Western Canadian Select

Edit links
From Wikipedia, the free encyclopedia

This is an old revision of this page, as edited by Oceanflynn (talk | contribs) at 02:38, 24 August 2013 (Irving Oil). The present address (URL) is a permanent link to this revision, which may differ significantly from the current revision.

Western Canadian Select is one of North America’s largest heavy crude oil streams.(Platts 2012)[1] It is a heavy blended crude oil composed mostly of bitumens blended with sweet synthetic and condensate diluents from 19 existing Canadian heavy conventional and bitumen crude oils at the Husky in the Hardisty terminal.(Cenovus 2010) harv error: multiple targets (2×): CITEREFCenovus2010 (help)[2] Hardisty, Alberta."(CAPP 2012)[3](Argus 2012)[4](Suncor, 2013 & 1)[5] Western Canadian Select heavy crude oil (Natural Resources Canada GC 2011 p. 8) is one of many petroleum products from Western Canadian Sedimentary Basin oil sands. "The extremely viscous oil contained in oil sands deposits is commonly referred to as bitumen. Western Canadian Select is the benchmark for emerging heavy, high TAN (acidic) crudes [4] Western Canadian Select was launched in December 2004 as a new heavy oil stream by Cenovus, Canadian Natural Resources Limited, Suncor and Talisman Energy Inc.(Cenovus 2010) harv error: multiple targets (2×): CITEREFCenovus2010 (help)[2][4] Only these produce WCS and they are committed to keeping the quality of WCS "tightly controlled" making it a benchmark for emerging heavy, high TAN (acidic) crudes [4] Western Canadian Select was produced and traded out of Western Canada,(Cenovus 2010) harv error: multiple targets (2×): CITEREFCenovus2010 (help)[2]Hardisty, Alberta (CAPP 2012),[3] but in June 2012 Platts launched a new daily price assessment, pricing Platts Ex-Cushing Western Canadian Select (WCS), assessed at $70.78 per barrel at Cushing, Oklahoma, a major storage area and delivery point for key crude oil futures contracts.(Platts 2012)[1]

Bitumen comprises all of Canada’s non-conventional oil, and is either converted into heavy oil or upgraded to synthetic light crude.[6]

Characteristics

At the Husky Hardisty terminal, Western Canadian Select is blended from sweet synthetic and condensate diluents from 19 existing Canadian heavy conventional and bitumen crude oils.(Cenovus 2010) harv error: multiple targets (2×): CITEREFCenovus2010 (help)[2][4]

Western Canadian Select is a heavy crude oil with an API gravity level of between 19 to 22 (API),(Platts 2012)[7] 20.5° (Natural Gas and Petroleum Products 2009).(NRC, 2013 & 9)[8]

Western Canadian Select's characteristics are described as follows: Gravity, Density (kg/m3) 930.1,(2010 & Cenovus)[2][9] MCR (Wt%) 9.6,(Cenovus 2010) harv error: multiple targets (2×): CITEREFCenovus2010 (help)[2] Sulphur (Wt%) 2.8-3.5%,(Platts 2013)[7] TAN (Total Acid number) of (Mg KOH/g) 0.93.(2010 & Cenovus)[2]

WCS has an API gravity of 19-22.(Platts 2013)[7]

"Oil sands crude oil does not flow naturally in pipelines because it is too dense. A diluent is normally blended with the oil sands bitumen to allow it to flow in pipelines. For the purpose of meeting pipeline viscosity and density specifications, oil sands bitumen is blended with either synthetic crude oil (synbit) and/or condensate (dilbit)."(NRC, 2011 & 9)[8]

In a study commissioned by the U.S. Department of State (DOS), regarding the Environmental Impact Statement (EIS) for the Keystone XL pipeline project, the DOS assumes "that the average crude oil flowing through the pipeline would consist of about 50% Western Canadian Select (dilbit) and 50% Suncor Synthetic A (SCO)."(Lattanzio, 2013 & 9)[10]

Volumes

By 2010 Western Canadian Select achieved threshold volumes of approximately 250,000 barrels per day.(Cenovus 2010) harv error: multiple targets (2×): CITEREFCenovus2010 (help)[2]

Price of Crude Oil

Main article: Price of petroleum

The price of petroleum as quoted in news in North America generally refers to the WTI Cushing Crude Oil Spot Price per barrel (159 liters) of either WTI/light crude as traded on the New York Mercantile Exchange (NYMEX) for delivery at Cushing, Oklahoma, or of Brent as traded on the Intercontinental Exchange (ICE, into which the International Petroleum Exchange has been incorporated) for delivery at Sullom Voe. West Texas Intermediate (WTI), also known as Texas Light Sweet, is a type of crude oil used as a benchmark in oil pricing and the underlying commodity of New York Mercantile Exchange's oil futures contracts. WTI is a light crude oil, lighter than Brent Crude oil. It contains about 0.24% sulfur, rating it a sweet crude, sweeter than Brent. Its properties and production site make it ideal for being refined in the United States, mostly in the Midwest and Gulf Coast regions. WTI has an API gravity of around 39.6 (specific gravity approx. 0.827). per barrel (159 liters) of either WTI/light crude as traded on the New York Mercantile Exchange (NYMEX) for delivery at Cushing, Oklahoma, or of Brent as traded on the Intercontinental Exchange (ICE, into which the International Petroleum Exchange has been incorporated) for delivery at Sullom Voe. Cushing, Oklahoma, a major oil supply hub connecting oil suppliers to the Gulf Coast, has become the most significant trading hub for crude oil in North America.

The price of Western Canadian Select (WCS) crude oil (petroleum) per barrel [2] suffers a differential(CNRL 2012)[11] against West Texas Intermediate (WTI) oil price as traded on the New York Mercantile Exchange (NYMEX) as published by Bloomberg Media, which itself has a discount versus London-traded Brent oil.(CNRL 2012)[12]

"West Texas Intermediate Crude oil (WTI) is a benchmark crude oil for the North American market, and Edmonton Par and Western Canadian Select (WCS) are benchmarks crude oils for the Canadian market. Both Edmonton Par and WTI are high-quality low sulphur crude oils with API gravity levels of around 40°. In contrast, WCS is a heavy crude oil with an API gravity level of 20.5°."(NRC, 2011 & 9)[8]

West Texas Intermediate WTI is a sweet, light crude oil, with an API gravity of around 39.6 and specific gravity of about 0.827, which is lighter than Brent crude. It contains about 0.24% sulfur thus is rated as a sweet crude oil (having less than 0.5% sulfur), sweeter than Brent which has 0.37% sulfur. WTI is refined mostly in the Midwest and Gulf Coast regions in the U.S., since it is high quality fuel and is produced within the country (from Wikipedia article on West Texas Intermediate).

"WCS prices at a discount to WTI because it is a lower quality crude (3.51Wt. percent sulfur and 20.5 API gravity).(Moore 2011) [13]

Crude oil differentials and Western Canadian Select (WCS)

Alberta's Minister of Finance argues that WCS "should be trading on par with Mayan crude at about $94 a barrel." [14] Maya crudes are close to WCS quality levels.(Moore 2011)[13] However, Maya was trading at $US108.73 a barrel in February 2013 while WCS was $US 69. Mexico enjoys a location discount with its proximity to the heavy oil-capable refineries in the Gulf Coast. As well, Mexico began to strategically and successfully seek out joint venture refinery partnerships in the 1990s to create a market for its heavy crude oil in the U.S. Gulf. In 1993, for example, Petroleos Mexicanos (PEMEX, the state-owned Mexican oil company) and Shell Oil Company agreed on a joint $US 1 billion refinery upgrading construction project which led to the construction of a new coker, hydrotreating unit, sulfur recovery unit and other facilities in Deer Park, Texas on the Houston Ship Channel in order to process large volumes of PEMEX heavy Maya crude while fulfilling the U.S. Clean Air Act requirements.(PR 2013)[15]

Year 2007 2008 2009 2010 2011 2012 Feb 2013 24 April 2013 August 2013
Price Brent C $US/bbl 73 98 62 80 112 112 118 103.41
Price WTI C $US/bbl 72 100 62 80 95 95 95 93.29(2013a & PSAC)[16]
Price WCS C $US/bbl - 80 52 65 78 72 69 77.62 82.36 $C/bbl

(2013a & PSAC)[16]

Price Syncrude Sweet C $US/bbl 62 102 62 78 104 93 97 98.51
Edmonton Par C $US/bbl 72 96 58 75 96 86 87 89.53
Maya C $US/bbl 2007 2008 2009 2010 2011 2012 101 April 2013

(Prices except Maya for years 2007-February 2013)(2013 & TD) [6](Prices for Maya)(2013 & Van Loon)[14](Prices for 24 April 2013).(2013 & PSAC)[17]

By July 2013, Western Canadian Select (WCS) "heavy oil prices climbed from US$75 to more than US$90 per barrel — the highest level since mid-2008, when WTI oil prices were at a record (US$147.90) — just prior to the 2008-09 'GreatRecession'."(Mohr 2013)[18] WCS "heavy oil prices were "expected to remain at the US$90, which is closer to the world price for heavy crude and WCS 'true, inherent value'."(Mohr 2013)[18] The higher price of WCS oil off WTI was explained by "new rail shipments alleviating some export pipeline constraints — and the return of WTI oil prices to international levels."(Mohr 2013)[18]

Getting to tidewater: landlocked Canadian oil sands petroleum products suffer huge losses on price differentials

Until Canadian crude oil, Western Canadian Select, accesses international prices like LLS or Maya crude oil by "getting to tidewater (marketing)" (south to the US Gulf ports via Keystone XL for example, west to the BC Pacific coast via the proposed Enbridge Northern Gateway Pipelines to ports at Kitimat, BC or north via the northern hamlet of Tuktoyaktuk, near the Beaufort Sea,(Hussain 2013) harv error: multiple targets (2×): CITEREFHussain2013 (help)[19], or east to the Atlantic Ocean, the Alberta government (and to some extent, the Canadian government) is losing from $4 – 30 billion in tax and royalty revenues as the primary product of the oil sands, Western Canadian Select (WCS), the bitumen crude oil basket, is discounted so heavily against West Texas Intermediate (WTI) while Maya crude oil, a similar product close to tidewater, is reaching peak prices.[20] Calgary-based Canada West Foundation warned in April 2013, that Alberta is "running up against a [pipeline capacity] wall around 2016, when we will have barrels of oil we can’t move."[19]

Frustrated by delays in getting approval for Keystone XL (via the US Gulf of Mexico), the Northern Gateway Project (via Kitimat, BC) and the expansion of the existing TransMountain line to Vancouver, British Columbia, Alberta has intensified exploration of two northern projects "to help the province get its oil to tidewater, making it available for export to overseas markets." [19] Canadian Prime Minister Stephen Harper, spent $9 million by May, 2012 and $16.5 million by May, 2013 to promote Keystone XL.[21]

In the United States, Democrats are concerned that Keystone XL would simply facilitate getting Alberta oil sands products to tidewater for export to China and other countries via the American Gulf Coast of Mexico.[21]

On 1 August 2013, TransCanada CEO Russ Girling announced that the company was moving forward on the $12 billion 4,400-kilometre (2,700 mile) Energy East pipeline project with a proposed completion date in 2017 or 2018.(2013 & Zawadzki)[22] In the long term this would mean that WCS could be shipped to Atlantic tidewater via deep water ports such as Quebec City[23] and Saint John. Potential heavy oil overseas destinations include India,[23] where super refineries capable of processing vast quantities of oil sands oil are already under construction. In the meantime, Energy East pipeline would be used to send light sweet crude, such as Edmonton Par crude[23] from Alberta to eastern Canadian refineries Montreal/Quebec City, for example. Eastern Canadian refineries, such as Imperial Oil Ltd. 88,000-barrel-a-day refinery in Darmouth, N.S.,[23] currently import crude oil from North and West Africa and Latin America, according to Mark Routt, "a senior energy consultant at KBC in Houston, who has a number of clients interested in the project." The proposed Energy East Pipeline will have the potential of carrying 1.1-million barrels of oil per day from Alberta and Saskatchewan to eastern Canada.(TransCanada 2013)[24]

Patricia Mohr, a Bank of Nova Scotia senior economist and commodities analyst, in her report(Mohr 2013)[18] on the economic advantages to Energy East, argued that, Western Canada Select, the heavy oil marker in Alberta, "could have earned a much higher price in India than actually received" in the first half of 2013 based on the price of Saudi Arabian heavy crude delivered to India" if the pipeline had already been operational.[23] In her report, Bohr predicted that initially Quebec refineries, owned by Suncor Energy Inc. and Valero, for example could access comprise light oil or upgraded synthetic crude from Alberta’s oil sands via Energy East to displace "imports priced off more expensive Brent crude."[23] In the long term, super tankers using the proposed Irving/TransCanada deep-sea Saint John terminal could ship huge quantities of Alberta's blended bitumen, such as WCS to the super refineries in India. Mohr predicted in her report that the price of WCS would increase to US$90 per barrel in July, 2013 up from US$75.41 in June."[23]

Canada's largest refinery, capable of processing 300,000 barrels of oil per day, is owned and operated by Irving Oil, in the deep-water port of Saint John, New Brunswick, on the east coast. A proposed $300-million deep water marine terminal, to be constructed and operated jointly by TransCanada and Irving Oil Ltd., would be built near Irving Oil's import terminal with construction to begin in 2015.(CBC 2013)[25]

Maine-based Portland–Montreal Pipe Line Corporation, which consists of Portland Pipe Line Corporation (in the United States) and Montreal Pipe Line Limited (in Canada), is considering ways to carry Canadian oil sands crude to Atlantic tidewater at Portland's deep-water port.(Reuters 2013)[26] The proposal would mean that crude oil from the oil sands would be piped via the Great Lakes, Ontario, Quebec and New England to Portland, Maine. The pipelines are owned by ExxonMobil and Suncor.

Bull or Bear Markets in Crude Oil in the US

Investors placed bullish bets in the six weeks from January through February 8, 2013, on oil futures based on the U.S. central bank's bond-buying program that "adds liquidity to the financial markets." The demand, and therefore the price, of commodities in general and oil in particular falls if and when such a program is scaled back. Even a rumor that a hedge fund is in trouble and was liquidating positions can cause the price of U.S. crude oil to fall. Signs of strong demand of crude oil from China and India with hopes of a tighter market can raise the price and even an oil rally. Investors also refer to the Energy Information Administration reports on U.S. inventories of commercial crude oil. The higher the inventory of crude oil, the lower the price. U.S. inventories of commercial crude oil hit their highest level in February 15, 2013 since July 2012. (Krishnan and Brown 2013-02-21)."[27]

Western Canadian Select Derivatives Market

Most Western Canadian Select is piped to Illinois for refinement and then to Cushing, Oklahoma for sale. Western Canadian Select (WCS) futures contracts are available on the Chicago Mercantile Exchange (CME)while bilateral over-the-counter WCS swaps can be cleared on Chicago Mercantile Exchange (CME)'s ClearPort or by NGX.[4]

Refineries

WCS is transported from Alberta to refineries with capacity to process heavy oil from the oil sands. The Petroleum Administration for Defense Districts (Padd II), in the US Midwest, have experience running the WCS blend.[4][13] Most of WCS goes to refineries in the Midwestern United States where refineries "are configured to process a large percentage of heavy, high-sulfur crude and to produce large quantities of transportation fuels, and low amounts of heavy fuel oil."[13] While the US refiners "invested in more complex refinery configurations with higher processing capability" that use "cheaper feedstocks" like WCS and Maya, Canada did not. While Canadian refining capacity has increased through scale and efficiency, there are only 19 refineries in Canada compared to 148 in the United States.(Hackett 2013)[13]

WCS crude oil with its "very low API (American Petroleum Institute) gravity and high sulphur content and levels of residual metals"(Hackett 2013)[13] requires specialized refining that few Canadian refineries have. It can only be processed in refiners modified with new metallurgy capable of running high-acid (TAN) crudes.

"The transportation costs associated with moving crude oil from the oil fields in Western Canada to the consuming regions in the east and the greater choice of crude qualities make it more economic for some refineries to use imported crude oil. Therefore, Canada’s oil economy is now a dual market. Refineries in Western Canada run domestically produced crude oil, refineries in Quebec and the eastern provinces run primarily imported crude oil, while refineries in Ontario run a mix of both imported and domestically produced crude oil. In more recent years, eastern refineries have begun running Canadian crude from east coast offshore production." [13]

If the Keystone pipeline were completed and WCS could reach Gulf Coast refineries and tidewater,[28] it would "narrow the spread or discount faced by Canadian crude producers"(Moore et al. 2011:3).[13] and WCS would "be priced at the equivalent discount of Maya" (Moore et al. 2011:2).[13] page 2

US refineries import large quantities of crude oil from Canada, Mexico, Columbia and Venezuela, and they began in the 1990s to build coker and sulfur capacity enhancements to accommodate the growth of these medium and heavy sour crude oils while meeting environment requirements and consumer demand for transportation fuels. "While US refineries have made significant investments in complex refining hardware, which supports processing heavier, sourer crude into gasoline and distillates, similar investment outside the US has been pursued less aggressively (Moore et al. 2011).[13] Medium and heavy crude oil make up 50% of US crude oil inputs and the US continues to expand its capacity to process heavy crude (Moore et al. 2011).[13]

Large integrated oil companies that produce WCS in Canada have also started to invest in upgrading refineries in order to process WCS (Moore et al. 2011:34).[13]

British Petroleum refinery in Whiting, Indiana(Dezember 2012)[29][30] is the sixth largest in the US and can refine more than 400,000 barrels of crude oil per day.(2012 & oilandgasonline)[31] As of 2012, BP is making a multi-billion investment to modernise the refinery in order to allow it to process heavier crude oil.(Fox 2012)[32][33] The Toledo refinery in northwestern Ohio, in which BP has invested around $500 million on improvements since 2010, is a joint venture with Husky Energy, which operates the refinery, and processes approximately 160,000 barrels of crude oil per day.[34][35] Since the early 2000s, the company has been focusing its refining business on processing crude from oil sands and shales.[30][36]

Lloydminster heavy oil, a component in the Western Canadian Select (WCS) heavy oil blend, is processed at the Co-op Refinery Complex heavy oil upgrader which had a fire in the coker of the heavy oil upgrader section of the plant, on February 11, 2013. It was the third major incident in 16 months, at the Regina plant.[37] The price of Western Canadian Select weakened against U.S. benchmark West Texas Intermediate (WTI) oil.[37]

Royalties

Royalty rates in Alberta are based on the price of WCS discounted against WTI. "Based on the high correlation with WTI37 (0.95 or 95 percent of the difference is explained by substituting WTI for WCS on the world market after adjusting for quality differences (Moore et al. 2011:37)."[13]

The Province of Alberta receives a portion of benefits from the development of energy resources in the form of royalties that fund in part programs like health, education and infrastructure (Energy Alberta 2009:1).[38]

In 2006-7 the oil sands royalty revenue was $2.411 billion. In 2007/08 it rose to $2.913 billion and it continued to rise in 2008/09 to $2.973 billion. Following the revised Alberta Royalty Regime it fell in 2009/10 to $1.008 billion (Budget 2009 cited in Energy Alberta 2009:10)[38]). In that year Alberta's total resource revenue "fell below $7 billion...when the world economy was in the grip of recession." [39] By 2013 [39]

In February 2012 the Province of Alberta "expected $13.4 billion in revenue from non-renewable resources in 2013-14 (O'Donnell and Gerein 2013-01-24)." [39] By January 2013 the province was anticipating only $7.4 billion. "30 per cent of Alberta’s approximately $40-billion budget is funded through oil and gas revenues. Bitumen royalties represent about half of that total (O'Donnell and Gerein 2013-01-24)."[39] In 2009/10 royalties from the oil sands amounted to $1.008 billion (Budget 2009 cited in Energy Alberta 2009:10)[38])

In order to accelerate development of the oil sands, the federal and provincial governments more closely aligned taxation of the oil sands with other surface mining resulting in "charging one per cent of a project’s gross revenues until the project’s investment costs are paid in full at which point rates increased to 25 per cent of net revenue. These policy changes and higher oil prices after 2003 had the desired effect of accelerating the development of the oil sands industry (Energy Alberta 2009:1).[38]" A revised Alberta Royalty Regime was implemented in January 1, 2009 (Energy Alberta 2009:7).[38] through which each oil sands project pays a gross revenue royalty rate of 1% (Oil and Gas Fiscal Regimes 2011:30).[40] [41] [42][43] to a maximum of 9% [44] "payout" (Oil and Gas Fiscal Regimes 2011:30). [45][40] [46]

In order to encourage growth and prosperity and due to the extremely high cost of exploration, research and development, oil sands and mining operations pay no corporate, federal, provincial taxes or government royalties other than personal income taxes as companies often remain in a loss position for tax and royalty purposes for many years. Defining a loss position becomes increasingly complex when vertically-integrated multi-national energy companies are involved. Suncor claims their realized losses were legitimate and that Canada Revenue Agency (CRA) is unfairly claiming "$1.2-billion" in taxes which is jeopardizing their operations.[47]

Oil Sands Royalty Rates (Energy Alberta 2009:18)[38]

"Bitumen Valuation Methodology (BVM) is a method to determine for royalty purposes a value for bitumen produced in oil sands projects and either upgraded on-site or sold or transferred to affiliates. The BVM ensures that Alberta receives market value for its bitumen production, taken in cash or bitumen royalty-in-kind, through the royalty formula. Western Canadian Select (WCS), a grade or blend of Alberta bitumens, diluents (a product such as naphtha or condensate which is added to increase the ability of the oil to flow through a pipeline) and conventional heavy oils, developed by Alberta producers and stored and valued at Hardisty, AB was determined to be the best reference crude price in the development of a BVM" (Energy Alberta 2009:17)[38]

Price WTI C $/bbl Royalty Rate on Gross Revenue Royalty Rate on Net Revenue
Below C$55 1.00% 5.00%
C$60 1.62% 26.15%
C$75 3.46% 29.62%
C$100 6.54% 35.38%
Above C$125 9.00% 40.00%

Bitumen Bubble

In January 2013, the Premier of Alberta, Alison Redford, used the term bitumen bubble to explain the impact of a dramatic and unanticipated drop in the amount of taxes and revenue from the oil sands linked to the deep discount price of Western Canadian Select against WTI and Maya crude oil, would result in deep cuts in the 2013 provincial budget.[48] In 2012 oil prices rose and fell all year. Premier Redford described the "bitumen bubble" as the differential or "spread between the different prices and the lower price for Alberta's Western Canadian Select (WCS)." In 2013 alone, the "bitumen bubble" effect will result in about six billion dollars less in provincial revenue.[49]

Notes

See also

References

  1. ^ a b "Platts Assesses Ex-Cushing Western Canadian Select at $70.78 per Barrel: Brings transparency to the US value of Canadian Oil as Seaway Takes Oil to Gulf". Houston, Texas: Platts. 1 June 2012.
  2. ^ a b c d e f g h Cenovus (April 29, 2010). "Western Canadian Select (WCS) fact sheet".
  3. ^ a b CAPP (2012). Technical Publication: Oil Sands Bitumen: Valuation Methodology (Report). Canadian Association of Petroleum Producers (CAPP).
  4. ^ a b c d e f g Argus (May 2012). WCS at Cushing: A new spot market for heavy sour Canadian crude emerges (Report). Argus White Paper. Argus Media.
  5. ^ Suncor (1 March 2013). Common industry terms (PDF) (Report). Annual Information Form. Suncor.
  6. ^ a b TD (14 March 2013). Drilling Down on Crude Oil Differentials (PDF) (Report). TD Economics.
  7. ^ a b c "Methodology and Specifications Guide: Crude Oil" (PDF). Platts. January 2013.
  8. ^ a b c Natural Resources Canada NRC (2011). Canadian Crude Oil, Natural Gas and Petroleum Products: Review of 2009 & Outlook to 2030 (PDF) (Report). Government of Canada. p. 9. ISBN 978-1-100-16436-6. {{cite report}}: Unknown parameter |city= ignored (|location= suggested) (help); Unknown parameter |month= ignored (help)
  9. ^ Cenovus (29 April 2010). "Western Canadian Select (WCS) fact sheet".
  10. ^ Richard K. Lattanzio (15 March 2013). Canadian Oil Sands: Life-Cycle Assessments of Greenhouse Gas Emissions (PDF) (Report). Congressional Research Service.
  11. ^ CNRL (2012). "Canadian Natural Resources Limited Announces 2012 Third Quarter Results". Globe and Mail. Toronto, ON.
  12. ^ Based on data on prices and differentials from Canadian Natural Resources Limited (TSX:CNQ) (NYSE:CNQ)
  13. ^ a b c d e f g h i j k l m M.C. Moore; S. Flaim; D. Hackett; S. Grissom; D. Crisan; A. Honarvar (December 2011). "Catching the Brass Ring: Oil Market Diversification Potential for Canada" (PDF). 4 (16). Calgary, Alberta: School of Public Policy, University of Calgary. {{cite journal}}: Cite journal requires |journal= (help) Cite error: The named reference "UofC2013" was defined multiple times with different content (see the help page).
  14. ^ a b Van Loon, Jeremy (21 January 2013). "World's Cheapest Oil Crimps Alberta Budget With Price Gap". Bloomberg.
  15. ^ PR (8 July 1993). Gale, Cengage Learning (ed.). "Shell/PEMEX Billion Dollar Refinery Construction Project Underway". Houston, Texas: PR Newswire, The Free Library. Retrieved February 10, 2013. {{cite web}}: Check |url= value (help)
  16. ^ a b PSAC (21 August 2013a). "Industry Statistics & Information: Market & Commodity News". First Energy Capital.
  17. ^ PSAC (26 April 2013). "Industry Statistics & Information: Market & Commodity News". First Energy Capital.
  18. ^ a b c d Patricia Mohr. Commodities (PDF) (Report).
  19. ^ a b c Hussain, Yadullah (25 April 2013). "Alberta exploring at least two oil pipeline projects to North". Financial Post.
  20. ^ Vanderklippe, Nathan (22 January 2013). "Oil differential darkens Alberta's budget". Calgary, Alberta: Globe and Mail.
  21. ^ a b Goodman, Lee-Anne (22 May 22, 2013). "Republicans aim to take Keystone XL decision out of Obama's hands". The Canadian Press. {{cite news}}: Check date values in: |date= (help)
  22. ^ Sabina Zawadzki; David Sheppard (5 August 2013). "TransCanada's Energy East pipeline to transform North American oil industry". Financial Post.
  23. ^ a b c d e f g [1]
  24. ^ "About Energy East Pipeline". TransCanada. 2013. Retrieved 20 August 2013.
  25. ^ "Irving Oil's plans for land worry environmentalist". CBC. 12 August 2013.
  26. ^ Dave Sherwood (22 May 2013). "Maine pipeline plan hinges on flows to Montreal". South Portland, Maine: Reuters. Retrieved 22 August 2013.
  27. ^ Barani Krishnan; Veronica Brown (February 21, 2013). "COMMODITIES-Oil, metals on defensive; Fed puts investors on edge". New York/London. Retrieved February 2013. {{cite news}}: Check date values in: |accessdate= (help)
  28. ^ Getting to tidewater is a term used by industry and government to refer to the need for the oil sands products to be transported to the north, south, east and west coasts raising the price of WCS per barrel in an international market.
  29. ^ "United States: Refining". BP. 2012. Retrieved 25 July 2012.
  30. ^ a b Ryan Dezember (6 March 2012). "BP Draws Buyer Interest in Two Refineries". The Wall Street Journal. Retrieved 7 June 2012.
  31. ^ oilandgasonline (23 May 2012). "BP Agrees To Add More Than $400M In Pollution Controls At Indiana Refinery And Pay $8M Clean Air Act Penalty". Oil and Gas Online. Retrieved 14 June 2012.
  32. ^ Fox (23 May 2012). "US reaches pollution agreement at BP Indiana plant". Fox News. Associated Press. Retrieved 14 June 2012.
  33. ^ Bowdeyah Tweh (13 January 2012). "BP CEO: We want your trust". nwi.com. Retrieved 30 July 2012.
  34. ^ "BP-Husky Toledo refinery set for September turnaround". Reuters UK. 24 July 2012. Retrieved 27 July 2012.
  35. ^ "BP-Husky OKs $2.5B for project to boost oil volume". Toledo Blade. 1 December 2010. Retrieved 30 July 2012.
  36. ^ T.J. Aulds (6 June 2012). "Rumor mill in high gear over BP buyers". The Daily News (Galveston). Archived from the original on 11 July 2012. Retrieved 12 February 2013.
  37. ^ a b Welsch, Edward; Harvey, Christine (11 February 2013). "Consumers Co-op Shuts Coker at Saskatchewan Plant After Fire". Bloomberg.
  38. ^ a b c d e f g Energy Economics: Understanding Royalties (PDF) (Report). Edmonton, Alberta: Government of Alberta. September, 2009. p. 17. {{cite report}}: Check date values in: |date= (help)
  39. ^ a b c d Sarah O'Donnell; Keith Gerein (January 24, 2013). "Bitumen bubble' costing Alberta billions, Redford says". Edmonton Journal.
  40. ^ a b Oil and Gas Fiscal Regimes (PDF) (Report). Alberta Energy. June 2011. Retrieved February 10, 2013.
  41. ^ Oil and Gas Fiscal Regimes 2011 summarizes the petroleum fiscal regimes for the western provinces and territories.
  42. ^ When the price of oil per barrel is less than or equal to $55/bbl indexed against West Texas Intermediate (WTI) (Oil and Gas Fiscal Regimes 2011:30).
  43. ^ indexed to the Canadian dollar price of West Texas Intermediate (WTI) (Oil and Gas Fiscal Regimes 2011:30).
  44. ^ When the price of oil per barrel is less than or equal to $120/ bbl indexed against West Texas Intermediate (WTI) (Oil and Gas Fiscal Regimes 2011:30).
  45. ^ i.e. the first time when the developer has recovered all the allowed costs of the project, including a return allowance on those costs equal to the Government of Canada long-term bond rate ["LTBR"] (Oil and Gas Fiscal Regimes 2011:30)
  46. ^ [Oil and Gas Fiscal Regimes| http://www.energy.alberta.ca/Tenure/pdfs/FISREG.pdf] 2011 summarizes the petroleum fiscal regimes for the western provinces and territories.
  47. ^ Nathan Vanderklippe (February 6, 2013). "Suncor's $1.5-billion writedown puts oil sands project in jeopardy". The Globe and Mail.
  48. ^ Kleiss, Karen (26 April 2013). "Bitumen bubble doubts stem from lack of trust in government, opposition says". Edmonton Journal. Retrieved 26 April 2013.
  49. ^ Redford, Premier Allison (24 January 2013). "Premier's Address". Government of Alberta.

External links

Retrieved from "https://en.wikipedia.org/w/index.php?title=Western_Canadian_Select&oldid=569942138"