BTU/barrel of oil = 5.8 million BTU
5.8 million BTU/60 USD = 96,666,67 BTU/USD
5.8 million BTU/147 USD = 39,455,78 BTU/USD
So the BTUs / USD is much higher now than in summer.
http://www.eia.doe.gov/neic/infosheets/ ... ction.html
Reservoir characteristics (such as pressure) and physical characteristics of the crude oil are important factors that affect the cost of producing oil. Because these characteristics vary substantially among different geographic locations, the cost of producing oil also varies substantially. In 2006, average production costs (or “lifting” costs, the cost to bring a barrel of oil to the surface) ranged from about $4 per barrel (excluding taxes) in Africa to about $8.30 per barrel in Canada; the average for the U.S. was $6.83/barrel (an increase of 23% over the $5.56/barrel cost in 2005). Besides the direct costs associated with removing the oil from the ground, substantial costs are incurred to explore for and develop oil fields (called “finding” costs), and these also vary substantially by region. Averaged over 2004, 2005 and 2006, finding costs ranged from about $5.26/barrel in the Middle East1 to $63.71/barrel for U.S. offshore. While technological advances in finding and producing oil have made it possible to bring oil to the surface from more and more remote reservoirs at ever increasing depths, such as in the deepwater Gulf of Mexico, the total finding and lifting costs have increased sharply in recent years.
However fixed lifting/exploration cost are the same basically (though energy costs and credit costs made them explode, so they depend also on energy.) so their % of total cost per BTU goes up as price goes down for a barrel of crude, eventually to 100% as in offshore US exploration costs now.
So if you subtract say local lifting costs from local sales costs for a barrel of say Omani crude
http://www.upstreamonline.com/market_da ... kets_crudeCurrently 45,91 USD/barrel plus say 5USD/barrel lifting costs = 50,91 USD/barrel.
5.8 million BTU/50,91 USD = 113,926 BTU/USD
Lifing costs are not much differnet regardless of where you are at between USD5-USD 8. But when it comes to new discoveries only very high prices justify many new discoveries.
Verious oil grades however can have much different net BTU or resulting profit margin:
http://robertrapier.wordpress.com/2007/ ... say-essay/Let’s compare two hypothetical refineries. Refinery A has no coker, and thus is restricted to either buying light crude, or buying heavy crude and selling a lot of low-value asphalt and roofing tar. So let’s say that Refinery A pays $55 a barrel for West Texas Intermediate. They will turn that barrel into 0.909 barrels of liquid fuel product (per the light assay above, 4.4% ends up as gas and 4.7% ends up as resid), which let’s say has a value of $80/bbl. They therefore grossed $80*0.909 - $55, or $17.72 a barrel before we consider the value of the asphalt and the gases. Historically, the value of asphalt has been very low – less than $0.10/lb. Given that our barrel of crude weighed around 300 lbs, and we got a 4.7% asphalt yield, the barrel yielded 300*0.047 = 14.1 lbs of asphalt worth $1.40. Let’s value our gases at the value of propane (about $0.14/lb on the spot market), and we get a value of 300*.044*$0.14 = $1.85 for the propane. Our gross profit (before operating costs, taxes, etc. are considered) is then $17.72 + $1.40 + $1.85, or $20.97 per barrel for the light crude.
Now consider Refinery B. Instead of buying WTI at $55/bbl, it buys a heavy Canadian crude for $38/bbl (this is an actual current price). Again, their barrel of oil weighs some 300 lbs, and as we can see from the assay above their resid yield may be in the range of 28%. So, of the 300 lbs, 84 lbs ends up as resid. But with our coker, we turn 80% of that into high-value products, and only 20% (16.8 lbs) ends up as low-value coke (a coal substitute). Therefore, the overall yield from the heavy crude amounts to the sum of the cuts up to resid (71.6%), plus the resid that was turned into products (80% of 28%, or 22.4%) minus the gas cut (3.4%) for a total of 90.6%. The overall liquid yield is almost the same as for the light crude, and yet we paid much less for the crude. So, our economics look like this: For the liquid fuels, we grossed $80*0.906 - $38 = $34.48 a barrel. This is almost double what we profited from with the light crude. We have slightly less propane yield than in our previous example. The value of propane is $1.43. Finally, we end up with 16.8 lbs of coke, which is worth only $0.015/lb (about $0.25 total). Our total gross profit then is $34.48 + $1.43 + $0.25 = $36.16.
This explains why so many refiners are rushing to install cokers. This is also why I don’t get too excited when someone comments that the build in crude inventories could be a build in “undesirable” heavy sour. Refiners don’t buy what they don’t need, so if heavy sour inventories are increasing then this is primarily coming from refiners that can process heavy sour.
As light sweet supplies continue to deplete, refiners will increasingly turn to heavy sour crude. But not enough refiners yet have a demand for heavy sour, so it trades at a significant discount to light sweet. This will of course change as more cokers are installed. There will be a higher demand for heavy crudes, and the asphalt market will become more lucrative as the asphalt supply gets rerouted to cokers.
I guess coking at refineries is energy intensive using natgas and such so depending on what the coking costs this could be expensive and change RR's calculations above.