Today the U.S. Fish and Wildlife Service (Service) published notice in the Federal Register of a long-anticipated final rule revising its eagle permitting regulations (Revised Eagle Rule). Concurrent with the Revised Eagle Rule, the Service issued a Final Programmatic Environmental Impact Statement (PEIS) analyzing the Eagle Rule revision under the National Environmental Policy Act (NEPA). Although we are still in the process of evaluating the entire package and have concerns with certain aspects of the Revised Eagle Rule, many of the proposed changes represent a step forward for applicants seeking regulatory certainty through the eagle permitting process. Here’s a quick snapshot of the changes:

(Re)extends maximum permit term to 30 years. As we discussed in a previous blog post, in August 2015, the U.S. District Court for the Northern District of California set aside the 30-year tenure provision of the 2013 revisions to the eagle permit regulations on NEPA grounds, concluding that the Service had failed to demonstrate an adequate basis in the record for deciding not to prepare an Environmental Impact Statement or Environmental Assessment. The Revised Eagle Rule, now backed by NEPA analysis that evaluates the 30-year maximum term, once again extends the maximum term for eagle take permits from five to 30 years, subject to recurring five-year check-ins. In the Federal Register notice, the Service acknowledges that “[t]he 5-year maximum duration for programmatic permits appears to have been a primary factor discouraging many project proponents from seeking eagle take permits. Many activities that incidentally take eagles due to ongoing operations have lifetimes that far exceed 5 years. We need to issue permits that align better, both in duration and the scale of conservation measures, with the longer-term duration of industrial activities, such as electricity distribution and energy production. Extending the maximum permit duration is consistent with other Federal permitting for development and infrastructure projects.”

Applies practicability standard to all permits. Under the previous rule, applicants for standard (non-programmatic) permits were required to reduce potential take to a level where it was “practicably” unavoidable, but applicants for programmatic permits were required to meet a higher standard (reducing take through the implementation of advanced conservation practices (ACP) to a level where remaining take is “unavoidable”). The Revised Eagle Rule applies the “practicability” standard to all eagle take permits and removes the “unavoidable” standard from the permit program. Thus, all permits will contain the standard that take must be avoided and minimized to the maximum degree practicable.
Continue Reading U.S. Fish and Wildlife Service Issues Final Revised Eagle Rule

Today, the National Association of Regulatory Utility Commissioners (NARUC) released its final manual on distributed energy resources (DER) compensation.  The draft manual was circulated for review and comment in August 2016, and is intended to help jurisdictions navigate the policy and stakeholder considerations behind DER compensation.

Read our previous post for more information on NARUC’s

Today, the Minnesota Public Utilities Commission approved Xcel Energy’s dramatic proposal to shift away from coal generation toward renewable energy.   In authorizing the company’s 2016-2030 Integrated Resource Plan (RP-15-21), the Commission directed Xcel to retire two large coal units capable of generating approximately 680 MW each, procure at least 1,ooo MW of wind by 2019,

Around the country clean energy resources, energy efficiency and demand response are quickly being adopted alongside more traditional resources. Southern California Edison (“SCE”) recently contracted for an assortment of clean energy resources that will be used in a groundbreaking attempt to see whether those resources can supply electricity to a densely populated area – Orange

Following a decision of the Federal Energy Regulatory Commission (FERC) released last week that cuts transmission owners’ return on equity (ROE) by more than 200 basis points,[1] ratepayers in the Midcontinent Independent System Operator, Inc. (MISO) footprint will save an estimated $200 million per year.

Spurred by industrial customers’ challenge to MISO’s ROE rate in 2013, FERC ultimately found in its September 28, 2016 order that MISO’s ROE of 12.38% – which had been in place since 2002 – was unjust and unreasonable, and reset it to a base rate of 10.32%.[2]  Transmission owners may also qualify for transmission incentive ROE adders, although the maximum ROE rate may not exceed 11.35%.[3]  FERC also ordered that refunds be issued on a prospective basis for the period from November 12, 2013 through February 11, 2015.[4]
Continue Reading MISO Transmission Owners’ Return on Equity Cut by FERC

With a goal to spur wind and solar development on public lands, the Bureau of Land Management (BLM) is expected to soon release a new rule that will streamline approval of new renewable energy projects.

First proposed for advance notice and comment in 2011, the rule would amend BLM regulations at 43 C.F.R. §§ 2800

Yesterday, Governor Jerry Brown signed Senate Bill (SB) 32 into law, extending and expanding California’s 10-year old greenhouse gas (GHG) emissions reductions mandate under Assembly Bill (AB) 32.  SB 32 provides for a 40% reduction in GHG emissions from 1990 levels by 2030.  This builds on AB 32’s existing mandate to reduce statewide emissions to 1990 levels by 2020.  In negotiations to pass SB 32 in the final weeks of the state legislative session, the bill was trimmed to add only one sentence to existing statute, to insert the 2030 target.  Left unaddressed was one question of the moment, can the cap and trade program authorized by AB 32 legally continue past 2020?  The California Air Resources Board (ARB) has its own answer to the question, the subject of this earlier post.  The courts will no doubt end up as the final arbiter.  Whether post-2020 GHG emissions reductions are met through a cap and trade program or other screws and hammers in ARB’s toolbox, the 2030 target is now written into law, rather than just Executive Order B-30-15.

The vital component of the compromise to pass SB 32 was companion bill AB 197.  AB 197 establishes legislative oversight of ARB’s actions to implement AB 32 and SB 32, by creating a Joint Legislative Committee on Climate Change Policies and adding two ex officio nonvoting members to the Board.  AB 197 also puts a new twist on ARB’s broad authority to adopt rules and regulations to achieve emissions reductions.  AB 32 requires ARB to achieve maximum technologically feasible and cost-effective emissions reductions from sources or categories of sources.  AB 197 further requires ARB to prioritize direct emissions reductions, including from large stationary sources and mobile sources, when adopting rules and regulations to achieve reductions.

In addition to headliner SB 32, the Legislature passed one additional bill with direct emissions reduction mandates, SB 1383.Continue Reading California Continues Ambitious Regulation of Greenhouse Gas Emissions

Via my colleague Xiaowan Mao:

On August 31, 2016, SDG&E will issue one ECR Request for Offers (“RFO”), seeking contracts with facilities that produce Renewable Portfolio Standard (RPS)-eligible energy for the purpose of implementing its ECR program. In this solicitation, SDG&E is seeking PPAs for the ECR program only. This solicitation is not requesting bids for feed-in-tariff projects (e.g. Re-MAT, Bio-MAT), GT projects, BioRAM or other RPS procurement activities that currently exist or are being contemplated.

Approved on September 28, 2013, Senate Bill (SB) 43[1] created the Green Tariff Shared Renewables (“GTSR”) program, which consists of a Green Tariff (“GT”) option and an Enhanced Community Renewables (“ECR”) component.[2]  San Diego Gas & Electric Company (“SDG&E”) plays an active role in implementing the GTSR program to: (1) make clean, renewable energy available to bundled utility customers, whether or not they own a home and/or can afford a significant capital investment; (2) increase the overall volume of renewable energy in the area of San Diego and (3) increase options for institutional, commercial and residential customers to meet their renewable energy goals. [3]
Continue Reading SDG&E Seeks Projects for Community Renewables Program

The National Association of Regulatory Utility Commissioners (NARUC) recently issued a draft manual on distributed energy resources (DER) compensation to assist jurisdictions in navigating the challenges and policy considerations associated with this hot button issue. The release of the manual marks the first time NARUC has specifically weighed in on DER compensation issues.

DERs are