PUC Annual ReportâFiscal Year 2011-12 - Public Utilities Commission
PUC Annual ReportâFiscal Year 2011-12 - Public Utilities Commission
PUC Annual ReportâFiscal Year 2011-12 - Public Utilities Commission
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<strong>Public</strong> <strong>Utilities</strong> <strong>Commission</strong> <strong>Annual</strong> Report <strong>2011</strong>-<strong>12</strong><br />
State of Hawaii Page 40<br />
Hawaii Island to take public comment relating to HELCO’s application.<br />
docket process is ongoing.<br />
The<br />
• KIUC DSM and IRP Cost Adjustment Surcharge—Docket No. <strong>2011</strong>-0388<br />
On December 28, <strong>2011</strong>, KIUC submitted an application to the <strong>Commission</strong><br />
for approval of changes to their tariff to reflect a surcharge to recover costs for its<br />
20<strong>12</strong> IRP and DSM programs. The surcharge also includes a reconciliation<br />
adjustment of amounts collected in <strong>2011</strong>. In an order filed on February 24, 20<strong>12</strong>,<br />
the <strong>Commission</strong> found that the proposed tariff changes are reasonable and<br />
appropriate, effective March 1, 20<strong>12</strong>.<br />
• HECO/MECO/HELCO Modification of Rule 14H—Docket No. 2010-0015<br />
Tariff Rule 14H governs the interconnection of distributed generating<br />
facilities operating in parallel with the utilities’ electrical systems. The<br />
HECO companies initially filed this application to amend parts of the appendices<br />
of this rule in January 2010. The parties reached a consensus about some of the<br />
proposed revisions to Rule 14H, which were adopted in an order filed on May 26,<br />
2010. The agreed upon changes approved in this order include (1) increasing<br />
the percentage of annual peak kilovolt-ampere load for the feeder that triggers<br />
additional technical studies from 10 to 15 percent, (2) establishing a standard<br />
three-party interconnection agreement, (3) including cross-limitation of liability<br />
and non-indemnification language with respect to projects where a<br />
State of Hawaii agency is the customer; and (4) including additional data<br />
information regarding the customer’s generating facility.<br />
To deal with the amendments that were contentious among the parties,<br />
the <strong>Commission</strong> filed a Decision and Order on December 20, <strong>2011</strong>. The<br />
<strong>Commission</strong> decided that (1) for generating facilities with an aggregate capacity<br />
of greater than 250 kW for HELCO and MECO, supervisory controls shall be<br />
required; (2) for generating facilities with an aggregate capacity of greater than<br />
1 MW for HECO, supervisory controls shall be required; (3) for generating<br />
facilities with an aggregate capacity of 250 kW or less for HELCO, MECO, and<br />
HECO supervisory controls per se are not required, and for generating facilities<br />
with an aggregate capacity greater than 250 kW and up to 1 MW for HECO,<br />
supervisory controls may be required; (4) remote disconnection will apply to<br />
generating facilities if such facilities have supervisory control; and (5) the electric<br />
utility may require the installation or modification of equipment under certain<br />
conditions, once a generating facility has been interconnected, provided that the<br />
electric utility is responsible for the post-interconnection associated costs.<br />
The <strong>Commission</strong> declined to adopt the proposals that enabled the<br />
HECO companies to (1) require inverters to operate outside of the voltage levels<br />
that are presently specified in Rule 14H, and (2) establish set points and clearing<br />
times outside of the ranges that are presently specified in the rule. The<br />
<strong>Commission</strong> also declined to adopt the HECO Companies’ proposals to provide<br />
them with the absolute authority to defer the interconnection of a generating<br />
facility under certain conditions.