The OPEC Plus Joint Technical meeting did not offer any concrete decisions on whether they would extend cuts by 6 or 9 months but at least suggested that it would be one or the other. Oh sure, the Saudi Energy Minister is saying that the jury is still out on an oil output cut extension, yet the market feels this is just a way for the group to under promise and over deliver. While this fell short of what market bulls were hoping for, the expectations for some type of extension was better than a sharp stick in the eye.
Geopolitical risk to supply may be focusing again on Nigeria. Reuters is reporting that oil companies have asked security services to tighten surveillance as violent anti-police brutality protests and the expected sacking of hundreds of workers worsen desperation in the region, industry sources told Reuters. Already unemployment is above 40% in Nigeria’s energy regions and observers say further job losses could aggravate problems of pipeline tapping, illegal oil refining and pirate attacks.
Interestingly, the rates for storing oil are soaring. Reuters reports that global container shipping rates have surged to records on a spike in restocking demand in the United States and Europe, container scarcity at export hubs, and changes in freight flows because of the coronavirus pandemic, shipping sources said. The Freightos Baltic Global Container Index (FBX), a weighted average of 12 major global container routes, rose to $2,359 per forty-foot equivalent (FEU) container this week, the highest on record and up 30% since July 1. The cost to ship a container from China to the U.S. East Coast, a key global retail market, topped $4,750 this week, up 42% since July and a new record.
Instead, working stocks ended the first week in November only 175 billion cubic feet (5%) above the five-year average, well within the typical yearly variation. With stocks normalizing, futures prices more than doubled between June and the start of November, from $1.50 per million British thermal units to more than $3.20. What happens next, Kemp says, depends critically on temperatures. Electricity producers have continued to retire coal-fired generators, ensuring marginal energy consumption in any cold spell will rely on gas more than ever before. If there is a sustained period of colder than normal weather in December and January, such as in 2016/17 and 2017/18, inventories will dwindle rapidly and push up prices sharply. If temperatures remain close to the seasonal average, or warmer, gas prices are likely to fall back towards the summer lows to limit a renewed inventory build.
Andrew Weissman of EBW Analytics agrees. He says that the natural gas market is staring down projections for repeated triple-digit storage builds and the resumption of a growing year-over-year storage surplus, likely weighing on NYMEX gas futures in the near term. Already, falling injections into fast-cycling storage facilities may indicate marketers are holding out for lower pricing before building summer inventories. Falling weather-driven demand, weakening spot market prices at Henry Hub, and a likely boost in production with the end of spring pipeline maintenance, may all act as additional near-term bearish catalysts for natural gas into early June. By mid-to-late June, however, NYMEX gas may begin to show strength as rising power sector demand, growing Mexican exports, firm LNG demand, and seasonal trends point to likely price increases into mid-summer.
