RBN’s Daily Energy Blog and Insights sharpen your energy IQ through fundamentals-based analysis that makes sense of North America’s energy market dynamics.
Natural gas production in the Gulf of Mexico (GOM) has been falling for 15 years, hurt first by hurricane-related rig damage, then more recently by the side effects of the BP/Macondo disaster, the on-shore sale boom, and the resulting sag in gas prices.
Houston area refineries are currently operating with about a third less onshore storage (measured in storage days) than comparable refineries in other regions. Waterborne crude imports help to alleviate the challenges that this constraint can cause.
After a WSJ story broke in late June that the Commerce Department’s Bureau of Industry and Security (BIS) had permitted the export of condensates by Enterprise and Pioneer, a good number of additional export requests were received by the agency. Then a couple of weeks ago, Reuters reported
Eastern Canadian refineries are importing record volumes of light US crude - 263 Mb/d in May 2014 according to the Energy Information Administration (EIA).
The New England states and ISO-New England, which manages the region’s electric grid, are taking steps to keep the lights on during polar vortex events until new natural gas pipeline capacity through New England comes online.
A study released yesterday (August 4, 2014) by the North Dakota Petroleum Council (NDPC) details the final results of work they commissioned to extensively sample and test North Dakota crude oil.
US natural gas liquids (NGL) production is growing fast, and surplus volumes are moving to export markets. NGL production from natural gas processors increased from 1.7 MMb/d in early 2009 to 3.0 MMb/d this year (2014), and it is expected to continue growing to 4.5 MMb/d by 2019.
The polar vortex events this past winter provided a jolting reminder to New England’s electricity sector that natural gas transmission infrastructure in the increasingly gas-dependent region needs further expansion.
Ever since US crude production began to increase in 2009 after 40 years of decline from its peak in 1970, refineries have been processing higher crude volumes.
For gas producers in Appalachia, this has not been such a good summer for basis – the price they get for their gas versus the benchmark at Henry Hub, LA. Basis in the eastern part of the Marcellus has been particularly weak, with negative differentials extending into New York. E
