So far in 2017, increased hydroelectric generation and solar power generation in California have contributed to lower natural gas-fired power generation in the California Independent System Operator (CAISO) region, the electric system operator for much of the state. In a late April update to several state agencies responsible for planning and managing California’s energy reliability, Southern California Gas Company (SoCalGas) outlined its views regarding several assumptions and challenges for safely and reliably serving its customers in Southern California over the coming summer and winter.
SoCalGas cited expectations of warmer-than-normal summer temperatures driving increased electricity demand as one of the factors raising potential energy reliability concerns. The ability to draw natural gas from storage fields in the SoCalGas system continues to be affected by operating restrictions on SoCalGas's Aliso Canyon field, an underground natural gas storage facility with a capacity of 86 billion cubic feet (Bcf), or 64% of SoCalGas's total storage capacity.
This facility is still recovering from the leak that was initially detected in late October 2015 and plugged in February 2016. Following the leak, Aliso Canyon natural gas storage levels were reduced to about 15 Bcf, and total combined inventories at all of SoCalGas's storage facilities remained about 60 Bcf throughout most of 2016.
In June 2016, the California Public Utility Commission (CPUC) conditionally authorized SoCalGas to withdrawthe remaining 15 Bcf at Aliso Canyon. Storage injections into that field would require additional regulatory approval. A total of 19 Bcf was withdrawn from the SoCalGas system from November 2016 through the end of March 2017, including withdrawals from Aliso Canyon during a two-day cold snap in late January. Over the five prior November-through-March periods, withdrawals averaged nearly 60 Bcf, ranging from 31 Bcf to 103 Bcf. As of May 16, SoCalGas's inventory stands at 43 Bcf.
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Headline crude prices for the week beginning 11 February 2019 – Brent: US$61/b; WTI: US$52/b
Headlines of the week
Midstream & Downstream
Global liquid fuels
Electricity, coal, renewables, and emissions
2018 was a year that started with crude prices at US$62/b and ended at US$46/b. In between those two points, prices had gently risen up to peak of US$80/b as the oil world worried about the impact of new American sanctions on Iran in September before crashing down in the last two months on a rising tide of American production. What did that mean for the financial health of the industry over the last quarter and last year?
Nothing negative, it appears. With the last of the financial results from supermajors released, the world’s largest oil firms reported strong profits for Q418 and blockbuster profits for the full year 2018. Despite the blip in prices, the efforts of the supermajors – along with the rest of the industry – to keep costs in check after being burnt by the 2015 crash has paid off.
ExxonMobil, for example, may have missed analyst expectations for 4Q18 revenue at US$71.9 billion, but reported a better-than-expected net profit of US$6 billion. The latter was down 28% y-o-y, but the Q417 figure included a one-off benefit related to then-implemented US tax reform. Full year net profit was even better – up 5.7% to US$20.8 billion as upstream production rose to 4.01 mmboe/d – allowing ExxonMobil to come close to reclaiming its title of the world’s most profitable oil company.
But for now, that title is still held by Shell, which managed to eclipse ExxonMobil with full year net profits of US$21.4 billion. That’s the best annual results for the Anglo-Dutch firm since 2014; product of the deep and painful cost-cutting measures implemented after. Shell’s gamble in purchasing the BG Group for US$53 billion – which sparked a spat of asset sales to pare down debt – has paid off, with contributions from LNG trading named as a strong contributor to financial performance. Shell’s upstream output for 2018 came in at 3.78 mmb/d and the company is also looking to follow in the footsteps of ExxonMobil, Chevron and BP in the Permian, where it admits its footprint is currently ‘a bit small’.
Shell’s fellow British firm BP also reported its highest profits since 2014, doubling its net profits for the full year 2018 on a 65% jump in 4Q18 profits. It completes a long recovery for the firm, which has struggled since the Deepwater Horizon disaster in 2010, allowing it to focus on the future – specifically US shale through the recent US$10.5 billion purchase of BHP’s Permian assets. Chevron, too, is focusing on onshore shale, as surging Permian output drove full year net profit up by 60.8% and 4Q18 net profit up by 19.9%. Chevron is also increasingly focusing on vertical integration again – to capture the full value of surging Texas crude by expanding its refining facilities in Texas, just as ExxonMobil is doing in Beaumont. French major Total’s figures may have been less impressive in percentage terms – but that it is coming from a higher 2017 base, when it outperformed its bigger supermajor cousins.
So, despite the year ending with crude prices in the doldrums, 2018 seems to be proof of Big Oil’s ability to better weather price downturns after years of discipline. Some of the control is loosening – major upstream investments have either been sanctioned or planned since 2018 – but there is still enough restraint left over to keep the oil industry in the black when trends turn sour.
Supermajor Net Profits for 4Q18 and 2018
- 4Q18 – Net profit US$6 billion (-28%);
- 2018 – Net profit US$20.8 (+5.7%)
- 4Q18 – Net profit US$5.69 billion (+32.3%);
- 2018 – Net profit US$21.4 billion (+36%)
- 4Q18 – Net profit US$3.73 billion (+19.9%);
- 2018 – Net profit US$14.8 billion (+60.8%)
- 4Q18 – Net profit US$3.48 billion (+65%);
- 2018 - Net profit US$12.7 billion (+105%)
- 4Q18 – Net profit US$3.88 billion (+16%);
- 2018 - Net profit US$13.6 billion (+28%)