Inadequate — and REMANDED! Here’s the Appellate Court decision, just out:

Bottom line:
However, the commission acted in a manner unsupported by substantial evidence and arbitrary and capricious when it determined the FEIS adequate despite its failure to address the issue—raised during scoping and in public comments on the DEIS—of how an oil spill from Enbridge’s Line 3 project would impact Lake Superior and its watershed. Accordingly, we reverse the commission’s adequacy decision and remand for further proceedings consistent with this decision.

Love it when that happens…

There’s been a lot of speculation about the low wind production during the low-low temps at the end of January.  Turns out there’s an issue not anticipated by MISO that they’re going to have to deal with.  I heard it first from a little birdie who heard it while in a flock…

And now from a bigger birdie with primary info from the horse itself: Turbines apparently have a -22F degree or so automatic shutoff, so when it was way cold, they shut off.

Unidentified temperature cutoff thresholds challenged
wind forecasting in morning of Jan 30. Unexpected
shutoffs led to a large deviation from planned output.

Ummmmm, that’s a problem.  Here’s the MISO update on that:

20190207 MSC Item 04 Jan 30 Max Gen Event317407

And from my “good friends” at Center of the American Experiment, who got it twisted again:

Bitter Cold Shows Reliable Energy Sources Are Critical

Twisted?  What’s wrong with that?  Well, their focus is that it was an intermittency issue, which it was not.  As above, it was that shut-off at -22!  And note the part in their post about “unforeseen.”  And THAT is the problem, because the -22 cut-off was not integrated into the MISO modeling, plans, and that was a surprise, and they’re going to have to figure that one out.  It’s possible, probable, and now apparently likely that we will have another -22 degree spell in the foreseeable future.  So get with it, MISO!

And natural gas.  I keep thinking about that CenterPoint natural gas underground storage dome.  7 billion cubic feet at least.  There’s a lot of gas in storage.  Are they relying on pipelines, and does that reliance take into account the many newer natural gas plants?  Does Xcel share/buy from CenterPoint, take advantage of the storage?  What is the impact of so many electric generators fueled by natural gas?  They did recently do a lot of natural gas pipeline work on that primary north/south line running north from Waseca, was that a capacity expansion… upgrades or maintenance ??

So why is no one talking about all the oil and gas drilling around Cook Inlet where the MASSIVE earthquake was in Alaska?  Primary info HERE!  See for yourself.

Check this video of all the earthquakes in Alaska since the big one.

And as we know, there are seismic impacts:

You can find it here at


Today the Motions for Reconsideration for Enbridge’s Line 3 pipeline were due, and here they are:



Friends of the Headwaters_20189-146618-01


Red Lake_White Earth_Honor The Earth_20189-146620-01

Young Climate Intervenors_20189-146623-01

Whew, that’s a lot to read, but it’s instructive!!



I’ve been hearing a lot of comments about an Inspector General report, in the last few days,for example:

The Public Has Been Ignored for Too Long on Pipelines

Oh so true!!  That’s how it is in all infrastructure proceedings I’ve been involved with and observed. And as I sit here with a terrified doggy coping with a storm and fireworks, I’ve got time to look into it.  She’s watching the storm come in from the west, have the office screen door open, oh, she’s a freakin’.  Not drooling, that’s a start, Xanax might be doing something, but not much…

Anyway, a gas pipeline group I’m in was posting articles about this, and so I started with the post, no link… read the article, with many links, but no link to the Inspector General report, so followed the links, still no report.  OK, fine, it’s GOOGLE TIME!

DOE-OIG Audit-18-33 – FERC’s Certification Process

The bottom line?  There is an Office of Inspector General Audit, a NRDC commissioned report, AND FERC published notice of a comment period, NOTICE OF A COMMENT PERIOD 4/25/2018 AND A COMMENT PERIOD THAT ENDED 6/25.  BUT IT’S BEEN EXTENDED!

Here’s the Notice in the Federal Register, April 25, 2018:

2018-08658_FR 4-25-2018

Here’s the notice of extension of the comment period:

20180523175645-PL18-1-000_Comment Extension

DATES: Comments are due July 25, 2018.



What did the FERC Office of Inspector General have to say?  In summary:

Opening a new docket to solicit comment on various points would be an appropriate vehicle by which FERC could obtain broad public input and fresh consideration of the substantial recent and ongoing changes in energy industries and what changes in FERC’s certification policy may be appropriate in light of these transitions. The questions that could be posed for comment might raise some of the same types of issues examined by FERC two decades ago, as well as other ones raised by the trends of the past two decades. Examples of such questions include:

 Should FERC develop more prescriptive standards for reviewing applications for new pipelines, in light of the increasingly uncertain forecasts of the need for incremental pipeline capacity?
 Do changes underway in both the gas and electric industries – and the increasingly strong interrelationship between them – warrant a more integrated assessment of sectoral demand and electricity market forces in assessing natural gas pipeline need in Section 7 proceedings?
 Should FERC require regional planning regarding gas transportation resources similar to the regional planning requirement imposed on electric transmission owners?
 Should FERC apply a higher threshold standard and greater scrutiny with respect to demonstration of need, market demand, and public benefit where an affiliate (e.g., gas LDC, electric utility, and/or independent power producer) is involved in the proposed project?
 Should determination of need for a proposed pipeline project be the threshold determination (instead of the current threshold determination, which is whether the project could proceed without subsidies from existing customers)?
 Should FERC’s balancing of benefits against adverse impacts be expanded to include noneconomic factors (e.g., should environmental impacts be among the adverse impacts FERC considers while applying the balancing test)?
 Should FERC give deference to state regulatory approvals (e.g., of contracts between pipeline companies and affiliated shippers, including either local distribution companies or power plants) only when such approvals involve a regulatory review of whether such contracts represent the least-cost method of serving such demand, taking into account other strategies (e.g., energy efficiency in the case of an LDC contract, or dual-fuel capability at the power plant, or application of technologies to increase throughput on existing pipeline capacity)?
 Should FERC require a demonstration of need and public benefit based on a showing that non-pipeline alternatives have been considered as options to meet the demand of shippers (e.g., an integrated gas/electric resource plan or an integrated gas/electric reliability study, energy efficiency programs in the case of an LDC contract, dual-fuel capability at a power plant, or adoption and application of technologies to increase throughput on existing pipeline capacity)?
 Should FERC impose a greater burden to show that a pipeline is needed when it is proposed to gain market share rather than to meet new market demand?
 How should FERC’s policy take into account the views of a variety of interested constituencies (including competitors, customers, landowners, local communities, and others affected directly and indirectly by the pipeline and by the impacts of gas combustion), many of whom may have limited access to resources to participate as full parties in specific pipeline-review cases?
 How should FERC weigh the relative distribution of benefits and burdens across those interested and affected constituencies?
 How should FERC take into account the potential for stranded costs of new pipeline capacity that is later determined to be no longer needed in light of changes in the nation’s current and future energy mix?
 Should FERC consider new ways for pipeline applicants to internalize the long-term monetary and non-monetary risks associated with near-term capacity investment decisions?

There was also a NRDC report, done by Susan Tierney:


This report was more concerned about broader issues, such as OVERBUILDING, as happened in electric transmission:

Although there is interest in some regions to add pipeline capacity to alleviate wintertime gas-transportation constraints (and the pricing impacts that result), some industry observers are increasingly concerned about the potential to overbuild capacity on the interstate system in light of anticipated transitions in the nation’s energy system in the future.  And there are growing questions about FERC’s balancing of public benefits versus adverse consequences in the context of case-by-case review of applications.

And listing factors that should be considered in updating FERC procedures:

Key Factors Warranting a Refresh of FERC’s 1999 Policy Statement:

Significant industry changes led to adoption of the 1999 Policy Statement, but rapid industry changes and trends since then call into question the policy’s continued appropriateness.

A new, generic proceeding is a better forum than individual case dockets for addressing implications of wide-ranging industry changes and trends.

The meaning and application of FERC goals have evolved over the decades.

The interaction of gas and electric industries suggests a need for integrated assessment of both markets.

Other factors originally highlighted in FERC’s 1999 Policy Statement remain important but warrant a reassessment in light of changes. Changes in the gas and electric industries and an increasingly active and oppositional context in which FERC’s pipeline certification cases occur indicate the need for review of factors FERC initially emphasized. These factors include:

 the relevance and magnitude of pre-certification contractual commitments and/or precedent agreements;
 the nature of relationships between pipeline developers and natural gas LDC, electric utility, and/or independent power producer affiliates;
 the balancing of public benefits against adverse impacts in an era of debate over power system reliability implications and accelerating evidence of and concern over GHG emissions and climate-change risks resulting from current and future combustion of natural gas;
 complications in assessing need and impacts across pipeline owners in an era of rapidly expanding changes and growth in production regions and consumption patterns; and
 trade-offs across the interests of gas-consuming populations and those of communities impacted by gas infrastructure.

This is a good assessment of where we’re at.  BUT, the many things raised by Tierney in NRDC’s report were not addressed in the FERC Office of Inspector General report.  And yes, those things addressed by the Inspector General are also oh-so-relevant.  So there’s a lot to do!

DATES: Comments are due June 25, 2018.

We have three weeks.  Let’s get cracking!