With the exception of a brief period in the late 1990's when oil prices were too low as to encourage oil sands growth, oil production in Alberta has been in a long term upward trend.
not and that has given some credibility to the peak oil theory. Recent data coming out of Alberta shows a surprising reversal to this trend: Production light and medium oil will reach 500,000 bpd in 2014. In 2011 alone, medium/light oil output increased by 70,000 bpd which represents the largest year on year gain in over a decade; that trend is expected to continue into the near future. Keep in mind that the trend is still very new, between 2002 and 2010 output from conventional sources declined by 33%, 50% since 1995. The last time conventional oil was produced at a rate higher than it currently is, was back in 2006. Remember though that future supply depends a lot more on heavier crude than conventional (the oil sands are on track to account for 88% of Alberta's oil production by 2017 up from 64% in 2007).
--> More than half of oil exports go to refineries in an area known as PADD II in the US Midwest. Because of a glut of supply, Canadian oil is more heavily discounted there than it is in PADD III which is Texas (why getting the Keystone pipeline approved is so important).
--> Export market not diversified : 99% of Canadian oil goes to only one market, the United States.
--> Among lowest royalties in the world, something that makes it easier to attract foreign investment.
--> Canada is home to 90% of the world's oil reserves outside opec.
--> Calgary is home to more than 2,000 petroleum companies. TSX Venture Exchange makes attracting investment easier to do for statups.
At Canadian Natural Resources Limited Canada's leading producer, drills for conventional are are yielding better results; conventional oil production will grow by 17% in 2012 even though the number of wells drilled will be reduced by 62 (956/2000 wells vs 1018/2004 in 2011).
As oil sands production grows, companies such as Canadian Natural Resources are improvising in order to reduce their reliance on water from the Athabasca river, so that they continue to remain below the usage limit set by the province (was 360 million m3 a couple years ago, only about 1% of water from the river is used by the province and oil and gas operations); CNRL now separates water from solids more effectively by injecting carbon dioxide captured from its hydrogen plant into tailings lakes reducing the need for additional water. The Athabasca River is fed by a glacier 1,200 km away. 90% of conventional oil reserves are controlled by state owned oil companies.
Cenovus Energy (more indepth coverage by me can be found at Cenovus Energy production reserves)
On February 15, 2012 Cenovus released data for the 2011 fiscal year and the results are very impressive! Even though the stock was down little more than 1% on the day of the news TD Newcrest upgraded CVE from hold to buy.
Net asset value per share is $37 up 32% from 2010 year-end ($28).
Net Income $1.95/share (+37%) even though operating earnings were +55% to $1.64/share. The company profited $1.478b on the year ($1.081m in 2010, $680m in 2009, $2.487b in 2008).
-> Total proved reserves up 17% to 1.9455 billion barrels of oil equivalent. What's most notable there is the amount of bitumen reserves. On December 31, 2010 bitumen reserves were 1.154B boe. Today they are 1.455B boe an increase of 26%. Contingent resources increased 34% to 8.2B boe. Reserves of light and medium oil (& ngl's) +3.6% to 115M boe but natural gas -13% to 200M boe (which is inline with company plans to focus capital away from gas to bitumen, long-term production target is 400 MMcf/d, 575-600 for 2012). 2P proved + probable reserves +10.7% to 2,660.7M boe.
-> Production: Total Oil/Bitumen/NGL's 134,000 bpd which is up 3.88% vs 2010 (129,000 bpd), up 12.61% vs 2009 (119,000 bpd).
Oil sands +13.56% or 8 bpd to 67,000 bpd, +52.27% vs 2009. Christina Lake 12,000 bpd +50% vs 2010 (4Q2011 150% higher than 4Q2010 20,000 bpd). Quarterly high was 4Q2011 at 75,000 bpd (13.6% higher than 3Q2011 which is the largest quarter to quarter increase in a while).
Conventional oil down 2,000 bpd to 68,000 bpd (Pelican Lake, Weyburn -10% to 36,000 bpd).
Natural gas output took a 737 nosedive (no pun intended :) from 737 MMcf/d (122.8 boe/d) to 656 MMcf/d (~110,000 boe/d). Gas production averaged 837 MMcf/d in 2009 (140 boe/d).
-> Cash flow +33% to $3.3. Operating Cost at CL +23% to $20.2/bbl (+28% not excl fuel). Weyburn's operating costs were also up but they are still roughly half of CL.
Christina Lake consists of seven phases of development. The last phase G won't be completed until the start of 2019. Phase E is 30% complete, phase D is 70% complete. When project is complete Christina Lake will production at a rate of 278,000 bpd (in the last quarter production was only 20,000 bpd).
Last year Suncor's total production was hit hard by the situtation in Libya however there is optimism surrounding the company right now; 3 of its 5 fields there have already resumed operations (Jan 2012).
Also up at Suncor, oil sands output ! In December of 2011 Suncor's oil sands output averaged a monthly record high of 345,000 bpd, that record was broken the next month in January 2012 when 355,000 bpd production was reached.
Remember too, that oil sands output was only 162,000 bpd as recently as May 2011. Suncor finished 2011 averaging just over 10,000 bpd in Libya up from nothing; 2Q of last year it took on a $514 million writedown in the value of its Libyan assets.
Suncor is Canada's largest oil company by market capitalization (though second to Canadian Natural Resources in terms of production) and is the largest producer of oil sands oil through a 12% interest in the Syncrude Canada Ltd. mine, a 41% stake in the Fort Hills mine and operations at Firebag & Mackay river.
Penn West Exploration Penn West 3Q 2011 Report Penn West 4Q 2011 Report
4Q: For the 2011 year 18.0% of total oil and gas sales went to royalty payments ($661m/$3667m) down from 17.8% in 2010. Expenses were 69.0% higher ($1503m --> $2540m) mostly due to the company's gain on dispositions being $910m lower than in 2010.
Prices In the 4Q, light oil and liquids was sold at an average price of $88.76/boe (up 25%), heavy oil $76.88/boe (up 24%), natural gas $3.47/mcf (down 8%). For the year oil and liquids were priced at $86.19 (up 24%), heavy oil $69.07 (up 14%), natural gas $3.78/mmcf (down 10%). HOWEVER because of the company's constantly changing hedging strategy, oil prices realized varied even more; light oil realized in 2011 was $87.18 (up 30% from 2010), heavy oil $76.88 (up 24%), natural gas hedging included, $3.47 (down 15% because in 2010 hedging caused it to gain an additional $0.31/mcf).
In 2011, light oil and ngl's represent 52.31% of total output (85,316/163,094 bpd) up from 49.02% in 2010 (80,706/164,633 bpd) heavy oil 17,892 bpd or 10.97% of production (down from 11.09% 18,260 bpd), natural gas 59,886 boe/d or 36.72% of production (down from 39.9% 65,667 bpd).
Overall, operating netback declined the most for natural gas, -53% to $0.99/mcf. The reserve replacement ratio was 234% up from 122% in 2010, 73% of which was liquids (65% liquids in 2010). Although gross revenue (+19% to $3.604B) and funds flow (+30% to $1.537B) were up, net income was -43% to $638M making earnings per share $1.37 basic (-45%), $1.36 diluted (-45%).
For 2012 the company has hedged 60,000 bpd of liquids at between US$85.53 and US$101.16.
In 2011, light oil and ngl's production was up 6.20% to 85,316 bpd (+2% to 90,185 in the 4Q), conventional heavy oil down 2.0% to 17,892 bpd (but +6.15% to 17,886 bpd in the 4Q), natural gas down 9% to 359 mcf/d (but steady in the last quarter at 364 mcf/d).
Royalties for the 2011 fiscal year: +23% to $16.83/boe for light oil, +15% to $10.01/boe for heavy oil, $0.54/mcf for natural gas (down 7%). Overall risk management loss per boe was $1.06/boe (+212%) but overall netback (profit) per boe was still up 23% due to prices being 20% higher overall.
Risk management losses (hedging prices) were less negative than they were in 2010. $2.03/bbl for light oil (down 25% vs 2010), and $0 for natural gas (compared to a gain of $0.42/mcf in 2010).
3Q: During the first nine months of 2011 revenue from light oil and ngl's went up 36% ($1417 --> C$1921m) compared to only 5% for heavy oil. Peak oil doesn't seem to be a reality for Penn West either: For the first three quarters of 2011 light oil production was up by 7.14% or 5,578 bpd even though total oil production by Penn West declined 1.80% or 2,952 bpd to 161,171 bdp.
9M2011 light oil & ngl's output: 83,675 bbls/d (3Q: 83,287 b/d) total production: 161,171 bbls/d (3Q: 161,323 b/d)
9M2010 light oil & ngl's output: 78,087 bbls/d (3Q: 80,614 b/d) total production: 164,123 bbls/d (3Q: 164,087 b/d)
2012 forecast: total production up to 174-178,000 bpd up from 162-164,000 bpd in 2011. capex spending in 2012 estimated to be $1.6B. Like North American Interests on Facebook