AINEWS
Champlain Hudson Power Express, a 339 mile Quebec to Queens cable that opened in May, has been dark for most of July as drought constrains the hydropower that feeds it.
On July 3, with the New York region under a heat advisory, the state grid pulled 52 GWh from Canada in a single day. A real share of that electricity traveled through a 339-mile high-voltage direct current line running under Lake Champlain, down the Hudson, and into a converter station in Astoria, Queens. The line, called the Champlain Hudson Power Express, had been in service for less than two months. It is the longest underground transmission line in North America, and on that July afternoon it was carrying what it was built to carry: Quebec hydropower into a city whose grid is openly short on capacity.
For most of the rest of July, the cable has not been carrying anything. The line has been offline for stretches that span more than half the month, according to reporting from MIT Technology Review, and the operator's public statements have not yet pinned down a single cause. What is clear is that the constraint is upstream. Quebec is in a drought, and some experts are concerned about how drought will affect the power supply feeding the hydro stations contracted to deliver power on the line. CHPE was sold as a climate hedge for New York. In its first operating summer it is also behaving as a climate import, hauling the hydrology of the source basin along with the electrons.
CHPE runs from a Hydro-Québec substation near Hertel to a converter station in Queens. At roughly 1,250 megawatts of nameplate capacity, the line can supply up to about 20% of New York City's electricity demand when fully dispatched. The private side of the project was financed at roughly $6 billion by Transmission Developers, a Blackstone-backed developer, and Hydro-Québec. Construction started in late 2022. The line was completed in mid-2026, and Governor Hochul marked completion on June 16, a few weeks after commercial operations began. The U.S. Department of Energy had signed off on the cross-border route in 2014, a decade before the cable was finished.
The New York Independent System Operator, the nonprofit that runs the state's bulk power system, has been warning for two consecutive planning years that New York City faces a capacity deficiency in the medium term. The 20% headline figure on CHPE is a design ceiling, not a realized July 2026 share. On a peak summer day, even a partial delivery on the line displaces local gas-fired generation and pulls the city's import balance upward, which is why the U.S. Energy Information Administration has noted that New York is importing more electricity from Canada since CHPE came online. Directionally the line is doing what it was designed to do. Quantitatively, the record on a full summer is still thin.
That is the part that makes the July downtime load-bearing. CHPE is being tested against two questions at once. The first is operational: can a 339-mile, mostly underwater HVDC line be kept running through a New York City summer, with the converter stations, the cooling systems, and the protection equipment all working through heat waves? The second is climatic: when Quebec's reservoirs are short, does the New York end of the cable still get the megawatt-hours the contract calls for? Both questions were always going to be asked. They are now being answered in public, in the line's first month.
Hydro-Québec's grid is more than 99% renewable, according to the Canada Energy Regulator, with the great majority coming from large hydroelectric stations. Wind is growing fast. That mix is the reason CHPE is marketed as a low-carbon asset rather than just a capacity asset, and it is the reason the drought on the source side is more politically visible than a comparable gas-line disruption would be. New York is paying for Quebec electrons, and Quebec electrons are, mostly, water.
The next planning choices will determine whether the template scales. Drought contingency, redundant transmission paths, and storage sized to backfill a HVDC outage are no longer optional. NYISO's interconnection queue is already crowded with data center and electrification load that assumes more imports will be available, and industry coverage describes a state strategy being rewritten around the assumption that hyperscale compute will land near the lines that can feed it. The contractors who built CHPE have a second project on their boards. The question is not whether the next line gets permitted but whether it gets financed, and the answer will turn on the operational record of the first one.
CHPE will be back online. The cable itself is intact. The question for New York's grid planners is whether the early summer's record is read as a teething problem, which a second HVDC line plus storage can absorb, or as a structural signal, which changes the math on every new import contract the state signs. The difference is a few billion dollars a year in capital allocation, and it will show up in the next NYISO reliability report.