up with Superior, Wisconsin. This pipeline no doubt accounts for whatever increase in PADD2 imports occurred since early 2010, which from Figure 2 above, doesn’t appear to be much.

One reason that the Alberta Clipper doesn’t seem to actually be doing very much to increase US imports is the fact that it appears to have been built for a bigger increase in Canadian production than actually took place, so is running under capacity.

The other reason for the lack of increase is because of leak-related shut downs and reductions in capacity in US pipelines. First, on July 8, 2010, there was a spill in Michigan on the Line 6B (built to carry 290,000 barrels a day, but carrying 190,000 barrels a day). Then, on September 9, there was a leak discovered outside of Chicago in Line 6A (built to carry 670,000 barrels a day, but carrying 459,000 barrels a day before the leak). Both of these leaks were repaired, but Enbridge was ordered to run the pipelines at lower pressure afterward. One report said the reduction in pressure had the potential to reduce deliveries of Line 6A by 300,000 barrels a day. The long and short of this is that while the April 1 increase in pipeline capacity theoretically had the potential to increase deliveries, the closures and reduced pipeline pressures (which reduced the flow rate) prevented much of an actual increase in deliveries. I would not be surprised if we continue to have problems with leaks. There seem to be real issues with putting heavy crude through very old US pipelines–see my post on this issue.

Since the Alberta Clipper didn’t actually increase deliveries very much, crude has been accumulating in Canada. On January 24 Reuters said, “Capacity on Canadian oil pipelines has been tight since this summer, when two of Enbridge’s lines in the Midwest ruptured, backing up crude supplies in Alberta. Oil producers have since been trying to winnow down Alberta stockpiles, routinely requesting more space than available on the lines leaving the province.”

A second new pipeline, Trans Canada’s Keystone Pipeline with a capacity of 590,000 barrels of crude oil a day, was added in February 8. It is labeled with a numeral “2″ on Figure 8. Since it opened so recently, the effects would not yet appear in Figure 3 amounts. The new section brings oil from Steele City Nebraska to Cushing, and raises capacity on the line by 145,000 barrels per day. The addition of this line appears to have the potential to bring more oil into the Midwest, where refining capacity is already “maxed out”. It seems to me that the opening of this line is a major part of what is scaring refineries, since they already have as much crude oil as they can handle from other sources. They are offering low prices for additional oil, recognizing they cannot really handle more.
Storage Maxed Out?

A graph of recent PADD2 storage (the entire amount, not just Cushing) is shown in Figure 9.

Clearly, crude oil in storage was already on an upward trend before the Alberta Clipper pipeline opened on April 1, 2010. If we compare the recent changes in inventory to what has happened with PADD2 imports (Figure 3), we see that there seems to be a close correlation. Between the opening of the pipeline and the day of the first spill (July 26, 2010), inventory increased from 85.0 million barrels to 97.7 million barrels. This was an increase of 12.7 million barrels in about 116 days, indicating that PADD 2 was accumulating inventory at a rate of about 109,000 barrels a day.

Once the first outage began, inventory was drawn down, reaching about 90.7 million barrels when Line 6B was finally put back on at a reduced rate on September 27, 2010. Figure 3 shows piped oil imports began increasing about November 1, 2010. Between November 1 and February 11, inventories increased from 90.7 million barrels to 99.2 million barrels, an increase of 8.5 million barrels in 102 days, or 83,000 barrels a day of inventory accumulation. So it looks as if PADD2 was not able to handle the additional crude oil added by the Alberta Clipper during the times it increased flow from Canada. It is not surprising that refineries are worried about the Trans Canada’s Keystone pipeline expansion coming on line February 8, adding even more potential crude oil supply.
Are the new low crude oil prices reducing PADD2 gasoline prices?

This is a graph comparing PADD2 gasoline prices to US average gasoline prices.

The lower prices that refineries have been paying for crude in PADD2 do not seem to be translating to lower gasoline prices. There would seem to be three reasons for this. First, demand for products, like gasoline, remains high in the Midwest. It is crude oil that is oversupplied, because of pipeline issues and other factors. Second, it is not clear whether refineries actually paid the reduced prices that we have been seeing recently. They may have had long-term contracts or have hedged their costs, so that they did not benefit from the reduced price for WTI. Third, since PADD2 consumes more oil products than it produces, it is importing oil products refined elsewhere, and must pay the “going rate” for them.
How will all of this resolve?

Some have suggested that TransCanada’s Keystone XL pipeline (labeled as “3″ on Figure 8 ) will help solve the problem, when it is completed in 2013. I am not so sure. For one thing, the pipeline hasn’t been approved yet, and it has substantial opposition in the US. Furthermore, unless Canadian production really ramps up, it is not clear that there will be enough crude oil to fill another pipeline. There are already two recent pipelines bringing more oil into PADD2, and they are likely nowhere near full. Canada also has options for sending its crude elsewhere–see pipelines to the West Coast, labeled “4″, “5″, and “6″ on Figure 8.

To handle our current problems, what seems to be needed is a pipeline specifically from Cushing to the Gulf coast. Even this piece of the Keystone XL pipeline has substantial opposition, and won’t be available until 2013, assuming it is approved and moves ahead as planned. If the portion of Keystone XL from Canada is added as well, it will also be bring more crude from Canada, adding to the amount of oil that needs to be transported to the Gulf Coast. The new segment to the Gulf Coast may not add much more capacity than what is being brought south by the new line.

As mentioned in the introduction, there is a 430,000 barrel a day crude oil pipeline that brings crude oil up from the Gulf Coast to Cushing, called the Seaway Pipeline. If it were reversed, it theoretically might solve the problem, assuming that each refinery could still get the type of crude it needs. ConocoPhillips, a partial owner of Seaway, has said it is not interested in reversing the pipeline. Conoco Phillips operates refineries in the Midwest, and stands to make money if there is a large gap between crude oil prices and the selling prices of products (in other words, crack spread). But there may be other reasons for wanting the pipeline to continue flowing in toward Cushing. A 860,000 change in capacity (from +430,000 to -430,000) would a big change to digest, even for a PADD that is oversupplied.

If the selling price of crude oil in the Midwest remains depressed long enough, sellers will find other markets for their crude oil, and the Seaway and Capline pipelines bringing oil up from the Gulf will operate at reduced capacities. That would be one solution to the PADD2 crunch. If the situation is bad enough, long enough, it is possible that the Seaway Pipeline owners will relent and turn the pipeline direction around, so it pumps oil toward the Gulf, instead of up to Cushing.

Another option is railroad or truck shipping of oil from the Midwest down to the Gulf Coast. According to Dennis Gartman, the cost of shipping crude from Cushing to the coast is $10 barrel by truck and $6 barrel by train. If there really is sufficient train and trucking capacity, this would seem to be the approach to use. A person would think the price differential would then be reduced to the additional transit cost, or the additional transit cost, plus a small margin. The price differential between Brent and WTI would then go back to $10 or $15 barrel.

One way or another, the gap between WTI and Brent prices seems unlikely to continue growing, and I would expect the differential to eventually start dropping. It nothing else, as the total supply of oil drops, there will be less oil to fill pipelines from the Gulf to the Midwest, making more opportunity for locally produced oil to use the local refineries.