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Nova Scotia's Electric Power System

Where does our electricity come from?

Finding online copies
of official documents
in the UARB website

Finding online copies of official documents
in the
“Electricity” section of the UARB website
by using Matter Numbers M×××××


Example: Finding online copies of official documents re
the UARB's Review of NSPI's response to storm Arthur
Matter Number M06321

              In the Board's website
•  (1) Click on “Cases & Evidence”.  A new webpage will open.
•  (2) Locate search window “Find Cases by Case Number”.
•  (3) Insert in “Search Term” Matter ID No. M06321.
•  (4) Click on “Go Get It”. 
•  (5) A new webpage will open.
•  (6) In the new webpage, click on the link “M06321”.

The Transformation of Nova Scotia's Electric System

 
M00000-M00999    M01000-M01999    M02000-M02999    M03000-M03999    M04000-M04999
M05000-M05499    M05500-M05999    M06000-M06199    M06200-M06399
M06400-M06599    M06600-M06799    M06800-M06999    M07000-M07199


In the “Electricity” section of the UARB website
Matter Numbers M07000 to M07199

      Matter
    Number


   •  M07244    December 18, 2015
   •  M07243    December 18, 2015
   •  M07239    December 17, 2015
   •  M07238    December 17, 2015
   •  M07237    December 17, 2015
   •  M07236    December 17, 2015
   •  M07235    December 17, 2015
   •  M07234    December 17, 2015
   •  M07233    December 17, 2015
   •  M07231    December 17, 2015
   •  M07226    December 15, 2015
   •  M07218    December 4, 2015
   •  M07215    December 8, 2015

   •  M07187    November 25, 2015
   •  M07183    November 23, 2015
   •  M07179    November 16, 2015
   •  M07176    November 12, 2015
   •  M07173    November 10, 2015
   •  M07169    November 9, 2015
   •  M07161    October 30, 2015

   •  M07160    NSPI - 23H Rockingham Voltage Conversion - Phase One - $566,694 - October 30, 2015
                                 The load at 23H-Rockingham (suburban Halifax city) is approaching the limits of the largest mobile substation
                                 in the NS Power fleet.  The forecasted peak loading at 23H-Rockingham exceeds the nameplate rating of
                                 23H-T51 (25MVA) in 2015.  The attached Distribution Planning Study (Peninsular Halifax and Area Report number
                                 342-1113-H50) Appendix F... [Exhibit N-1 under Matter Number M07160] indicates that the conversion of 23H-Rockingham
                                 load to 25kV should commence in 2015 and continue until the retirement of the substation in 2025...
                                 This portion of the project will reduce the 12kV loading at 23H-Rockingham, through initial conversions to 25kV...

   •  M07159    October 30, 2015
   •  M07158    October 30, 2015
   •  M07157    October 30, 2015
   •  M07156    October 30, 2015
   •  M07155    October 30, 2015
   •  M07154    October 30, 2015
   •  M07151    October 30, 2015
   •  M07149    October 30, 2015

   •  M07148    Efficiency Nova Scotia Corporation - 2015 Q3 Demand Side Management (DSM) Quarterly Report - October 30, 2015
                                 – "Demand Side Management" refers to any program or activity designed to influence the amount and timing of
                                 electricity usage, and ultimately reduce the overall demand for electricity – and thus to reduce the need to build
                                 more electricity generating plants.  "Efficiency Nova Scotia" is a franchise awarded by the Province of Nova Scotia
                                 to EfficiencyOne, an independent not-for-profit corporation.  The franchise delivers electrical energy savings and
                                annual system-peak demand savings to Nova Scotia Power under a Supply Agreement...
                                 – The Residential sector achieved energy savings of 12.5 GWh in the third quarter, totalling 48.3 GWh year-to-date,
                                 toward the annual target of 61.5 GWh...  In the third quarter, Residential Efficient Product Rebates obtained energy
                                 savings of 1.2 GWh, with the majority of savings coming from the Appliance Retirement program component...
                                 The Business, Non-Profit and Institutional sector achieved energy savings of 14.9 GWh in the third quarter for
                                 a year-to-date total of 43.0 GWh, toward the annual target of 59.7 GWh...
                                 – Two major research initiatives were undertaken in Q3, which include an upstream research initiative and research
                                 on light-emitting diode (LED) purchases.  The objective of the commenced research on upstream potential was to
                                 determine the feasibility of developing an upstream (incentive provided to manufacturer) or midstream (incentive
                                 provided to distributor) delivery model for the Residential Instant Savings program.  Research on the purchasing of
                                 LEDs among the general residential population was designed to determine energy savings associated with sales
                                 of LED bulbs, as well as the degree of market transformation...
                                                                                           References:
                                        •  Matter Number M07148 – Efficiency Nova Scotia Corp. - 2015 Q3 DSM Quarterly Report
                                        •  Matter Number M07012 – Efficiency Nova Scotia Corp. - 2015 Q2 DSM Quarterly Report
                                        •  Matter Number M06869 – Efficiency Nova Scotia Corp. - 2015 Q1 DSM Quarterly Report
                                        •  Matter Number    ???     – Efficiency Nova Scotia Corp. - 2014 Q4 DSM Quarterly Report
                                        •  Matter Number M06733 – EfficiencyOne Application...Supply Agreement...Nova Scotia Power Inc...
                                        •  Matter Number M06524 – Efficiency Nova Scotia Corp. - Update on Implementation...
                                        •  Matter Number M06500 – Efficiency Nova Scotia Corp. - 2014 Q3 DSM Quarterly Report
                                        •  Matter Number M06395 – Efficiency Nova Scotia Corp. - 2014 Q2 DSM Quarterly Report
                                        •  Matter Number M06248 – Efficiency Nova Scotia Corp. - 2014 Q1 DSM Quarterly Report
                                        •  Matter Number    ???     – Efficiency Nova Scotia Corp. - 2013 Q4 DSM Quarterly Report
                                        •  Matter Number M05956 – Efficiency Nova Scotia Corp. - 2013 Q3 DSM Quarterly Report
                                        •  Matter Number M05904 – Efficiency Nova Scotia Corp. - Various 2012 and 2013 Reports

•  Details of N.S. power system crucial
Steep Learning Curve for the Public
Understanding the Complex Rate-Setting Process of Energy Utilities
...Nova Scotia effectively now has two regulated energy utilities – one selling electricity and one
selling  "efficiency."   There is a  steep  learning  curve  for  everyone  involved in brokering a new
supply contract between the two parties.  There will also be a steep  learning  curve  for the  public
as it strives to understand the technical debates and seeks to separate fact from spin on both sides.
EfficiencyOne is a not-for-profit corporation that holds the provincial franchise to deliver energy
efficiency services to the main utility.  Most of EfficiencyOne's activities are regulated,
and  for  this  reason  it  is  deemed  to  be  a  provincial  utility...
Chronicle-Herald, Halifax,  May 8, 2015


   •  M07139    NSPI - Annual Report on the Time of Use Real Time Pricing (TOU-RTP) Tariffs - October 22, 2015
                                                                                           References:
                                           M07139    M06517    M04706    M04164    M03768    M03762    M03072    M02487    M01736

   •  M07132    NSP Maritime Link Inc.- NSPML - 2015 Affiliate Code of Conduct Annual Report - October 16, 2015
                                                                                           References:
                                        •  Matter Number M07132 – NSPML - NSP Maritime Link Inc.- (Draft) 2015 Affiliate Code of Conduct - Oct. 16, 2015
                                        •  Matter Number M06868 – NSPML - NSP Maritime Link Inc.- 2014 Affiliate Code of Conduct Report - April 30, 2015
                                        •  Matter Number M06862 – NSPI - Nova Scotia Power Inc. - 2014 Affiliate Code of Conduct Report - April 30, 2015
                                        •  Matter Number M06644 – NSPML - NSP Maritime Link Inc.- 2013 Changes...Affiliate Code...Guidelines - Dec. 19, 2014
                                        •  Matter Number M06280 – NSPML - NSP Maritime Link Inc.- 2013 Affiliate Code of Conduct Report - June 13, 2014
                                        •  Matter Number M06268 – NSPI - Nova Scotia Power Inc. - 2013 Affiliate Code of Conduct Report - May 30, 2014
                                        •  Matter Number M05646 – NSPI - Nova Scotia Power Inc. - 2012 Affiliate Code of Conduct Report - April 30, 2013
                                        •  Matter Number M04946 – NSPI - Nova Scotia Power Inc. - 2011 Affiliate Code of Conduct Report - April 30, 2012
                                        •  Matter Number M04067 – NSPI - Nova Scotia Power Inc. - 2010 Affiliate Code of Conduct Report - April 29, 2011
                                        •  Matter Number M03070 – NSPI - Nova Scotia Power Inc. - 2009 Affiliate Code of Conduct Report - April 29, 2010
                                        •  Matter Number M01558 – NSPI - Nova Scotia Power Inc. - 2008 Affiliate Code of Conduct Report - April 30, 2009
                                        •  Matter Number M00209 – NSPI - Nova Scotia Power Inc. - Review...Affiliate Trnsctns (Code of Conduct) - Jan. 4, 2008

                                        Maritime Link across Cabot Strait       500 MW        670 000 horsepower
   •  M07118    NSPML - Nova Scotia Power Maritime Link Inc. - NSPML 2015 Q3 Quarterly Report - October 15, 2015
                                 — This [Exhibit N-1 [44 pages] in Matter Number M07118] is the Q3 2015 Quarterly Report for the Maritime Link to the UARB.
                                 — Manufacturing of the Marine Cable One (Cabot Strait) began at the Futtsu, Japan, manufacturing facility in July, slightly
                                 ahead of schedule.  The cable length manufactured is approximately 100km.  The interior core stranding was completed
                                 successfully and the paper lapping (insulating) commenced.  The manufacturing of the fibre optics cable was completed
                                 in Rognan, Norway, facility in September 2015; this will be integrated into the Cable One lapping process....
                                 — The MWH Independent Engineer team, together with a representative of Natural Resources Canada participated in the
                                 site visit for the Maritime Link (ML) project in Nova Scotia on July 14, 2015 and in Newfoundland on July 15-16, 2015...
                                 — In Nova Scotia the two underwater high-voltage DC (HVDC) cables across Cabot Strait will come ashore just west
                                 of the existing Point Aconi thermal generating station.  The Nova Scotia portion of the project includes approximately
                                 46km of 200kV HVDC transmission line from Point Aconi to the Woodbine converter station site, and approximately
                                 40km of grounding line from Woodbine to the Big Lorraine grounding site... The right-of-way (ROW) for the existing
                                 230kV AC transmission line from Point Aconi to Woodbine has been widened by up to 28m [92 feet] to accommodate
                                 the new overhead DC line... The grounding line, two large (1300-ampere) conductors, from Woodbine to Big Lorraine
                                 will be an overhead line supported on single wood poles...
                                                Photographs - July 14, 2015 - [Exhibit N-1, Attachment 3, Appendix No. 1 in Matter Number M07118]
                                 Photo 1 - Point Aconi - View looking southerly along right-of-way from the HDD site to the transition compound.
                                 Photo 4 - Cleared right of way adjacent to existing 230 kV line near Woodbine substation.
                                 Photo 8 - Big Lorraine - Proposed grounding station location.

            Comment:– Electrically, the Maritime Link Project (NSPML) is a transmission link between
the Nova Scotia grid and the grid on Newfoundland Island – it has no particular association with
anything that may be happening in Labrador.  Financially, legally and politically, NSPML is closely
associated with what is happening in Labrador, but – electrically – Labrador is not essential to the
operation of the Maritime Link.  That is, whenever the Maritime Link is ready it can to go into
commercial operation as a transmission intertie between the two provincial grids.  NSPML will
be able operate at full power in either direction, from Newfoundland to Nova Scotia or from
Nova Scotia to Newfoundland.
            Without the Labrador connection, Newfoundland will not have any electricity to sell
to Nova Scotia.  But, in the interval before Muskrat Falls begins commercial operation, Nova Scotia
may have electricity to sell to Newfoundland, either from generation within Nova Scotia or as a
transmission link from generation in New Brunswick, or both simultaneously.
            Consider this scenario – during the wee hours, Point Lepreau in New Brunswick has
surplus power available at a very low price – less than two cents for each kilowatt-hour (kWh)
of electricity generated.  Newfoundland could make an arrangement with New Brunswick to buy
(say) 100 megawatts from New Brunswick.  This power would be carried across Nova Scotia
from Amherst to Point Aconi by Nova Scotia Power's grid and then carried by NSPML across
Cabot Strait to Newfoundland.  Nova Scotia Power would be paid for providing this transmission
service, but would not participate in the transaction between generator and consumer.  Electric
energy could be delivered into the Newfoundland grid at Granite Canal for less than three cents
per kWh.  This could be attractive to Newfoundland.  The Maritime Link also would provide
backup to help prevent future extensive power failures on Newfoundland Island such as occurred
in January 2014 and March 2015.
            Of course, this scenario has been known to planners in all three provinces for a long time.
The bottleneck is between Saint John and Moncton.  There is now no generation at Moncton and
the transmission from Saint John to Moncton is heavily loaded, but Nova Scotia's existing grid can
handle such a west-to-east transfer by displacement with no problem.  Such an arrangement would
mean that the Maritime Link could be officially declared to be "used and useful" (the regulatory
parlance) and folded into the rate base from the day that installation and testing of all components
is completed, no matter if Muskrat Falls is ready or not.
              Under existing provincial legislation, “the Company (Nova Scotia Power Inc.) shall
              not construct a generating plant that utilizes nuclear energy to produce electricity.”
              Nova Scotia Power's website states that “nuclear power was, and is, prohibited by provincial
              statute in Nova Scotia...”  Nuclear power was considered but was not viable “for Nova Scotia
              at this time (2012)...”  These three items refer to the legal prohibition of nuclear generating plants
              located in Nova Scotia, but it appears that spot purchases (a series of one-hour contracts arranged
              shortly before delivery) of electric energy – generated from nuclear fuel at Point Lepreau – may not
              be illegal under existing Nova Scotia laws.  However, this seems to be viewed by government as being
              politically unwise, and there have been no known purchases of energy from Lepreau for consumption
              in Nova Scotia and none are likely in the foreseeable future.  Nova Scotia frequently does buy electric
              energy from New Brunswick but the official records (accounts payable, etc) always show the energy
              to have been generated at a plant other than Lepreau.


   •  M07100    NSPI - IT (Information Technology) - Outage Map Technology Upgrade - $2,895,724 - September 30, 2015
                                                        Start Date: 2015/02        In-Service Date: 2015/11
                                 NS Power is implementing the UARB Order of October 10, 2014, [Exhibit M06321 under Matter Number M06321] to close
                                 gaps associated with the processes and technology that deliver communications to customers during power outages.
                                             This project [Documentation (51 pages) - Exhibit N-1 under Matter Number M07100] will address the major gaps of:
                                 (1) determining and delivering estimated times of restoration (ETRs) to customers on all sizes of outage events,
                                 (2) utilizing new channels of communication, (3) educating customers on the new services, and (4) ensuring the
                                 outage map can deliver outage information during large outage events.  NS Power has determined that the quickest
                                 and most cost effective solution to meet customer expectations for outage communications is to procure the solution
                                 from a third party who specializes in this technology.
                                             The company, iFactor, serves a majority of North American utilities which experience severe weather related
                                 outage events like NS Power.  The improvements must be completed as soon as possible to ensure customer
                                 expectations are met when NS Power experiences a major power outage during a future storm event...
                                                                                           Reference:
                                        •  What Really Upsets Customers During Power Outages?  Posted on September 25th, 2015

            Comment:– The documentation [Exhibit N-1 (51 pages) under Matter Number M07100] provided by NSPI
in support of this Application is extensive, and addresses several problems that need attention.  However,
there is a significant problem within the existing NSPI Outage Map website that is not addressed in this
documentation.  Nova Scotians currently use five different browsers, designed and built by five different
manufacturers with widely varying design philosophies.  It is essential that any new software purchased
by NSPI for this project be carefully designed and written so as to be able to display and operate properly
within any browser that may be chosen by a citizen.  It will not be sufficient for NSPI to put a note in its
website to the effect that "this Outage Map is designed to operate with the (insert name) browser". In 2015,
it is unreasonable for any publicly-funded website, such as the NSPI website, to expect the citizens who use
it to choose a particular browser to suit the personal preference of its webmaster.
            This problem was brought to the attention of NSPI eight months ago (see below:
"Letter from Citizen re Browsers"), but in this Application for approval to spend nearly
three million dollars for M07100 - Outage Map Technology Upgrade there is no mention of it.
The word “browser“ does not appear anywhere in the Application.
            It is essential that the Specification for the purchase of this new software explicitly states this
requirement – that all software purchased by NSPI for this project be designed and built so as to be able
to display and operate properly within any browser that may be chosen by a citizen of Nova Scotia.
It is also essential that the Specification explicitly states that the browser-compatibility of this new software
be maintained within each and every modification/upgrade made to this software in the future.
             •  Letter from Citizen re Browsers - January 27, 2015
             •  Letter from Citizen re Browsers - Figure 1  (half size)
             •  Letter from Citizen re Browsers - Figure 1  (full size, best legibility)
             •  Letter from Citizen re Browsers - Figure 2  (half size)
             •  Letter from Citizen re Browsers - Figure 2  (full size, best legibility)
             •  Letter from Citizen re Browsers - Figure 3  (half size)
             •  Letter from Citizen re Browsers - Figure 3  (full size, best legibility)
             •  Letter from UARB forwarding Citizen's letter to NSPI - Febuary 9, 2015
             •  Letter from NSPI to UARB - Response to Citizen's letter re Browsers - Febuary 20, 2015
"NS Power follows a structured quality assurance process...which includes validation that the top web
browsers render the page correctly."  Fair enough.  However, IMO this is too vague to be a satisfactory
justification for officially approving an expenditure of nearly three million dollars of ratepayers' money.
A satisfactory justification should include, at a bare minimum, a clear statement of  (1) specifically which
browsers are included in the "top web browsers" tested, so that each citizen can know if his/her choice
of browser is, or is not, included; and  (2) a report of specifically which browsers have been used recently
by the public to access NSPI's existing Outage Map website.  This report should include a month-by-month
statement of this browser use going back at least twelve months, so that trends can be identified.
             •  Graph showing Web Browser Market Share Trends  at six-month intervals beginning in May 2007...
             •  Postscript:– In the Letter from UARB forwarding Citizen's letter to NSPI dated Febuary 9, 2015,
the Board refers to “similar concerns (that) were raised...in his letter of September 4, 2014, regarding
NSPI's performance during post-tropical storm Arthur“.  These “similar concerns“ that were raised on
September 4, 2014, have been available since September 9, 2014 in the Board's website, as [pages 92-100
of 141 pages in Exhibit Letters of Comment received from Members of the Public under Matter Number M06321
].
This file is not easy to find in the Board's wesite – it is listed beside date 07/25/2014 (even though it has
been updated to 09/09/2014).  This collection Letters of Comment received from Members of the Public
is a massive (78 megabytes) file, containing the complete text of 59 Letters of Comment, some with colour
photographs.  Since September 2014, all have been publicly available to be perused by anyone at any time.
             •  Technically Beautiful?  The Supreme Court of Canada (SCC) and the Internet Age  September 9th, 2009
              ...(J)ust as the internet was popularized by the World Wide Web, the World Wide Web was popularized by one
              significant technological development – the modern web browser.  This analysis places the definitive arrival of
              the internet age as no earlier than 1993, with the release of NCSA Mosaic, the first popular modern web browser.
              Netscape Navigator was released in 1994, and by the time Microsoft came out with Internet Explorer in 1995 and
              subsequently began bundling it with its Windows 95 operating system, it was seen as something of a
              latecomer to the game...  [boldface emphasis added]

   •  M07099    NSPI - Backbone Communication System Upgrade - $8,913,092 - September 30, 2015
                                 This upgrade is required as a result of technological advancement, rendering older equipment obsolete and unsupported.
                                 Time-Division Multiplexing (TDM) technology is no longer the industry standard and has been replaced by packet technology
                                 that cannot be supported by NS Power's existing infrastructure.  For NS Power to continue reliable operation of these systems,
                                 an upgrade to the backbone system capacity is required.  The existing multiplexer equipment is between 15-20 years old.
                                 The backbone communication system supports NS Power's mobile radio system, RTU / SCADA circuits in substations,
                                 Internal IP Network, protection circuits for substation and transmission and other data and voice circuits.  Providing critical
                                 data transmission and voice communications to all critical NS Power facilities is a North American Electric Reliability
                                 Corporation (NERC) requirement for electric utilities.  This project includes the upgrade from the current TDM multiplexers
                                 to the new Multi-Protocol Label Switching (MPLS) equipment as well as the required system upgrades necessary to support
                                 this new technology.  In order to support the multiplexer replacement, the microwave radio network will need a capacity
                                 upgrade.  The new network will carry a minimum of 5Mbps (million bits per second), which is significantly higher than
                                 the 768kbps (thousand bits per second) of bandwidth on current microwave radio system.

            Comment:– On October 28th, 2015, Charlie Rose's TV show included an interview with Ted Koppel,
on the subject of his new book – Lights Out: A Cyberattack, A Nation Unprepared, Surviving the Aftermath,
published Oct 27, 2015.  During the interview, Koppel said “there are only three electric grids in the United
States – the Eastern Interconnection, Texas, and the Western Interconnection.” (All of the electric utilities in the
Eastern Interconnection are electrically synchronized – connected together and operating at 60 Hz – during
normal system conditions.   For  years,  Nova Scotia  has  been  included  in the Eastern Interconnection.)
Koppel went on to talk about a special type of component that is found in many electric utility systems –
SCADA, Supervisory Control And Data Acquisition.  “Essentially, they run the computer system that keeps
our energy grids in balance.  You have to have a perfect balance between the production of electric energy
and the consumption of energy.  Siemens make a lot of these SCADA systems (also known as Programmable
Logic Controllers).  Essentially, the same SCADA systems as are sold in California are sold in Teheran – they
are sold around the world...”  (Many of them are connected to the Internet for the purpose of controlling their
operation from a central point in each country.)  Here, Koppel recounted a story about the password used by
Siemens to protect these Internet-connected grid controls from hackers.  He described a BlackHat conference
in Las Vegas where a speaker showed the private Siemens password to the whole audience...
            This comment is presented here because Nova Scotia Power is seeking Utility and Review Board
approval [Exhibit N-1 in Matter Number M07099] to purchase and install a Backbone Communication System
Upgrade
budgeted to cost $8,913,092.  “The backbone communication system supports NS Power's mobile
radio system, RTU/SCADA circuits in substations, Internal IP Network, protection circuits for substation
and transmission and other data and voice circuits.  Providing critical data transmission and voice
communications to all critical NS Power facilities is a NERC requirement for electric utilities...” [emphasis added].


   •  M07086    Antigonish Electric Utility - Wind Energy Project - September 17, 2015
                                 The Town of Antigonish Electric Utility requests approval to purchase and include in its rate base, a 63% share of wind
                                 assets located in Ellershouse, Hants County, Nova Scotia.  The Wind Farm is under construction in partnership with the
                                 Towns of Berwick (with 27% of the project) and Mahone Bay (with 10% of the project).  The Total cost of the 16.1 MW
                                 wind generating facility is expected to be approximately $24 000 000, with the expected cost of the Antigonish Town Utility's
                                 share being $15 120 000.  The Utility would depreciate the asset on a straight line basis over twenty years, and we also
                                 request that the depreciation funds required by the addition of the asset be applied against the principal portion of the long
                                 term debt.  While the project, depending on assumptions used, may generate a small profit or loss over its life, the major
                                 benefit to the utility customer lies in the effective flattening of approximately 18% of its electric power costs for twenty years.
                                 The result essentially will be sheltering 18% of the utility power costs from larger increases beyond its control, such as those
                                 that occasionally are passed on through NSPI rate increases...

            Each of these three towns is located far from the Ellershouse Wind Farm Project, and none
of them own any power transmission facilities.  How will the electricity generated at Ellershouse get from
there to each of these towns?  The Ellershouse Project will be connected to Nova Scotia Power's (NSPI)
provincial grid, and the electric power generated by the Project thus will be available throughout the
province.  Each of the three towns will draw from the grid an amount of electric energy equal to its share
of the energy fed into the grid from the Ellershouse Wind Farm, less a small amount (about 3%) to
compensate NSPI for the energy lost in its transmission system.
            This is not a description of what actually happens, minute by minute 24/7/365 in the large
electric circuit that forms the Nova Scotia electric power system.  The individual electrons cannot be
labelled, and their behaviour as they flow through the provincial electric grid is controlled by physics
– such things as ohms, turns ratios in transformers, and where the supply of vars (zero power factor)
is being produced and consumed – not by legal contracts between the various organizations that have
equipment connected to the grid.
            The statement above – “each of the three towns will draw from the grid an amount of electric energy
equal to its share of the energy fed into the grid from the Ellershouse Wind Farm” – is a description of the
accounting system that will be used each month to calculate how much is owed by each Town.  The actual
electricity drawn by any particular Town from the grid conceptually will be at each moment 24/7/365 precisely
equal to that Town's total electrical requirement less that Town's share of the electrical generation produced
at that moment by the Ellershouse Project – but in practice this is not feasible.
            In practice, each Town will draw its total moment-by-moment requirement from the grid, same as has
been the regular operating procedure for many years past.  The moment-by-moment electric generation at
Ellershouse – with the normal unpredictable variations of any wind-powered generation system – will be fed into
the grid in Hants County, metered (measured) at the point where the Ellershouse Wind Farm connects to the grid.
            Moment-by-moment, the three Towns will draw from the grid in Antigonish County or in Kings County
or in Lunenburg County whatever amount of power their individual systems require.  Moment-by-moment, the
NSPI grid will provide among the counties whatever power flows are needed to precisely balance the electricity
supply with the electricity demand so as to make the whole arrangement work reliably and continuously, and
invisibly as far as the electricity consumers in these four counties – and everywhere in the province, where
there are many other electricity consumers, small and large, doing whatever they do without telling NSPI
what their plans may be but every one connected (indirectly) to the grid – are concerned.
            It will be the responsibility of NSPI to adjust its generation (by monitoring the power flow across
the NS-NB intertie) to accommodate these variations for the system as a whole.  When a brisk wind
is blowing at Ellershouse, NSPI will reduce its total generation.  If an Ellershouse turbine needs
maintenance work, NSPI will increase its total generation to make up the deficit.  NSPI will provide
backup for the Ellershouse generation, available at any time 24/7/365 without advance notice.
NSPI will be paid a fixed monthly fee for providing this essential service.
            The energy drawn from the grid in any one month by any particular Town will be measured as
a single number of kilowatt-hours – metered at the point where the Town's electric system connects to
the grid.  For each individual Town, the monthly accounting procedure will separate the total number
of kilowatt-hours into two parts, with (a) one part being treated as the energy deemed to have been
supplied by that Town's share of the Ellershouse Project and thus not charged to the Town under the
official NSPI rate, and (b) the remaining part being treated as the energy deemed to have been supplied
by NSPI and thus charged to the Town at the official NSPI rate.  This accounting procedure then will
credit the first part as income to the Ellershouse Project (AREA) to be “applied against the principal
portion of the long term debt,” and the second part as a number of dollars owed by the Town to NSPI.
            The contracts between Nova Scotia Power and the individual Towns will include many intricate
engineering, legal and financial details to enable all participants including electricity consumers to
have a clear idea of how the monthly accounting will be done.

   •  M07065    NSPI - HYD (Hydro) GIS (Gisborne Generating Station) Gearbox and Bearing Replacement - $371,079 - August 31, 2015
                                 The Gisborne Generating Station – located on the Wreck Cove System in Victoria County, Nova Scotia – is a 3.5 MW
                                 generator in between the Gisborne and Wreck Cove reservoirs.  [Note: On Google Maps, these two bodies of water are labelled
                                 "Gisborne Flowage" and "Wreck Cove Flowage".]  This project is to replace the bearings and seals with modern designs that
                                 maximize operating life and minimize the risk of oil release to the environment as well as general refurbishment of
                                 the gearbox, including bearing and oil replacement.  Why do this project?  The Gisborne plant is controlled locally
                                 and is difficult to access, especially in winter.  This project will increase reliability, reduce costly call-outs to Hydro
                                 staff to perform equipment checks, and maximize the run time for the unit in the current control scheme.  Why do
                                 this project now?  The seal has shown an increasing frequency of failures.  To ensure the unit is capable of running
                                 and to prevent a forced outage this work needs to be done now.

   •  M07064    NSPI - 16W-302 Lake George Neutral Replacement P&A - $303,708 - August 31, 2015
                                 This project includes the replacement of approximately 4.6 km of neutral conductor with 2/0 AASC in Lake George,
                                 Kings County.  The existing neutral conductor is a mix of #6 and #8 copper that is approximately 50 years old.
                                 This section of line has previously been identified as in need of work due to its level of deterioration.  Reconductoring
                                 with new 2/0 AASC (Aluminum Alloy Stranded Conductor) will reduce neutral-to-earth voltages to within acceptable levels.
                                 Why do this project?  The neutral conductor is undersized and at end of life.  Neutral-to-earth voltages were measured and
                                 found to be above the 10 volts allowable maximum.  Why do this project now?  Neutral-to-earth voltages at the measured
                                 20.1 volts is above the allowable maximum of 10 volts.  Replacing the neutral was being planned as part of the
                                 2016 ACE Plan.  Testing of the neutral-to-earth voltages while scoping this project showed voltage level reaching as high
                                 as 20.1 volts – the allowable limit for neutral-to-earth voltage is no more than 10 volts as listed under Section G 2.0 of the
                                 overhead distribution standards and Section 17.9 Grounding Criteria of the CEJC(?).  This project has been moved
                                 into 2015 as a result of the voltage being above the allowable maximum.

   •  M07063    NSPI - East Uniacke Road Load Growth P&A - Overloaded Distribution Feeder - $904,331 - August 31, 2015
                                 Why do this project?  A new residential development in East Uniacke, Halifax Regional Municipality, is increasing
                                 the load on feeder 131H-422.  The load on 131H-422 in February 2015 was measured, with Phase A at 366 amperes,
                                 Phase B at 368 amperes and Phase C at 356 amperes – an average of 363.3 amperes.  This is in excess of the
                                 overhead distribution standard of 325 amperes.  In order to resolve the overload issue, 131H-422G requires a
                                 two-phase extension starting on Etter Road, past the South Uniacke Road intersection to 874 East Uniacke Road.
                                 There is continued load growth expected on the existing single phase line supplying the developing area.
                                 Approximately 11.5km of line will require two additional phases.  Why do this project now?  Growth has occurred
                                 in East Uniacke and the current loading of 131H-422 is unbalanced, creating voltage issues on this feeder section.
                                 The load on this feeder is anticipated to continue to grow due to new development in the area.  Load growth occurred
                                 at a high rate throughout 2015 which has led to this project being required prior to the winter period and thus, being
                                 advanced from 2016 into 2015.  Why do this project this way?  Re-conductoring the existing phase and adding two
                                 phases is the most cost-effective solution.  Two phases will be extended along the existing alignment along Etter Road
                                 and East Uniacke Road, minimizing easement acquisition costs and effort.  The replacement of 43 poles will bring the
                                 line up to current three phase construction standards.  The existing single-phase voltage regulator on Etter Road will
                                 be replaced with three 300-ampere voltage regulators once the two new phases are installed.

   •  M07062    NSPI - HYD (hydro) Wreck Cove Tailrace Rockfall U&U - $2,422,964 - August 31, 2015
                                 Wreck Cove is the largest hydro facility in the NS Power fleet and is required to maintain a high level of reliability
                                 for system stability and North American Electric Reliability Corporation (NERC) requirements (black start and
                                 ten minute reserve).  Wreck Cove has been evaluated as the top priority for Hydro automation projects due to
                                 its remote location and importance to the system stability.  On March 11, 2015, Wreck Cove Generating Station
                                 experienced a rock fall in the tailrace tunnel that is used by both generating units.  Currently the quantity of the
                                 rock fall is imposing a capacity restriction on the units, limiting them to generate at 75 percent total output.
                                 This project is to clear the rock fall and stabilize the tunnel to prevent future occurrences.  This includes installing
                                 rock bolts and mesh throughout the mucking and tailrace tunnel down to the fall site, and securing of the fall site
                                 through removal of fallen material.  The mucking tunnel is 252 feet [76.8 m] long, (12 feet [3.7 m] wide
                                 by 14 feet [4.3 m] high) and the tailrace tunnel (to the location of the rockfall) is 280 feet [85.3 m] long
                                 (20 feet [6.1 m] wide by 20 feet [6.1 m] high).

   •  M07061    NSPI - LIN (Lingan) U&U (Unforeseen and Unbudgeted) Coal System Refurbishment - $291,211 - August 31, 2015
                                 The trough, impact rolls and structural steel sections on the reclaim and exterior conveyor belts on
                                 the Lingan Coal delivery system were deteriorated and required replacement to ensure continued
                                 reliable service of the coal handling system.  This work was completed in 2014.

   •  M07060    NSPI - 2015 ACE Plan Capital Item for Subsequent Approval - L6538 Replacements - $1,008,356 - August 31, 2015
                                 L-6538 is a 34.5 kilometre 138kV transmission line that connects 3S Gannon Road (North Sydney) and
                                 5S Glentosh (about 30 km northeast from Baddeck) substations.  This Transmission line was constructed in 1971.
                                 This project's scope includes the replacement of assets on approximately 64 structures.

   •  M07058    NSPI - Nova Scotia Power Fuel Manual - Revised Fuel Manual... - August 31, 2015
                                 Revised Fuel Manual re changes related to the potential impact of Maritime Link discretionary energy - Revision 8, Aug. 2015
                                 Included in this submission to the Utility and Review Board are redline and clean copies of the updated and revised
                                 Nova Scotia Power Fuel Manual (Revision 8, dated August 2015) and a clean copy with all the linked reference attachments.
                                 Purchase of the Maritime Link discretionary energy is addressed in the Energy Access Agreement (EAA), which is now
                                 included as a linked reference document within the Fuel Manual.  Updates to Section 13 of the Fuel Manual (Purchase Power,
                                 Export Power Sales and Economic Scheduling & Marketing) have been made to capture the process for acquiring
                                 Maritime Link energy as outlined in the Energy Access Agreement.
                                                                                           Reference:
                                        •  NS Power has developed a Fuel Manual for all operations related to procurement and management of fuel
                                                     required for power generation...
                                               §1.0  NSPI Fuels Policy
                                               §2.0  Risk Management, Credit Policy and Affiliate Code of Conduct
                                               §3.0  Governance
                                               §4.0  Approval Authority and Reporting
                                               §5.0  Determination of Fuel Requirements
                                               §6.0  Fuel and Transportation Procurement Procedures
                                               §7.0  Allowed Fuel Procurement Transactions, Freight Procurement Transactions, Financial Derivatives
                                               §8.0  Fuel Procurement Strategy and Objectives
                                               §9.0  Determination of Financial Hedging Requirements
                                               §10.0  Fuel Hedging Strategy and Objectives
                                               §11.0  Quality Control of Fuel Suppliers
                                               §12.0  Procurement Administration
                                               §13.0  Plant Inventory Policy
                                               §14.0  Purchased Power and Export Power Sales
                                                     Source– Page I-9 of "Audit of NS Power's FAM"  [Exhibit N-1 (249 pages) under Matter Number M06290]

   •  M07057    NSPI - 2015 ACE Plan Capital Item for Subsequent Approval - L6539 Replacements - $723,796 - August 31, 2015
                                 L-6539 is a 36 kilometre 138kV transmission line that connects 3S Gannon Road (North Sydney) and 2S Victoria Junction
                                 (eastward from Sydney) substations.  This transmission line was constructed in 1971.  This project is required to replace
                                 deteriorated assets identified through NS Power's ongoing inspection program.  This project's scope includes the
                                 replacement of assets on approximately 41 structures.

   •  M07056    NSPI - 2015 ACE Plan Capital Item for Subsequent Approval - L6503 Replacements - $870,870 - August 31, 2015
                                 L6503 is a 66 kilometre 138kV transmission line that connects 1N Onslow and 50N Trenton substations.  A portion of this
                                 line was constructed in 1970 with the remainder being built in 1981.  This project is required to replace deteriorated assets
                                 that have been identified through NS Power's ongoing inspection program.  This project includes the replacement of assets
                                 on approximately 43 structures.

   •  M07055    NSPI - 2015 ACE Plan Capital Item for Subsequent Approval - L7003 LiDAR Upgrades - $11,032,275 - August 31, 2015
                                 L-7003 is a 160 kilometre (743 structures) 230kV transmission line that connects 3C Port Hastings and 67N Onslow
                                 substations.  This transmission line was constructed in 1968 (57 km) and 1970 (103 km).  The line is designed and
                                 insulated for 138kV, but has been operated at 230kV since 1979.  This project is required to increase the ground
                                 clearance for energized conductors in locations that do not meet minimum CSA standard for ground clearances as
                                 identified in the LiDAR (Light Detection and Ranging) study.  This project also includes insulator replacement for the
                                 majority of the line as well as the replacement of deteriorated assets that have been identified through NS Power's
                                 inspection program.  The insulators targeted for replacement have a known failure mechanism resulting from
                                 cement growth.  Structure raises are required to meet Canadian Standards Association (CSA) clearance requirements.
                                 This project also includes a 10°C increase in the maximum operating temperature from 60°C to 70°C (whch increases
                                 conductor sag thus reducing ground clearance).  The maximum conductor operating temperature is being increased
                                 from 60°C to 70°C to allow higher Cape Breton export, reducing the need for out-of-merit (more expensive) generation
                                 at Trenton or Tufts Cove, particularly when other transmission lines are out of service.

   •  M07053    NSPI - Emergency Services Restoration Plan (ESRP) - 2015 ESRP Drill Report - August 31, 2015
                                                                                           References:
                                        •  Matter Number M07053 – NSPI - Emergency Services Restoration Plan (ESRP) - 2015 Drill Report - Aug. 31, 2015
                                        •  Matter Number M06406 – NSPI - Emergency Services Restoration Plan (ESRP) - 2014 Drill Report - Sep. 2, 2014
                                        •  Overview and Purpose of the Emergency Service Restoration Plan
                                                     beginning on page 6 of Appendix 3.01 [Exhibit A-2(i) (290 pages) in Matter Number M06321].
                                                                  NSPI will conduct an annual drill using the plan and testing its procedures.
                                        •  Post-Tropical Storm Arthur - Review of NS Power's Storm Response  eight items - August 2014 to May 2015
                                        •  Matter Number M06321 – 2014 NSUARB 163 - Decision: NSPI...Response to Storm Arthur - October 6, 2014
                                        •  Matter Number M06321 – UARB Review: Widespread Power Outages - Storm Arthur: July 5, 2014
                                        •  Matter Number M05943 – NSPI - 2013 ESRP - Level 3 & 4 Response - October 30, 2013
                                        •  Matter Number M05861 – NSPI - Emergency Services Restoration Plan (ESRP) - 2013 Drill Report - August 30, 2013
                                        •  Matter Number M05155 – NSPI - Revised ESRP - Level 3 & 4 Response and 2012 Drill Report - August 31, 2012
                                        •  Matter Number M04440 – NSPI - Revised ESRP - Level 3 & 4 Response - Rev. 1.7 & 2011 Drill Report - Aug. 31, 2011
                                        •  Matter Number M02140 – NSPI - Revised ESRP and 2009 Drill Report - August 31, 2009

   •  M07051    NERC - North American Electric Reliability Corp. - Q2 2015 - Application...Approval of Reliability Standards - August 28, 2015
                                 — Since the NS Power electrical system is interconnected with the North American bulk power system, NS Power
                                 is required to comply with standards and codes as governed by the North American Electric Reliability Corporation
                                 (NERC) and the Northeast Power Coordinating Council (NPCC).  This obligation to comply extends to Market
                                 Participants and generators interconnected with the Nova Scotia Power grid. 
                                 Links to the applicable standards and codes are published on the OASIS website.
                                 — Some or all of NERC's Reliability Standards are mandatory in the Canadian provinces of Alberta, British Columbia,
                                 Manitoba, New Brunswick, Nova Scotia [boldface emphasis added], Ontario, Quebec, and Saskatchewan.
                                 ♦  See Memorandum of Understanding between Nova Scotia Utility and Review Board
                                                        and the North American Electric Reliability Corporation (signed Dec. 22, 2006)
                                                                                     NOTE:– These two Memorandums of Understanding (next above and below) may
                                                                                        not display properly in some browsers.  The Chrome browser is recommended.

                                 ♦  See Memorandum of Understanding between Nova Scotia Power Inc. and the Northeast Power Coordinating Council, Inc.
                                                        and the North American Electric Reliability Corporation (signed May 11, 2010)
                                 ♦  Pursuant to the terms of the MOU with Nova Scotia Power Inc., enclosed is their recommendation to
                                                        the Nova Scotia Utility and Review Board supporting the adoption of NERC Reliability Standards
                                                        and NPCC Criteria in that province... (dated December 17, 2010)
                                 ♦  See Application by North American Electric Reliability Corporation for approval of its Reliability Standards,
                                                        and an application by Northeast Power Coordinating Council, Inc. for approval of its
                                                        Regional Reliability Criteria (UARB Order dated July 20, 2011)
                                 ♦  Before the Nova Scotia Utility and Review Board of the Province of Nova Scotia – NERC - November 30, 2011
                                                        Q3 2011 Application for Approval...Reliability Standards...North American Electric Reliability Corp. [115 pages]
                                                                                     NOTE:– These two Applications for Approval (next above and below) may not
                                                                                        display properly in some browsers.  The Chrome browser is recommended.

                                 ♦  Before the Nova Scotia Utility and Review Board of the Province of Nova Scotia – NERC - February 26, 2013
                                                        Q4 2012 Application for Approval...Reliability Standards...North American Electric Reliability Corp. [109 pages]
                                                                                           References:
                                        •  Matter Number M07051 – NERC - North American Electric Reliability Corporation - Q2 2015 - August 28, 2015
                                        •  Matter Number M06890 – NERC - North American Electric Reliability Corporation - Q1 2015 - May 13, 2015
                                        •  Matter Number M06728 – NERC - North American Electric Reliability Corporation - Q4 2014 - February 23, 2015
                                        •  Matter Number M06545 – NERC - North American Electric Reliability Corporation - Q3 2014 - November 26, 2014
                                        •  Matter Number M06525 – NSPI - Onslow 345 kV Node Swap - November 14, 2014
                                        •  Matter Number M06427 – NERC - N.A. Electric Reliability Corporation - 2015 Business Plans etc. - Sep. 17, 2014
                                        •  Matter Number M06363 – NERC - North American Electric Reliability Corporation - Q2 2014 - August 15, 2014
                                        •  Matter Number M06294 – NSPI - Protection Risk Reduction 67N-Onslow 230kV - $2,870,285 - June 25, 2014
                                        •  Matter Number M06258 – NERC - North American Electric Reliability Corporation - Q1 2014 - May 20, 2014
                                        •  Matter Number M06132 – NERC - North American Electric Reliability Corporation - Q4 2013 - February 28, 2014
                                        •  Matter Number M06011 – NERC - North American Electric Reliability Corporation - Q3 2013 - November 26, 2013
                                        •  Matter Number M05944 – NERC - N.A. Electric Reliability Corporation - 2014 Business Plans etc. - Nov. 04, 2013
                                        •  Matter Number M05862 – NERC - North American Electric Reliability Corporation - Q2 2013 - August 30, 2013
                                        •  Matter Number M05713 – NERC - North American Electric Reliability Corporation - Q1 2013 - May 31, 2013
                                        •  Matter Number M04460 – NERC - First NERC Quarterly Application...Approval...Reliability Standards... - Sep. 06, 2011
                                        •  Matter Number M04025 – NSPI - Review...Reliability of Service at NSPI - April 04, 2011
                                        •  Matter Number M03815 – NSPI - Backup Control Centre - $3,222,066 - December 24, 2010
                                        •  Matter Number M03324 – NERC - NERC Reliability Standards; and NPCC Regional Reliability Criteria - June 29, 2010
                                        •  Matter Number M01989 – NSPI - CIP Standards Implementation - $422,923 - July 22, 2009
                                        •  Matter Number M01871 – NSPI - Report to the UARB Regarding NSPI/NB Power Interconnection - June 30, 2009

   •  M07048    Riverport Electric Light Commission - Request...Addition to the Electric Utility's Rules and Regulations - August 25, 2015
                                 The Riverport Electric Light Commission, Riverport, Lunenburg County, Nova Scotia, has been approached by one
                                 of our customers wanting to install "Net Metering" in his new home which is currently under construction.  There
                                 has also been other inquires for this service from a few other customers.  Our panel of five Commissioners have
                                 discussed and voted to go forward with the service if approved by the Utility and Review Board.  This is a service
                                 not presently offered by Riverport Electric Light Commission.  The Commission has adopted Nova Scotia Power's
                                 approved regulation for the same service with a few minor changes to reflect Riverport Electric Light Commission.
                                 We have also changed the name from "net metering" to "Self Generation Offset".  The Utility requests that the
                                 UARB find attached Riverport Electric Light Commission's application for this addition to our Rules and Regulations.

   •  M07012    Efficiency Nova Scotia Corporation - 2015 Q2 Demand Side Management (DSM) Quarterly Report - August 4, 2015
                                 – "Demand Side Management" refers to any program or activity designed to influence the amount and timing of
                                 electricity usage, and ultimately reduce the overall demand for electricity – and thus to reduce the need to build
                                 more electricity generating plants.  "Efficiency Nova Scotia" is a franchise awarded by the Province of Nova Scotia
                                 to EfficiencyOne, an independent not-for-profit corporation.
                                – In the second quarter of 2015, Efficiency Nova Scotia achieved success with Demand Side Management program
                                 results.  33.2 GWh of energy savings were achieved in Q2 for an investment of $8.2 million, with a year-to-date
                                 total of 62.2 GWh of energy savings and an investment of $15.8 million.  Efficiency Nova Scotia is confident it will
                                 achieve its 2015 energy savings goal within its approved investment amount of $39.0 million...
                                                                                           References:
                                        •  Matter Number M07148 – Efficiency Nova Scotia Corp. - 2015 Q3 DSM Quarterly Report
                                        •  Matter Number M07012 – Efficiency Nova Scotia Corp. - 2015 Q2 DSM Quarterly Report
                                        •  Matter Number M06869 – Efficiency Nova Scotia Corp. - 2015 Q1 DSM Quarterly Report
                                        •  Matter Number    ???     – Efficiency Nova Scotia Corp. - 2014 Q4 DSM Quarterly Report
                                        •  Matter Number M06733 – EfficiencyOne Application...Supply Agreement...Nova Scotia Power Inc...
                                        •  Matter Number M06524 – Efficiency Nova Scotia Corp. - Update on Implementation...
                                        •  Matter Number M06500 – Efficiency Nova Scotia Corp. - 2014 Q3 DSM Quarterly Report
                                        •  Matter Number M06395 – Efficiency Nova Scotia Corp. - 2014 Q2 DSM Quarterly Report
                                        •  Matter Number M06248 – Efficiency Nova Scotia Corp. - 2014 Q1 DSM Quarterly Report
                                        •  Matter Number    ???     – Efficiency Nova Scotia Corp. - 2013 Q4 DSM Quarterly Report
                                        •  Matter Number M05956 – Efficiency Nova Scotia Corp. - 2013 Q3 DSM Quarterly Report
                                        •  Matter Number M05904 – Efficiency Nova Scotia Corp. - Various 2012 and 2013 Reports

   •  M07010    NSPI - Authorization to Overspend (ATO) - 2015 Sacrificial Anode Installation Program - $2,133,377 - July 31, 2015
                                 Sacrificial anodes are highly active metals that are used for cathodic protection to prevent a less active material
                                 surface from corroding.  This project will systematically install sacrificial anodes on steel transmission structures
                                 and key anchors identified as corroding or at a high risk for corrosion.  This program, along with a specialized
                                 transmission steel towers inspection and the steel tower refurbishment will identify, quantify and address
                                 corrosion issues on steel assets throughout the province.  NS Power has approximately 2,000 steel towers
                                 in the transmission system.  This expanded project would allow for anodes to be installed on approximately
                                 200 structures or 10% of the steel towers, compared to only approximately 25 structures that were included
                                 in the original project.  Anode installations under this expanded project will be prioritized based on inspection
                                 results, criticality of the line and age of the line.  Past transmission tower inspections did not include below-grade
                                 inspection of the towers.  Tower failures that have occurred over the last two years have shown corrosion below
                                 grade.  This led to changes in the inspection process for NS Power. Because of this extensive inspection process,
                                 transmission inspections completed throughout 2014 and 2015 identified more advanced corrosion on
                                 transmission steel towers than originally anticipated in the 2015 ACE Plan filing.  The 2015 ACE Plan filing
                                 included a scope of 280 anode installations.  As a result of more detailed inspections, an increase in anode
                                 installations from 280 anodes to 1,960 is required and included in this ATO submission.  Increasing the scope
                                 of this capital work order to 1960 anode installations will help mitigate the risk of tower failure due to corrosion.

   •  M07009    NSPI - 2015 ACE Plan Capital Item... - LIN (Lingan) CW (Cooling Water) Debris Removal... - $1,746,988 - July 31, 2015
                                 The purpose of this project is to install a Cooling Water (CW) debris removal system on Units 3 and 4 which will
                                 remove debris prior to entering and damaging the CW screens and the CW pumps.  Units 3 and 4 see the majority
                                 of the eel grass as they are the first units that take suction from the canal.  The debris causing the damage to the
                                 CW equipment is large eel grass mats which enter the CW canal as they exit Lingan Bay.  As the bay's bottom
                                 changes and the bay becomes more shallow over time, the amount of eel grass continues to increase slowly.
                                 This in turn increases the amount of eel grass entering the CW canal, causing damage to the CW screens and
                                 pumps.  Why do this project?  Eel grass entering the CW canal in large mats builds up against the screens,
                                 damaging them and creating the need for costly screen rebuilds.  Once a screen is damaged and requires repairs
                                 it must be taken out of service, leaving one screen to filter all the water for the two CW pumps for the unit.  As the
                                 eel grass builds up on the screen, the water flow is inhibited to the CW pumps reducing the flow through the pumps
                                 and in some cases forces the plant to take one pump out of service.  This reduction in condenser cooling capacity
                                 causes an increase in the backpressure on the turbine, creating a heat rate performance penalty (a reduction in the
                                 unit's energy efficiency – less energy output to the grid for a given quantity of energy consumed as fuel).  Another
                                 effect caused by the large volume of eel grass is the screen wash cannot remove all the debris from the screen
                                 and it is carried over into the sump where it travels into the pump's suction, throwing the pump out of balance and
                                 causing the need for an expensive pump rebuild and reducing the output (generating capacity) of the unit.  Why do
                                 this project now?  The eel grass events are increasing yearly and in 2013 an event occurred where eel grass was
                                 able to get by the CW screen through carryover and caused a CW pump to fail, derating the generating unit.

   •  M07008    NSPI - 2015 ACE Plan Capital Item... - Prime Brook (Sydney) Substation Addition - $4,300,627 - July 31, 2015
                                 The long term solution for the electrical load growth in Membertou is a new substation, which will be located on
                                 Gabarus Hwy in Prime Brook (not George Street as originally planned).  This substation will be NSPI standard
                                 construction with a capacity of 15/20/25 MVA (megavolt-amperes), located at the intersection of the L-6539
                                 corridor and Highway 327.  This new subtation will be tapped from L6539, an existing 138kV transmission line
                                 that connects 2S Victoria Junction to 3S Gannon Road substations.  It will include four distribution feeders to
                                 supply the Membertou area as well as provide transfer capability to 4S-Townsend Street and 11S-Keltic Drive.
                                 Sydney 4kV to 12kV distribution conversions are underway – Mason St., Cabot St. and Rockdale Ave. conversions
                                 are complete.  Further conversion projects will continue until the eventual retirement of 6S-Terrace Street.

   •  M07007    NSPI - HYD (Hydro) Wreck Cove Controls Upgrade - $3,802,446 - July 31, 2015
                                 Wreck Cove is the largest hydro facility in the NS Power fleet and is required to maintain a high level of reliability
                                 for system stability and NERC requirements (black start and ten-minute reserve).  Wreck Cove has been evaluated
                                 as the top priority for Hydro automation projects due to its remote location and importance to the system stability.
                                 This project will provide Wreck Cove with a robust communication and control system for dam and environmental
                                 monitoring, as well as generator condition monitoring and control, which will ensure its reliability.  This project will
                                 cover new instrumentation installations and/or replacements, Programmable Logic Controller (PLC) replacements,
                                 Distributed Control System (DCS) installation, and transfer of the information back to the NS Power Data Centre.
                                 The PLC is a computer used for automation of electromechanical processes, such as switches, motor start/stop
                                 control, or light fixtures.  The main microprocessors are only one component of the PLC networks – others are
                                 Input/Output (I/O) Modules, communication backplanes, and programming software.  NS Power plans to upgrade
                                 the Wreck Cove control and communication system based on an evaluation performed under that strategy.  This
                                 project will consist of four phases: Scoping, Design, Construction and Commissioning of the Wreck Cove facility.
                                 The current control system and level of instrumentation will be assessed.  Design of a modern control system
                                 followed standards developed within NS Power for flexibility, spare parts availability and technical support.
                                 This system was installed at the Nictaux Generating Station (Matter Number M06045 - CI 45115 approved by
                                 the UARB on March 17, 2014) as a pilot project and learnings from that project are being incorporated into this
                                 project as well as NS Power standards already in use across the thermal fleet.
                                                                                           Reference:
                                        •  Matter Number M06045 – CI 45115 Nictaux Plant Automation - approved by UARB March 17, 2014

   •  M07006    NSPI - 2015 ACE Plan Capital Item... - 85S Cable Termination Replacement - $623,523 - July 31, 2015
                                 The purpose of this project is to retire and replace one existing 144kV cable terminator and refurbish a second
                                 in the 85S - Wreck Cove substation.  The project also requires the purchase of a spare 144kV cable terminator.
                                 The project will also take the opportunity to sample and make repairs to the existing low pressure oil systems.
                                 Why do this project?  There are twelve cable terminations in total at the Wreck Cove site; six in the underground
                                 powerhouse, and six in the above ground substation.  One requires refurbishment and another requires
                                 replacement due to their poor condition.  These two terminators are leaking insulating oil.  In conjunction with
                                 this, the low pressure oil system for the high voltage cables requires refurbishment.  These deficiencies pose
                                 a risk to the reliable operation of the Wreck Cove generating station.  Why do this project now?  A significant
                                 amount of oil has already leaked from the cables; this will continue until the terminations have been replaced
                                 or refurbished.  This oil loss, currently being captured by oil containment pads, leads to the loss of the insulating
                                 medium in the cable.  If this is allowed to continue the risk of failure (short circuit) of a cable a cable termination
                                 is significant.  Why do this project this way?  Refurbishment and replacement is required to ensure reliable
                                 operation of Wreck Cove and reduce environmental risks.  This work will be completed by an outside contractor
                                 due to the specialized nature of terminating high voltage cables.

   •  M07005    NSPI - U&U (Unforeseen and Unbudgeted) - Capacitor Bank Breaker Replacements - $411,871 - July 31, 2015
                                 Capacitor Bank Breakers are utilized by system operators to control voltage on the transmission system.
                                 This project includes the replacement of three capacitor bank breakers and the purchase of one spare unit.
                                 Breaker replacements will be prioritized based on age, number of operations, maintenance history and
                                 criticality to the transmission system.  There are currently 23 Capacitor Bank Breakers on the transmission
                                 system.  These breakers are critical to the operation of the transmission system as they are utilized to control
                                 the system voltage.  These breakers are operated frequently and as a result see higher duty cycles compared
                                 to our line breakers.  This higher duty cycle increases the probability of failure in these devices – as does the
                                 mere fact that switching capacitors (zero power factor) is significantly more severe than disconnecting
                                 high-voltage short circuits.  Issues on capacitor bank breakers in the Halifax area were discovered as a result
                                 of NS Power's preventative maintenance inspection cycle on these capacitor bank breakers.  This project
                                 decreases the probability of failure by replacing those most at risk.  A Capacitor Bank Breaker Replacement
                                 program was intended to begin in 2016.  In late 2014, after the 2015 ACE Plan was filed, issues on capacitor
                                 bank breakers in the Halifax area were discovered as a result of NS Power's preventative maintenance
                                 inspection cycle on these capacitor bank breakers.  In these instances, there was high contact resistance and
                                 subsequent thermal imaging showed elevated temperatures on the affected poles.  As these breakers are
                                 operated multiple times per day in some cases, replacing these three breakers at this time is the prudent
                                 decision to avoid failure.  Failure of these devices could result in voltage issues on the transmission system.

   •  M07003    NSPI - U&U - 103H-T63 Transformer Replacement - $1,706,615 - July 31, 2015
                                 This project provides for the removal of the existing 103H-T63 transformer, procurement of a new 30/40/50 MVA
                                 transformer, and all miscellaneous material, civil infrastructure and labour associated with installing the new
                                 transformer.  103H-T63 is a 45 MVA 138-69/23kV 3-winding transformer with a delta-wound tertiary rated for
                                 15 MVA.  This transformer serves as the primary 69kV supply for the 20H Spryfield (Halifax suburban) substation.
                                 The load on this transformer was found to be beyond the maximum nameplate rating in late 2014; the maximum
                                 recorded peak was 180% of the 69 kV rating.  Short term measures have been taken to reduce the VARs
                                 (volt-amperes reactive) by setting the tap changer in the max position as well as installing online gas monitors
                                 – these measures are not long term solutions and a permanent solution is required to rectify this issue.  Why do
                                 this project this way?  Replacement of this transformer with a unit with increased capacity in conjunction with
                                 converting the 20H Spryfield distribution feeders to 25kV is the best solution to rectify the currently overloaded
                                 transformer.  The other option is to install a second transformer – with associated breakers and switching – which
                                 would be a more costly option.
                                 Note: This will be a triple-rated transformer (30/40/50 MVA) which means the transformer has three modes of cooling: OA/FA/FOA.
                                 OA: The oil circulates through the windings by natural convection, driven only by the density difference between hot oil and cool oil.
                                 The cooling air circulates over the the heat-dissipating surfaces of the transformer by two forces: convection, and any breeze that may
                                 exist in the surrounding atmosphere.  The power capacity of any transformer is determined by the temperature of the winding; thus an
                                 outdoor transformer will have a significantly reduced power capacity on a calm day in summer compared to a windy day in winter.
                                 FA: Forced air cooling: the transformer is equipped with fans, driven by electric motors, placed to blow air over the heat-dissipating
                                 surfaces of the transformer.  The fan motors are thermostatically controlled depending on the temperature of the oil.
                                 FOA: Forced Oil and Air cooling: Forced (pumped) oil is combined with forced air cooling.

   •  M07002    NSPI - LIN3 (Lingan unit 3) U&U 8th Stage Diaphragm & Spill Strip Replacement - July 31, 2015
                                 $829,409 spent as at June 30, 2015.  This project is now complete – remaining spend is due to outstanding invoicing.
                                 Unit #3 at the Lingan Generating Station executed a planned major outage with significant capital investment
                                 in turbine and generator components in the spring of 2015.  As part of any major outage, additional capital
                                 investment is to be expected on components and failure mechanisms that cannot be assessed prior to the
                                 disassembly of the unit.  This project is an example of such components.  This project includes the replacement
                                 of the 8th stage diaphragm and spill strips 7, 5, 8, 13 and 14 on Unit #3.  The 8th stage diaphragm and the spill
                                 strips direct steam through the turbine, which ensures that as much steam as possible is used to turn the turbine.
                                 The diaphragm that was removed from service will be refurbished and held as a capital spare.  Why do this project?
                                 As part of the Lingan Unit #3 planned major outage, these components were inspected once the unit was
                                 disassembled.  Through this inspection, these items were found to be deteriorated beyond recommended
                                 specification which negatively affects the unit's heat rate (efficiency) and increases the cost of each megawatt
                                 due to wasted steam energy.  Why do this project now?  Lingan Unit #3 executed a planned major outage to
                                 complete a turbine overhaul and is not planned to have an extended outage for another eight years.
                                 Completing this work at this time avoids an unplanned unit outage to complete this work in the future, as the unit
                                 heat rate will continue to deteriorate as the condition of the components worsens over time.  The condition of
                                 these components could not have been inspected until the unit was disassembled for the planned major outage.

 
M00000-M00999    M01000-M01999    M02000-M02999    M03000-M03999    M04000-M04999
M05000-M05499    M05500-M05999    M06000-M06199    M06200-M06399
M06400-M06599    M06600-M06799    M06800-M06999    M07000-M07199


In the “Electricity” section of the UARB website
Matter Numbers M06800 to M06999

      Matter
    Number


   •  M06985    NSPI - 2013 Annual Executive Compensation Report and 2013 Non-Executive Compensation Information - July 6, 2015
                                 Pursuant to Section 64(B) of the Public Utilities Act, NS Power is required to file a report with the Utility and
                                 Review Board (UARB) identifying its executive employees, the position held by each executive employee and
                                 the remuneration to which each executive employee is entitled.  An initial report is to be filed on or before
                                 January 1, 2013 and again with each application for a general rate application (GRA) made after January 1, 2013...

   •  M06977    NSPI - Authorization to Overspend (ATO) - Distribution Routines - $2,645,434 - June 30, 2015
                                 Meters routine variance of $169K is mainly due to additional labour costs of $125K and associated
                                 Administrative Overheads of $172K over the approved ACE budget... In 2014, NS Power moved to
                                 a per unit based allocation which showed prior years were understated...

   •  M06976    NSPI - ATO - Transmission Routines - $5,064,815 - June 30, 2015
                                 Transmission Line Replacements, Additions, Modifications & Replacements' actual spending was $387 000 over
                                 the 2014 Approved ACE Budget.  The primary reason for this variance is due to additional work in T001 Provincial
                                 Transmission Line Replacement (Unplanned) creating an overspend of $1.090M.  Actual capital spending was higher
                                 for this routine than the approved budget due to one major storm response event (Ice storm, March 31, 2014 - $290k)
                                 and unplanned deteriorated hardware (Eye Bolt Replacements - $600k)...

   •  M06975    NSPI - Protection Risk Reduction 67N-Onslow 230kV - $3,448,979 - June 30, 2015
                                 This project will upgrade the protection system at 67N-Onslow (230kV) to comply with Northeast Power Coordination
                                 Council (NPCC) bulk power system protection risk reduction plan.  Why do this project?  In August 30, 2010 NPCC
                                 requested a Mitigation Plan for Bulk Power System (BPS) facilities that lack a second set of protective relays on a BPS
                                 element and/or second battery at a BPS substation.  The substation at Onslow lacks these requirements.  Why do this
                                 project now?  Implementation of all redundant protection and second battery is required to be completed by end of 2016.
                                 NS Power had four stations requiring this upgrade.  Because this work is significant, NS Power has chosen to complete
                                 the four stations requiring this upgrade over the next three year period.  NS Power is planning to complete 120H-Brushy
                                 Hill 230kV by end of 2014, 67N-Onslow to be completed in early 2015, 3C-Port Hastings to be completed by end of 2015
                                 and 88S-Lingan by the end of 2016.  Why do this project this way?  The project must be completed this way in order to
                                 comply with the NPCC Request to submit to NPCC a Mitigation Plan for bulk power system (BPS) facilities that lack a
                                 second set of protective relays on a BPS element and/or a second battery at a BPS substation.

   •  M06974    NSPI - POT (Point Tupper) Automatic Trash Rack Cleaning System $329,721 - June 30, 2015
                                 This project will see the installation of an automatic trash rack cleaning system to allow for safe cleaning of the
                                 trash racks.  Cooling water for the Point Tupper Generating Station main steam condenser is supplied from the
                                 Strait of Canso.  The water is cleaned by a stationary rack called a trash rack (consisting of vertical steel members)
                                 and by rotating screens (which remove debris smaller than the trash rack is capable of capturing).  The rotating
                                 screens are cleaned by a screen wash system whereby a series of strategically placed nozzles impact the screens
                                 removing debris from the screens.  In the past, the trash rack was cleaned manually by using rakes, picks, and other
                                 tools either from a floating deck in front of the intake or from the deck above the racks.  This is a very physically
                                 demanding task and requires protection for workers from falling in the water.  To mitigate the safety risk, a beam
                                 with a trolley above the floating platform has been installed to provide fall protection for workers.  Risk is higher in
                                 winter due to ice and windy conditions.  The existing method of cleaning the trash racks exposes employees
                                 to risks that could be eliminated with an automatic trash rake.

   •  M06973    NSPI - LED (Light Emitting Diode) Streetlights - Capital Work Order and Tariff Application - July 3, 2015
                                               Capital Work Order CI 40320 - LED Roadway Streetlight Conversion - $36,041,594
                                 In 2011, the Nova Scotia provincial government passed amendments to the Energy-efficient Appliances Act,
                                 which contemplated regulations requiring roadway lighting to meet prescribed efficiency standards.
                                 On September 10, 2012, the Energy-efficient Appliance Regulations were amended to impose restrictions on
                                 the use of non-LED roadway lighting.  The Regulations mandated that any fixture which failed, or required
                                 maintenance, be replaced with LED lighting in compliance with the American National Standard Practice for
                                 Roadway Lighting.  The Regulations provide that non-LED roadway lighting may not be used by NS Power
                                 after December 31, 2019 or by a municipality after December 31, 2022.

   •  M06972    NSPI - 70V-311 Bridgetown Voltage Conversion - 4kV to 12kV - $534,887 - June 30, 2015
                                 This project is the completion of the offloading of the overloaded stepdown transformer at 69V to 70V.  This project
                                 offloads 69V by converting Highway 1 from Church Street in Bridgetown to Highway 101 from 4kV to 12kV and the
                                 building of a new express feeder from 70V to Queen Street to support this load transfer between feeders... The 69V
                                 stepdown transformer and feeder 70V-311 which feeds 69V are overloaded with downline equipment approaching,
                                 or at nameplate ratings.  Operating equipment in an overloaded state reduces the reliability and predicted life of the
                                 equipment and can cause power quality issues for customers... Voltage below the bottom of the normal operating
                                 range has also been identified due to the overloaded equipment – corrective action was taken to raise voltage levels
                                 but they remain at the lower end of acceptable levels... The new double circuit from along Brickyard Road from 70V
                                 to Church/Queen St and the conversion of part of 69V-211 from 4kV to 12kV allows it to be fed directly from the 70V
                                 transformer, reducing the load on the 69V and 70V-311.  When both of these upgrades are complete, it will relieve
                                 loading and overloading issues on the system...
                                               There is an unfortunate confusion in the substation naming designations chosen decades ago by
                                               NS Power.  The designations "69V" and "70V" look like the standard short symbols for "volt" but
                                               this is the wrong interpretation. "69V" and "70V" are merely identification names, not metric units.

   •  M06971    NSPI - HYDRO - Wreck Cove Fire Suppression Upgrades - $1,034,915 - June 30, 2015
                                 The Wreck Cove fire protection system wells, water storage tanks and piping down to the powerhouse are
                                 original equipment and are 35 years old.  The resupply pumps function but provide insufficient flows to account
                                 for the water storage deficiencies of the system.  The tanks hold 60 000 US gallons [228 000 litres] of the
                                 157 200 US gallons [595 000 litres] of water required by code.  The condition of the steel tanks is poor due
                                 to their age.  There are deficiencies in the fire hose cabinet size and quantity... Recent condition assessments
                                 completed in March 2015 at Wreck Cove Generating System identified these deficiencies in the Fire Protection
                                 and Detection System in need of remediation within the next two years.  Wreck Cove Generating Station's current
                                 fire suppression system, as an existing facility, has been grandfathered under prior standards, and was not required
                                 to be continually upgraded as fire code standards are revised.  NS Power has ongoing discussions with the insurer
                                 and considers this an appropriate time to upgrade the fire suppression system to align with current National Fire
                                 Protection Association (NFPA) standards.

   •  M06970    NSPI - L8001 Steel Tower Replacement U&U - $928,377 - June 30, 2015
                                 Structure 58 on L8001, the 345kV line between 67N Onslow, Nova Scotia, and 410N Memramcook, New Brunswick,
                                 experienced a failure (collapsed) on February 3, 2015.  In an effort to restore the tower and line safely and as efficiently
                                 as possible, two temporary Gulfport structures – assembled on-site with materials from locally available stock, including
                                 extra-tall wood poles, spar arms, cross braces, insulators, and all hardware (bolts, etc.) – were used to start the repairs
                                 the following morning.  The line was restored to service two days later.  Contributing factors to the failure were loose
                                 guys, high winds and ice build-up.  NS Power has taken steps to mitigate the risk going forward by thoroughly inspecting
                                 the guys on all structures on L8001.  Any deficiencies will be addressed as required. NS Power is also implementing a
                                 similar inspection initiative on transmission lines with steel towers similar to L8001.  This project includes the replacement
                                 of Structure 58 on L8001 with a new steel tower, as well as the erection of the two Gulfport structures to temporarily
                                 restore the line to service.  The temporary Gulfport structures will stay in place while the new steel tower is procured and
                                 then installed.  This project is required to return to service Line 8001, the only 345 kV transmission line connecting Nova
                                 Scotia to New Brunswick.  This is an essential line designated by the North American Electric Reliability Corporation
                                 (NERC).  Why do this project now?  This failure caused the line to be taken out of service, which was addressed with the
                                 temporary Gulfport structures and will be permanently replaced with a new steel tower.  Why do this project this way?
                                 Leaving L8001 out of service is not an option.  Repairing the collapsed steel tower is not an option.  Installing the two
                                 temporary Gulfport structures was the only option to return L8001 to service immediately until the new steel tower is
                                 designed, procured and installed. 
                                        The interconnection between Nova Scotia and New Brunswick consists of the following three transmission circuits:
                                        — One 345 kV single circuit line from Onslow (NS) to Meramcook (NB) to Salisbury (NB)
                                        — Two single circuit 138 kV lines from Springhill (NS) to Meramcook (NB)
                                        Power is imported or exported over the inter-tie in proportion to the electrical characteristics of the lines.
                                        The 345kV line carries approximately 80 percent of the total power transmitted.
                                                                                           References:
                                        •  Matter Number M01871 – NSPI - Report to the UARB Regarding NSPI/NB Power Interconnection - June 30, 2009
                                        •  Reference List of Major Transmission Lines   Table 6-2 (page 6-4)
                                            Line Names for major 345 kV, 230 kV and 138 kV transmission lines in the Nova Scotia transmission system.

   •  M06966    Nova Scotia Power Inc. - NSPSO  2015-2024  10 Year System Outlook Report - June 30, 2015
                                 Section 3.4.6.1 of the Wholesale Market Rules Regulations provides: Subject to any contrary order of the Board, the
                                 Nova Scotia Power System Operator (NSPSO) shall submit the draft NSPSO system plan to the Utility and Review
                                 Board (UARB) for the Board's public comment process and for any Board review, and shall publish the draft plan each
                                 year by the end of June.  The Market Rules were issued by the Nova Scotia Department of Energy on February 1, 2007,
                                 to coincide with the proclamation of the Electricity Act which opened, on a limited basis, the Nova Scotia electricity market
                                 to wholesale competition.
                                             – On behalf of the NSPSO, the 2015 10 Year System Outlook is attached for the Board's review.
                                             Concurrent with this filing, NS Power will post this report on the NSPSO OASIS site.
                                                                                           References:
                                        •  Matter Number M06966 – Nova Scotia Power Inc. - NSPSO  2015-2024  10 Year System Outlook Report
                                        •  Matter Number M06300 – Nova Scotia Power Inc. - NSPSO  2014-2023  10 Year System Outlook Report
                                        •  Matter Number M05775 – Nova Scotia Power Inc. - NSPSO  2013-2022  10 Year System Outlook Report
                                        •  Matter Number M05061 – Nova Scotia Power Inc. - NSPSO  2012-2021  10 Year System Outlook Report
                                        •  Matter Number M04250 – Nova Scotia Power Inc. - NSPSO  2011-2020  10 Year System Outlook Report
                                        •  Matter Number M03347 – Nova Scotia Power Inc. - NSPSO  2010-2019  10 Year System Outlook Report
                                        •  Matter Number M01870 – Nova Scotia Power Inc. - NSPSO  2009-2018  10 Year System Outlook Report
                                                                                  •  Nova Scotia Power Inc. - NSPSO  2008-2017  10 Year System Outlook Report

   •  M06963    NSPI - 2015 ACE Plan Stakeholder Engagement Report - June 30, 2015
                                 — The ACE Stakeholder Engagement Report [Exhibit N-1 (348 pages) in Matter Number M06963] includes
                                 much information relevant to Nova Scotia Power's Annual Capital Expenditure Plan (ACE), a document
                                 containing details regarding all of NS Power's capital projects planned for a given calendar year.
                                 The ACE Plan is submitted to the Utility and Review Board (UARB) every year.
                                 — NS Power is pleased to report that as a result of a productive and cooperative stakeholder engagement process,
                                 agreement with the Consumer Advocate (CA) and Small Busness Advocate (SBA) on most items described herein
                                 has been reached.  The Industrial Group (IG) took no position.  In the few cases where agreement was not reached,
                                 NS Power and stakeholders have reached conclusions that NS Power does not anticipate require further direction
                                 from the Utility and Review Board at this time...

   •  M06962    NSPI - 2016 Base Cost of Fuel Reset (BCF) as required under the Fuel Adjustment Mechanism (FAM) - June 30, 2015
                                            A Fuel Adjustment Mechanism (FAM) is generally defined as a mechanism that allows periodic
                                            adjustments to customer rates, outside of general rate proceedings, to reflect increases and
                                            decreases in the utility's fuel costs provided they are prudently incurred.
                                                                Electricity Rates for 2016
                                 –  Nova Scotia Power Inc. is making this Application to the Nova Scotia Utility and Review Board (UARB, the Board)
                                 to establish the Base Cost of Fuel (BCF) in accordance with the Fuel Adjustment Mechanism (FAM) Plan of Adminis-
                                 tration (POA).   NS Power  has  followed  the  approved  FAM fuel and load forecast methodologies for the test year
                                 beginning January 1, 2016 to establish the rates proposed in this filing effective January 1, 2016.  The BCF component
                                 of NS Power's rates was last modified January 1, 2014 through the 2013/2014 General Rate Application (GRA) process.
                                 In that Application, the Company worked with stakeholders to achieve agreement for a Rate Stabilization Plan that
                                 ensured all over-recoveries of non-fuel expenses would be applied to under-recovered fuel costs to the benefit of
                                 customers.  This current Application represents a continuation of the Company's objective of providing stable,
                                 predictable and affordable rates for customers.
                                            –  See page 10 of [Exhibit N-1 under Matter Number M06962] in the UARB website:
                                            “As agreed by the Company and customer representative groups and as approved by
                                            the BoardNOTE 3 NS Power has not applied the incentive component of the FAM since 2011.”
                                            [NOTE 3] See the 2012 GRA Settlement Agreement (NSUARB-NSPI-P-892) as approved
                                            by the UARB in its decision 2011 NSUARB 184.  The terms of the Settlement Agreement
                                            are set out at paragraph 16 of the decision and approved at paragraph 36.
                                 –  Fuel is the single largest expense for NS Power to provide electricity to customers.  It represents
                                 approximately 40% of the total cost to provide Nova Scotians with safe, reliable electricity service.
                                 Under the FAM, fuel is a direct pass-through to customers, meaning that customers only pay the actual
                                 cost of fuel to NS Power.  That is, NS Power does not add a markup to the price it pays for fuel. 
                                 For 2016, the fuel required to generate electricity will cost in excess of $560 million ($1000 per minute 24/7/365).
                                 This is an increase of more than $110 million over fuel costs in the 2014 GRA.
                                 –  If NS Power does not include Port Hawkesbury Paper (PHP), which covers its own fuel costs
                                 under the Load Retention Tariff (LRT), the largest contributor to increased fuel costs in 2016 is
                                 the Community Feed-In Tariff (COMFIT) program, which was established by the province of Nova Scotia in 2010.
                                 –  Based on what was forecast in 2014, customers are paying for approximately 50 GWh of COMFIT
                                 energy in the current (2015) BCF rate.  For 2016, the amount of COMFIT energy approved by the province
                                 to be on the system – and the ensuing cost to customers – is forecast to increase more than tenfold.
                                 For details see [page 7 of Exhibit N-1 under Matter Number M06962] in the UARB website.
                                 –  COMFIT is relatively expensive energy which NS Power has a statutory obligation to purchase.  The result
                                 is that NS Power customers pay for COMFIT energy in 2016 with a weighted average cost of $144.70 per MWh
                                 (14.47¢ per kWh), as compared to electricity generated from existing NS Power assets (or purchased as imports)
                                 at a cost in the range of $40 to $60 per MWh (4.0¢ to 6.0¢ per kWh).
                                 –  While COMFIT projects only produce 5% of the system energy for 2016, COMFIT is responsible
                                 for approximately 15% of the total system fuel costs.
                                 –  On August 6, 2015, the Nova Scotia Energy Minister announced closure of the COMFIT program.  A Department
                                 of Energy news release stated that "all unapproved projects, extensions and lapsed-permit renewals will be considered
                                 on a case-by-case basis and processed within 60 days."  NS Power believes this will produce a positive impact on fuel
                                 costs and rates, but specific quantifiable impacts will not be known until after the Energy Department's 60-day process
                                 is completed.
                                                                                           References:
                                        •  M06733 - NSPI - Electricity Rates - 2015 NSUARB 204 - August 12, 2015
                                        •  M06290 - NSPI - Electricity Rates - 2015 NSUARB 9 - January 20, 2015
                                        •  M06536 - NSPI - Electricity Rates - 2014 NSUARB 204 - December 12, 2014
                                        •  M06277 - NSPI - Electricity Rates - Small General and General Tariff Revisions - June 12, 2014
                                        •  M06194 - NSPI - Annual and Regulated Financial Statements - 2013 & 2014 - April 15, 2014
                                                                  Calculation of Nova Scotia Power Inc's Return on Equity - P-888(2)
                                        •  M06194 - Emera - Annual Report 2013 - Exhibit N-6 in Matter Number M06194 - December 31, 2013
                                        •  NSPI - Electricity Rates - 2012 NSUARB 227 - December 21, 2012
                                        •  NSPI - Electricity Rates - 2013 General Rate Application (NSUARB P-893)
                                                                  NSPI Responses to SBA Information Requests [44 pages] - June 25, 2012
                                                                  NSPI Responses to NSUARB Information Requests [157 pages] - June 25, 2012
                                                                  List of 77 NSPI Responses to Various Information Requests
                                                                                            [13 GRA Items] - May 8, 2012
                                                                                            [44 Information Requests] - June 25, 2013 2012
                                                                                            [19 Information Requests] - July 23, 2013 2012
                                                                                            [One item, NSPI Reply Evidence, 213 pages] - September 7, 2012
                                        •  NSPI - Electricity Rates - 2011 NSUARB 184 - November 29, 2011
                                        •  M04104 - NSPI - Electricity Rates - 2012 General Rate Application (NSUARB P-892) - May 13, 2011
                                                                  NSPI Responses to EAC Information Requests [25 pages] - July 18, 2011
                                                                  NSPI Responses to NPB Information Requests [276 pages] - July 18, 2011
                                                                  NSPI Responses to NPB Information Requests [45 pages] - July 13, 2011
                                                                  NSPI Responses to Woolridge Information Requests [42 pages] - July 14, 2011
                                                                  NSPI Responses to Multeese Information Requests [37 pages] - June 10, 2011
                                        •  NSPI - Electricity Rates - 2008 NSUARB 140 - November 5, 2008
                                        •  NSPI - Electricity Rates - NSPI Reply Evidence - September 10, 2008
                                        •  NSPI - Electricity Rates - 2007 NSUARB 174 - December 10, 2007
                                        •  NSPI - Electricity Rates - 2007 NSUARB 8 - February 5, 2007
                                        •  NSPI - Electricity Rates - 2006 NSUARB 97 - September 28, 2006
                                        •  NSPI - Electricity Rates - 2006 NSUARB 23 - March 10, 2006
                                        •  NSPI - Electricity Rates - 2005 NSUARB 27 - March 31, 2005
                                        •  NSPI - Electricity Rates - 2003 NSUARB 139 - November 21, 2003
                                        •  NSPI - Electricity Rates - 2003 NSUARB 138 - November 21, 2003
                                        •  NSPI - Electricity Rates - 2003 NSUARB 91 - August 1, 2003
                                        •  NSPI - Electricity Rates - 2002 NSUARB 59 - October 23, 2002
                                        •  NSPI - Electricity Rates - 2002 NSUARB 1 - January 24, 2002
                                        •  NSPI - Electricity Rates - 2000 NSUARB 72 - May 24, 2000
                                        •  NSPI - Electricity Rates (recurring pole attachment charges) - NSUARB-P-868 - March 1, 1996

   •  M06960    NSP Maritime Link Incorporated v. Ronald Reginato
Determination of compensation owing for expropriation of transmission line easements over lands located at
        Gabarus Highway, Marion Bridge, Cape Breton County and owned by Donald Burke and Virginia Burke - June 25, 2015
These easements are required for the purposes of the installation, maintenance
and operation of power line infrastructure required for the Maritime Link Project (see M06929 below).

   •  M06959    NSP Maritime Link Incorporated v. The Estate of Wayne Lorway by personal representatives Judy Lorway,
Richard Sean MacGregor Lorway and Charles Read - June 25, 2015
Determination of compensation owing for expropriation of transmission line easements over lands located at
        Hillside Road, Albert Bridge, Cape Breton County, owned by Estate of Wayne Lorway...
These easements are required for the purposes of the installation, maintenance
and operation of power line infrastructure required for the Maritime Link Project (see M06929 below).
♦ This matter has been settled – per email dated July 15, 2015, to NSUARB.

   •  M06958    NSP Maritime Link Incorporated v. Donald and Virginia Burke
Determination of compensation owing for expropriation of transmission line easements over lands located at
        3898 Highway 22, Albert Bridge, Cape Breton County, owned by Donald Burke and Virginia Burke - June 25, 2015
These easements are required for the purposes of the installation, maintenance
and operation of power line infrastructure required for the Maritime Link Project (see M06929 below).
NOTE: Exhibit B-1 [104 pages] in Matter Number M06958 provides an excellent overview of
the legal documentation that is involved in a proceeding like this.

   •  M06957    NSP Maritime Link Incorporated v. Jerry Harvey
Determination of compensation owing for expropriation of transmission line easements over lands located at
        Louisbourg Main-a-dieu Road, Louisbourg, Cape Breton County, Nova Scotia - June 25, 2015
These easements are required for the purposes of the installation, maintenance
and operation of power line infrastructure required for the Maritime Link Project (see M06929 below).
NOTE: Exhibit H-1 [116 pages] in Matter Number M06957 provides an excellent overview of
the legal documentation that is involved in a proceeding like this.

   •  M06956    NSP Maritime Link Incorporated v. Albert Wayne Musgrave and Russell Musgrave
Determination of compensation owing for expropriation of transmission line easements over lands located at
        Frenchvale Road, Frenchvale, Cape Breton County, owned by Albert Wayne Musgrave and Russell Musgrave - June 25, 2015
These easements are required for the purposes of the installation, maintenance
and operation of power line infrastructure required for the Maritime Link Project (see M06929 below).
♦ This matter has been settled – per email dated July 15, 2015, to NSUARB.

   •  M06955    NSP Maritime Link Incorporated v. Michael Edward Bishop, Cecilia MacBride Bishop and Michael William Bishop
Determination of compensation owing for expropriation of transmission line easements over lands located at
        522 Seaview Drive, Upper North Sydney, Cape Breton County,
        owned by Michael Edward Bishop, Cecilia MacBride Bishop and Michael William Bishop - June 25, 2015
These easements are required for the purposes of the installation, maintenance
and operation of power line infrastructure required for the Maritime Link Project (see M06929 below).
NOTE: Exhibit B-1 [103 pages] in Matter Number M06955 provides an excellent overview of
the legal documentation that is involved in a proceeding like this.

   •  M06954    NSP Maritime Link Incorporated v. Wallace Cartwright, Personal Representative of the Estate of Kenneth George Cartwright
Determination of compensation owing for expropriation of transmission line easements over lands located at
        Georges River Road, Georges River, Cape Breton County, Nova Scotia - June 25, 2015
These easements are required for the purposes of the installation, maintenance
and operation of power line infrastructure required for the Maritime Link Project (see M06929 below).
NOTE: Exhibit C-1 [103 pages] in Matter Number M06954 provides an excellent overview of
the legal documentation that is involved in a proceeding like this.

   •  M06953    NSP Maritime Link Incorporated v. Carl Cartwright and Joanne Cartwright
Determination of compensation owing for expropriation of transmission line easements over lands located at
        Grand Narrows Road, Georges River, Cape Breton County - June 25, 2015
These easements are required for the purposes of the installation, maintenance
and operation of power line infrastructure required for the Maritime Link Project (see M06929 below).
NOTE: Exhibit C-1 [102 pages] in Matter Number M06953 provides an excellent overview of
the legal documentation that is involved in a proceeding like this.

   •  M06952    NSP Maritime Link Incorporated v. Percy MacKenzie
Determination of compensation owing for expropriation of transmission line easements over lands located at
        Alder Point Road, Bras D'Or and 883 Georges River Road, Georges River, Cape Breton County - June 25, 2015
These easements are required for the purposes of the installation, maintenance
and operation of power line infrastructure required for the Maritime Link Project (see M06929 below).
NOTE: Exhibit M-1 [199 pages] in Matter Number M06952 provides an excellent overview of
the legal documentation that is involved in a proceeding like this.
                                                                Reference:
              Maritime Link expropriation opposed by 16 landowners in Cape Breton
Percy MacKenzie of George's River is one of 16 Cape Breton residents resisting having their land expropriated for the Maritime Link — CBC News, July 17, 2015

   •  M06950    NSP Maritime Link Incorporated v. Creighton Briggs, Melanie Marsh, Elaine Ingraham and Ronata Timmons
Determination of compensation owing for expropriation of transmission line easements over lands located at
        Point Aconi Road, Millville, Cape Breton County, Nova Scotia - June 25, 2015
These easements are required for the purposes of the installation, maintenance
and operation of power line infrastructure required for the Maritime Link Project (see M06929 below).
NOTE: Exhibit B-1 [108 pages] in Matter Number M06950 provides an excellent overview of
the legal documentation that is involved in a proceeding like this.

   •  M06949    NSP Maritime Link Incorporated v. Francis and Julie Dobrowolski
Determination of compensation owing for expropriation of transmission line easements over lands located at
        Point Aconi Road, Mill Creek, Cape Breton County, Nova Scotia - June 25, 2015
These easements are required for the purposes of the installation, maintenance
and operation of power line infrastructure required for the Maritime Link Project (see M06929 below).

   •  M06948    NSP Maritime Link Incorporated v. James Kennedy
Determination of compensation owing for expropriation of transmission line easements over lands located at
        Highway No. 125, Upper North Sydney, Cape Breton County, Nova Scotia - June 25, 2015
These easements are required for the purposes of the installation, maintenance
and operation of power line infrastructure required for the Maritime Link Project (see M06929 below).

   •  M06947    NSP Maritime Link Incorporated v. Nelson MacDonald and Donna Glencross
Determination of compensation owing for expropriation of transmission line easements over lands located at
        Georges River, Cape Breton County - June 25, 2015
These easements are required for the purposes of the installation, maintenance
and operation of power line infrastructure required for the Maritime Link Project (see M06929 below).

   •  M06946    NSP Maritime Link Incorporated v. John Kennedy King
Determination of compensation owing for expropriation of transmission line easements over lands located at
        Church Road, Little Bras D'Or, Cape Breton County owned by John Kennedy King and Mary Katherine King - June 25, 2015
These easements are required for the purposes of the installation, maintenance
and operation of power line infrastructure required for the Maritime Link Project (see M06929 below).

   •  M06942    NSP Maritime Link Incorporated v. Margaret Rose Jessome
Determination of compensation owing to Margaret Rose Jessome for expropriation of transmission line easements
        over lands located at 57 Point Aconi Road, Bras d'Or, Cape Breton County - June 24, 2015
These easements are required for the purposes of the installation, maintenance
and operation of power line infrastructure required for the Maritime Link Project (see M06929 below).
                                                                Reference:
              Maritime Link expropriation compensation to go to Review Board
The transmission corridor runs past Rose Jessome's one-storey, three-bedroom home on Point Aconi Road — Halifax Chronicle-Herald, June 26, 2015


   •  M06930    NSPI - NERC Bulk Electric System (BES) Definition Project Application - June 15, 2015
                                 North American Electric Reliability Corporation (NERC)       Federal Energy Regulatory Commission (FERC)
                                 Approved by FERC    • Order No. 773 – Revisions to Electric Reliability Organization (ERO)
                                                                        Definition of Bulk Electric System (BES) and Rules of Procedure (Issued December 20, 2012)
                                 Approved by FERC    • Order No. 773-A – Revisions to Electric Reliability Organization (ERO)
                                                                        Definition of Bulk Electric System (BES) and Rules of Procedure (Issued April 18, 2013)
                                 The NERC Glossary defines an Element as any electrical device with terminals that may be connected to other electrical
                                 devices such as a generator, transformer, circuit breaker, bus section, or transmission line.  An Element may be comprised
                                 of one or more components.  The Nova Scotia electricity system Elements which NS Power requests to be either included
                                 with the BES or exempted from the BES are described in the exception requests set out in Appendix H hereto...
                                                                                           Reference:
                                        •  Comments from the Canadian Electricity Association regarding FERC's order certifying NERC as the ERO (Aug. 2006)


                                        Maritime Link across Cabot Strait       500 MW        670 000 horsepower
   •  M06929    NSPML - Nova Scotia Power Maritime Link Inc. - NSPML 2015 Q2 Quarterly Report - June July 15, 2015
                                 — This [Exhibit N-1 in Matter Number M06929] is the Q2 2015 Quarterly Report for the Maritime Link as directed by the UARB.
                                                                                           References:
                                        •  Matter Number M06929 – NSPML - Maritime Link 2015 Q2 Quarterly Report - June 15, 2015
                                        •  Matter Number M06865 – NSPML - Maritime Link (Cabot Strait) Submarine Cable Report - April 30, 2015
                                               Design, Supply and Installation of ±200 kV DC Submarine Cable System [Exhibit N-1 in Matter Number M06865]
                                        •  Matter Number M06821 – NSPML - Maritime Link 2015 Q1 Quarterly Report - April 15, 2015
                                        •  Matter Number M06592 – NSPML - Maritime Link 2014 Q4 Quarterly Report - December 15, 2014
                                        •  Matter Number M06477 – NSPML - Maritime Link 2014 Q3 Quarterly Report - October 15, 2014
                                        •  Matter Number M06280 – NSPML - Maritime Link - 2013 Affiliate Code of Conduct Annual Report - June 13, 2014
                                        •  Matter Number M06279 – NSPML - Maritime Link 2014 Q2 Quarterly Report - June 13, 2014
                                        •  Matter Number M06191 – NSPML - Maritime Link 2014 Q1 Quarterly Report - April 15, 2014
                                        •  Matter Number M06024 – NSPML - Maritime Link 2013 Q4 Quarterly Report - December 13, 2013
                                        •  Matter Number M05419 – NSPML - Application for approval of the Maritime Link Project... - January 28, 2013
                                        •  Matter Number M05419 – NSP Maritime Link Incorporated (Re), 2013 NSUARB 154 (CanLII)    July 22, 2013
                                               §6.4.2  Submarine (underwater) and Land Cables
                                        •  Matter Number M05419 – NSP Maritime Link Incorporated (Re), 2013 NSUARB 242 (CanLII)    November 29, 2013
                                               §5.2  What should be the reporting requirements for NSPML during the course of the Maritime Link (ML) Project?
                                                       The reporting requirements are set out in §7 of the ML Regulations.
                                        •  Maritime Link Joint Development Agreement - Summary of the Commercial Agreements [1636 pages] - Dec. 17, 2012
                                               The Maritime Link shall consist of facilities for converting and transmitting energy and capacity from
                                               Newfoundland and Labrador to Cape Breton Island, Nova Scotia.  It will be designed, engineered and
                                               constructed to have a capacity of 500 megawatts and an initial service life of 50 years... Emera shall
                                               pay the costs of, and own, the Maritime Link, and provide Nalcor with transmission capacity in the
                                               Maritime Link and the Nova Scotia transmission rights, in exchange for which Emera shall be entitled
                                               to receive the Nova Scotia BlockSee NOTE NSB below for a term of 35 years from first commercial power...
                                               Each Party hereby agrees to each of the other Parties making this Agreement public at any time...
                                                         * NOTE NSB: The phrase "Nova Scotia Block" occurs 201 times in this Summary of the Commercial Agreements.

   •  M06921    NSPI - Regulation 5.3 - Alternative Billing Plans, Section A - Budget Plan - Report - June 05, 2015
                                 This is a report on the operation of NS Power's Budget Billing Plan.
                                                  Regulation 5.3 - Alternative Billing Plans
                                 A customer may make application to the Company, at any time during the year, for the Budget Plan which
                                 has a twelve-month budget period... A Budget Plan customer shall be billed monthly.  The monthly billing
                                 shall be based upon the average kilowatt-hour usage of the customer at the premises to which the application
                                 relates for the preceding budget period, as adjusted for normal weather... The Company shall read the meter
                                 on a monthly or bi-monthly basis and at the end of the budget period of electric service, the Company shall
                                 render a bill which shall show the new budget payment amount for the next twelve months and show the
                                 amount owing based on the meter readings less the amounts paid...

   •  M06911    NSPI - Natural Gas Report - November 1, 2014 to March 31, 2015 - May 29, 2015
                                 The winter period of 2014-2015 (November to March) saw North East gas prices at well below the levels
                                 of a year ago, even though temperatures in the area were colder.  With the collapse in crude oil prices,
                                 world Liquefied Natural Gas (LNG) pricing and fuel oil pricing were also well below forecasted levels. 
                                 NS Power's gas consumption during the winter period was limited due to fuel switching to heavy fuel oil,
                                 which provided a more economic source of fuel.

   •  M06899    NSPI - Proposed Changes to Regulation 5.5 Billing Adjustments - May 27, 2015
                                 NS Power is seeking the Board's approval to amend Regulation 5.5 to remove the requirement for the Company
                                 to conduct an "in position" meter test at the customer's premises in the event of a billing dispute.  Specifically,
                                 NS Power proposes replacing the "in position" test with the "As Found Meter Test", which the Company has
                                 determined to be a more effective a procedure for testing customer meters...
                                        ♦  A detailed statement of NSPI's argument supporting this application is contained in its 19-page letter
                                            [available in the Board's website – Exhibit N-1 in Matter Number M06899] to the UARB, dated May 26, 2015.
                                                                                           References:
                                        •  Matter Number M06674 – 2015 NSUARB 175 - UARB Decision - June 29, 2015
                                                            NOTE: When tested at points throughout the measuring range of the meter, its accuracy
                                                           must fall within +/- 3% to be considered accurate as per Measurement Canada's guidelines.

                                        •  Legislation – Electricity and Gas Inspection Regulations      Testing Fees and Charges
                                        •  Electricity Meters – Measurement Canada - Presentation to Ontario Smart Grid Working Group
                                        •  Specifications for Approval of Type of Electricity Meters, Instrument Transformers and Auxiliary Devices [145 pages]

   •  M06890    NERC - North American Electric Reliability Corporation - Q1 2015 - Application...Approval of Reliability Standards - May 13, 2015
                                 — Since the NS Power electrical system is interconnected with the North American bulk power system, NS Power
                                 is required to comply with standards and codes as governed by the North American Electric Reliability Corporation
                                 (NERC) and the Northeast Power Coordinating Council (NPCC).  This obligation to comply extends to Market
                                 Participants and generators interconnected with the Nova Scotia Power grid. 
                                 Links to the applicable standards and codes are published on the OASIS website.
                                 — Some or all of NERC's Reliability Standards are mandatory in the Canadian provinces of Alberta, British Columbia,
                                 Manitoba, New Brunswick, Nova Scotia [boldface emphasis added], Ontario, Quebec, and Saskatchewan.
                                 ♦  See Memorandum of Understanding between Nova Scotia Utility and Review Board
                                                        and the North American Electric Reliability Corporation (signed Dec. 22, 2006)
                                 ♦  See Memorandum of Understanding between Nova Scotia Power Inc. and the Northeast Power Coordinating Council, Inc.
                                                        and the North American Electric Reliability Corporation (signed May 11, 2010)
                                 ♦  Pursuant to the terms of the MOU with Nova Scotia Power Inc., enclosed is their recommendation to
                                                        the Nova Scotia Utility and Review Board supporting the adoption of NERC Reliability Standards
                                                        and NPCC Criteria in that province... (dated December 17, 2010)
                                 ♦  See Application by North American Electric Reliability Corporation for approval of its Reliability Standards,
                                                        and an application by Northeast Power Coordinating Council, Inc. for approval of its
                                                        Regional Reliability Criteria (UARB Order dated July 20, 2011)
                                 ♦  Before the Nova Scotia Utility and Review Board of the Province of Nova Scotia – NERC - November 30, 2011
                                                        Q3 2011 Application for Approval...Reliability Standards...North American Electric Reliability Corp. [115 pages]
                                 ♦  Before the Nova Scotia Utility and Review Board of the Province of Nova Scotia – NERC - February 26, 2013
                                                        Q4 2012 Application for Approval...Reliability Standards...North American Electric Reliability Corp. [109 pages]
                                                                                           References:
                                        •  Matter Number M07051 – NERC - North American Electric Reliability Corporation - Q2 2015 - August 28, 2015
                                        •  Matter Number M06890 – NERC - North American Electric Reliability Corporation - Q1 2015 - May 13, 2015
                                        •  Matter Number M06728 – NERC - North American Electric Reliability Corporation - Q4 2014 - February 23, 2015
                                        •  Matter Number M06545 – NERC - North American Electric Reliability Corporation - Q3 2014 - November 26, 2014
                                        •  Matter Number M06525 – NSPI - Onslow 345 kV Node Swap - November 14, 2014
                                        •  Matter Number M06427 – NERC - N.A. Electric Reliability Corporation - 2015 Business Plans etc. - Sep. 17, 2014
                                        •  Matter Number M06363 – NERC - North American Electric Reliability Corporation - Q2 2014 - August 15, 2014
                                        •  Matter Number M06294 – NSPI - Protection Risk Reduction 67N-Onslow 230kV - $2,870,285 - June 25, 2014
                                        •  Matter Number M06258 – NERC - North American Electric Reliability Corporation - Q1 2014 - May 20, 2014
                                        •  Matter Number M06132 – NERC - North American Electric Reliability Corporation - Q4 2013 - February 28, 2014
                                        •  Matter Number M06011 – NERC - North American Electric Reliability Corporation - Q3 2013 - November 26, 2013
                                        •  Matter Number M05944 – NERC - N.A. Electric Reliability Corporation - 2014 Business Plans etc. - Nov. 04, 2013
                                        •  Matter Number M05862 – NERC - North American Electric Reliability Corporation - Q2 2013 - August 30, 2013
                                        •  Matter Number M05713 – NERC - North American Electric Reliability Corporation - Q1 2013 - May 31, 2013
                                        •  Matter Number M04460 – NERC - First NERC Quarterly Application...Approval...Reliability Standards... - Sep. 06, 2011
                                        •  Matter Number M04025 – NSPI - Review...Reliability of Service at NSPI - April 04, 2011
                                        •  Matter Number M03815 – NSPI - Backup Control Centre - $3,222,066 - December 24, 2010
                                        •  Matter Number M03324 – NERC - NERC Reliability Standards; and NPCC Regional Reliability Criteria - June 29, 2010
                                        •  Matter Number M01989 – NSPI - CIP Standards Implementation - $422,923 - July 22, 2009
                                        •  Matter Number M01871 – NSPI - Report to the UARB Regarding NSPI/NB Power Interconnection - June 30, 2009

   •  M06887 NSPI - Halifax City - Morris St./Water St. Underground U&U - $948,562 - April 30, 2015
                                 This project is required to convert existing 25kV and 4kV overhead plant on Hollis St., Morris St. and
                                 Lower Water St. in Halifax to underground plant.  Why do this project?  As part of Halifax Regional
                                 Municipality's pole-free zone in downtown Halifax, the existing overhead plant on Hollis St., Morris St.
                                 and Lower Water St. needs to be converted to underground plant.  Why do this project now?
                                 The new VIC building at the intersection of Hollis St. and Morris St. and the new NS Power building on
                                 Lower Water St. are both currently being built.  Doing this project now enables the coordination of the
                                 installation with the construction of the new buildings.  This project is required at this time to co-ordinate
                                 other construction activities associated with placing the electrical system underground.  Why do this project
                                 this way?  This is the most economical way to convert the existing overhead plant to underground plant.
                                                                                           References:
                                        •  Dendroarchaeological Investigation of the Morris Building, Halifax, Nova Scotia
                                        •  Charles Morris [1st] (1711-1781)
                                        •  Charles Morris [2nd] (1731-1802)
                                        •  Charles Morris [3rd] (1759-1831)

   •  M06885    NSPI - LIN (Lingan) E-Gallery Floor Replacement U&U - $2,365,470 - April 30, 2015
                                 The E coal gallery is the main support structure for the two conveyor belts carrying coal into the building
                                 servicing the four units at the Lingan Generating Station.  The floor of the structure is steel plate, which
                                 has deteriorated due to the corrosive nature of coal and the wet conditions caused by washing down the
                                 gallery for general maintenance.  In early 2014, the deterioration was found to be such where access to
                                 the E-Gallery was no longer safe.  Why do this project?  It is essential to have E-belt and the E Coal
                                 Gallery completely operational to ensure reliable energy production.  The E-gallery is the only route
                                 for fuel to get to the boilers.  The floor structure is essential for full access around the belts for
                                 long term maintenance and reliability.

   •  M06884    NSPI - 2015 Substation Polychlorinated Biphenyl (PCB) Equipment Removal Program - $1,236,351 - April 30, 2015
                                 This project provides for the costs associated with the PCB sampling of all substation oil-filled equipment
                                 and the removal of substation devices with 500 mg/kg or more of PCBs, to be in compliance with
                                 2008 Federal Environmental PCB Regulations.  The 2015 Program will also include replacement of
                                 some equipment where sampling was not feasible.  The 2008 Federal Environmental PCB Regulations
                                 were amended on January 1, 2015 to extend the deadline from 2015 to 2025 to replace PCB contaminated
                                 equipment.  NS Power was notified of this amendment in April 2014.

   •  M06883    NSPI - 20H Spryfield Voltage Conversion (Halifax City) - $480,510 - April 30, 2015
                                 This project will convert two sections of the distribution feeders 20H-305 and 20H-306 from 12kV to 25kV and
                                 transfer them from 20H Spryfield substation to the Armdale feeder 2H-411.  This conversion will also create
                                 room for cascade offloading of the overloaded feeder 20H-305 (over 400 amperes).  The additional benefit of
                                 this project is to reduce load on the 20H Spryfield substation which is approaching its contingency maximum.

   •  M06882    NSPI - LIN 3 (Lingan Unit 3) - U&U Generator Stator Re-Wedge - $441,755 - April 30, 2015
                                 This project includes the re-wedging of the Generator Stator on Unit #3 at the Lingan Generating Station.
                                 A planned major turbine/generator overhaul is taking place on Lingan Unit #3 (March/April 2015).  Why do
                                 this project?  Forty percent of the generator wedges were identified as loose during a recent inspection of
                                 the wedges during the 2015 Generator/Turbine outage.  This is beyond the design parameters established
                                 by the Original Equipment Manufacturer (OEM).  If this issue is not addressed, insulation damage could
                                 occur and a potential rewind of the stator may be required.  Why do this project now?  The recommendation
                                 from the OEM is to complete the generator stator re-wedging during the current planned outage.  Replacing
                                 the generator stator wedges at this time will avoid future unplanned unit outages.  The next planned major
                                 outage where this work could occur would be in 8-10 years.  The issue being addressed is a well-known
                                 failure mechanism on electrical generators.  NS Power always inspects this equipment as part of a planned
                                 major outage.  The necessity of this work could not be identified until the unit was fully disassembled.

   •  M06878    Efficiency Nova Scotia Corporation - Internal Audit...Residential Direct Install Program - April 30, 2015

   •  M06877    Efficiency Nova Scotia Corporation - Internal Audit, Program Internal Controls, Business Energy...Program - April 30, 2015

   •  M06872    Efficiency Nova Scotia Corporation - Employee Expenses, Expense Reports, Corporate Credit Cards - April 30, 2015

   •  M06871    Efficiency Nova Scotia Corporation - 2014 Financial Statements January 1, 2014 to December 31, 2014 - April 30, 2015
                                 Efficiency Nova Scotia is a franchise awarded by the Province of Nova Scotia
                                 to EfficiencyOne, an independent not-for-profit corporation.

   •  M06869    Efficiency Nova Scotia Corporation - 2015 Q1 Demand Side Management (DSM) Quarterly Report - April 30, 2015
                                 Quarterly report for the period January 1, 2015 through March 31, 2015
                                                                                           References:
                                        •  Matter Number M06395 – Efficiency Nova Scotia Corp. - 2014 Q2 DSM Quarterly Report
                                        •  Matter Number M06248 – Efficiency Nova Scotia Corp. - 2014 Q1 DSM Quarterly Report
                                        •  Matter Number M05956 – Efficiency Nova Scotia Corp. - 2013 Q3 DSM Quarterly Report
                                        •  Matter Number M05904 – Efficiency Nova Scotia Corp. - Various 2012 and 2013 Reports

   •  M06868    NSPML - NSP Maritime Link Inc.- 2014 Affiliate Code of Conduct Report - April 30, 2015
                                 NSPML - List of 152 Affiliated and Minority-Owned Companies (Attachment 4) [Exhibit N-1 in Matter Number M06868]
                                 NSPML - Entity List to the Nova Scotia Utility and Review Board - March 30, 2015
                                                                                           Reference:
                                       •  NSUARB - NSPI-P-882 In the matter of a Code of Conduct to govern the
                                         relations between Nova Scotia Power Inc. and its Affiliates - February 24, 2009

   •  M06865    NSPML - Maritime Link (Cabot Strait) Submarine Cable Report - April 30, 2015
                                 Review of Contract E11-18 - Design, Supply and Installation of ±200 kV DC Submarine Cable System
                                 —The purpose of this report is to provide an independent review of the Marine EPC1 contract E11-18 between the project
                                 developer NSP Maritime Link Inc. (NSPML) and Nexans Norway AS, for design, supply and installation of a ±200 kV dc
                                 cable system across Cabot Strait between Newfoundland and Nova Scotia.  The report is intended to fulfill requirements
                                 of the Regulatory Approval granted in December 2013 by the Nova Scotia Utility and Review Board (UARB).
                                 —The 500 MW dc transmission system applies symmetrical bi-pole Voltage Source Converters.  ±200 kV overhead
                                 lines run between converters and the cable termination compounds.  The return path between converters is comprised
                                 of overhead lines on land and sea electrode systems at remote landfalls.  Converters will be provided by ABB, who also
                                 have responsibility for providing the transition compounds.
                                 —Figures 2 and 3 [Included in Exhibit N-1 in Matter Number M06865], identify the approximate submarine and land cable lengths,
                                 as well as where they will be manufactured – one power submarine cable at Nexans' factory in Halden, Norway and one at
                                 their joint venture NVC factory at Futtsu, Japan.  The land power cables will be manufactured in Halden.  Optical fibres are
                                 to be integrated into the underwater cables for about five km at each end for continuous temperature profiling in areas that
                                 are expected to be thermally limiting.  Fibre optic cables will be made at Nexans' Rognan, Norway factory.
                                 —A feature of the project is installation of submarine cables in horizontal directionally drilled (HDD) conduits for the
                                 approaches to landfalls.  The main purposes are to provide protection from ice floes, to reduce environmental impact
                                 compared to open trenching through the inter-tidal zone and to expedite the cable landing process.  The two conduits
                                 at each landing are anticipated to be 1100 m long at Point Aconi and and 600 m long at Cape Ray respectively, as shown
                                 in Figures 4 and 5 [Included in Exhibit N-1 in Matter Number M06865].  Although provision of the HDD conduits is not within the
                                 scope of E11-18, Nexans has responsibility for safely pulling the cables through them.
                                 —The contract requires completion of cable system commissioning tests in August 2017 and commissioning of the
                                 complete Maritime Link on October 1, 2017.  Converter tests with ±200 kV cable connections are planned in the interim.
                                                                                           References:
                                        •  Matter Number M06929 – NSPML - Maritime Link 2015 Q2 Quarterly Report - June 15, 2015
                                        •  Matter Number M06865 – NSPML - Maritime Link (Cabot Strait) Submarine Cable Report - April 30, 2015
                                               Design, Supply and Installation of ±200 kV DC Submarine Cable System [Exhibit N-1 in Matter Number M06865]
                                        •  Matter Number M06821 – NSPML - Maritime Link 2015 Q1 Quarterly Report - April 15, 2015
                                        •  Matter Number M06592 – NSPML - Maritime Link 2014 Q4 Quarterly Report - December 15, 2014
                                        •  Matter Number M06477 – NSPML - Maritime Link 2014 Q3 Quarterly Report - October 15, 2014
                                        •  Matter Number M06280 – NSPML - Maritime Link - 2013 Affiliate Code of Conduct Annual Report - June 13, 2014
                                        •  Matter Number M06279 – NSPML - Maritime Link 2014 Q2 Quarterly Report - June 13, 2014
                                        •  Matter Number M06191 – NSPML - Maritime Link 2014 Q1 Quarterly Report - April 15, 2014
                                        •  Matter Number M06024 – NSPML - Maritime Link 2013 Q4 Quarterly Report - December 13, 2013
                                        •  Matter Number M05419 – NSPML - Application for approval of the Maritime Link Project... - January 28, 2013
                                        •  Matter Number M05419 – NSP Maritime Link Incorporated (Re), 2013 NSUARB 154 (CanLII)    July 22, 2013
                                               §6.4.2  Submarine (underwater) and Land Cables
                                        •  Matter Number M05419 – NSP Maritime Link Incorporated (Re), 2013 NSUARB 242 (CanLII)    November 29, 2013
                                               §5.2  What should be the reporting requirements for NSPML during the course of the Maritime Link (ML) Project?
                                                       The reporting requirements are set out in §7 of the ML Regulations.
                                        •  Maritime Link Joint Development Agreement - Summary of the Commercial Agreements [1636 pages] - Dec. 17, 2012
                                               The Maritime Link shall consist of facilities for converting and transmitting energy and capacity from
                                               Newfoundland and Labrador to Cape Breton Island, Nova Scotia.  It will be designed, engineered and
                                               constructed to have a capacity of 500 megawatts and an initial service life of 50 years... Emera shall
                                               pay the costs of, and own, the Maritime Link, and provide Nalcor with transmission capacity in the
                                               Maritime Link and the Nova Scotia transmission rights, in exchange for which Emera shall be entitled
                                               to receive the Nova Scotia BlockSee NOTE NSB below for a term of 35 years from first commercial power...
                                               Each Party hereby agrees to each of the other Parties making this Agreement public at any time...
                                                        * NOTE NSB: The phrase "Nova Scotia Block" occurs 201 times in this Summary of the Commercial Agreements.

   •  M06862    NSPI - Affiliate Code of Conduct Report for 2014 [269 pages] - April 30, 2015
                                 Report for 2014 [Exhibit N-1 in Matter Number M06862 - 269 pages]

   •  M06858    NSPI - 2015 Load Forecast Report (10 Year Energy and Demand Forecast)- April 30, 2015
                                 This is NS Power's 2015 Load Forecast Report – as required by section 3.3.1.2 of the Nova Scotia
                                 Wholesale Electricity Market Rules, which states: The Nova Scotia Power System Operator (NSPSO)
                                 shall file with the Board its ten year energy and demand forecast by the end of April each year for the
                                 ten year period beginning in the following January.

   •  M06856    NSPI - 2014 Short Run Marginal Cost (SRMC) to Rates Report - April 30, 2015
                                 ...Changes in actual short-run marginal costs (SRMCs) are subject to dynamics different from those of unit
                                 revenues.  In the long-run, when the costs of all factors of production are variable, a positive correlation
                                 between marginal costs and average costs is expected, and a positive correlation between marginal costs
                                 and unit revenues results.  However, in the short run, such as on an annual basis, there can be significant
                                 departures in actual marginal costs from actual average costs or actual revenues... In summary, the
                                 relationship between average-cost-based rates and SRMC is not direct.  Both unit revenues and SRMC can
                                 fluctuate from average costs; each for different reasons.  The dynamics of these interactions can be complex
                                 and can produce diverse SRMC results on an annual basis...
                                 ...NS Power follows an economic dispatch order (pattern) in hourly operation of its generation fleet subject
                                 to annual environmental constraints of sulphur dioxide (SO2), nitrogen oxide (NOx) and mercury emissions.
                                 "Economic dispatch order" is defined in the EPACT 2005 as "The operation of generation facilities to produce
                                 energy at the lowest cost to reliably serve consumers, recognizing any operational limits of generation and
                                 transmission facilities" [Footnote 7 in Exhibit N-1 in Matter Number M06856].  In practice, it is a balancing act among
                                 a variety of objectives such as contractual obligations, regulatory and environmental constraints, scheduling
                                 commitments, and reliability practices.  The economic dispatch order can also be thought of as a constrained
                                 cost-minimization exercise.  The 2014 environmental requirements had an effect on generation dispatch
                                 decisions during the year...

   •  M06853    NSPI - 2014 Relay Testing Report - April 29, 2015
                                 —Relays are electromechanical devices installed in substations to protect equipment and devices from faults
                                 on the transmission and distribution system, and provide isolation capabilities to improve reliability to all electric
                                 utility customers.  Relay testing tests the calibration of these devices to ensure they are properly calibrated.
                                 This report [Exhibit N-1 in Matter Number M06853] shows the number of relays tested, test results, associated costs
                                 of the 2014 relay test program, and commentary regarding the number of relays tested year over year...
                                 —The 2014 Electromechanical Relay Test Program involved the testing of protective relays on the 138kV and
                                 69 kV transmission system.  These tests were completed by the System Maintenance Department at NS Power.
                                 —In 2014, 333 relays were tested in 14 substations across the Province.
                                 The results of the testing are summarized as follows:
                                                • Replacement or repair due to serious functional failures - 2 (0.6%)
                                                • Recalibration - 25 (7.5%)
                                                • Physical Maintenance - 0
                                                • No Action Required - 308 (91.9%)
                                 —The total cost associated with the testing of relays in 2014 was approximately $112,000.
                                 This cost is comprised of technician labour, administrative overheads and transportation costs...
                                 —In 2012, NS Power tested 73 relays.  In 2013, NS Power tested 316 relays; and in 2014, 333 relays.
                                 Prior to 2013, testing of relays was conducted every six years based on the relay installation date.
                                 Six years from the date that the relay was installed it was tested.  Therefore, relay testing numbers
                                 from year to year would depend on the number of relays installed each year...
                                 —Starting in 2013, as part of NS Power's ongoing effort to improve the efficiency of how its maintenance
                                 program is carried out, NS Power began proactively testing all relays installed in a substation when one relay
                                 in the same substation became due for testing...

   •  M06844    NSPI - Upgrade Transmission Lines L6511, L7019 Thermal Rating - Maritime Link-Related Work - $3,957,530 - April 24, 2015
                                              NSPI 138kV transmission line L-6511 between 50N-Trenton and 4C-Lochaber Road (Antigonish)
                                              NSPI 230kV transmission line L-7019 between 67N-Onslow and 91N-Dalhousie Mountain (Pictou County)
                                 This project - Capital Item CI 45066 - is being undertaken to eliminate thermal overload constraints on transmission
                                 Line L-6511 and Line L-7019 due to increased transmission loads that are anticipated will occur after the Maritime Link
                                 becomes operational.  To take advantage of line outage opportunities scheduled for other purposes, NS Power plans
                                 to begin construction for this project in early July 2015.  Construction is anticipated to continue from July through to
                                 November.  This proposal is submitted to the Board with the understanding that NS Power's shareholders bear the risk
                                 that the Board may require changes to the project or decline to approve the project in whole or in part.  NS Power is not
                                 seeking inclusion into rate base, at this time, of any of the costs associated with this work...

   •  M06835    NSPI - Accounting Policy and Procedure Manual dated March 31,2015 - P-111.6 - April 15, 2015
                                 Please find attached NS Power's Accounting Policies and Procedures provided for the Board's information only.
                                 All policies were in place at December 31, 2014, with the exception of Accounting Policy 5900 - Income Taxes.
                                 An amended Accounting Policy 5900 was approved by the Board on March 9, 2015 - Matter No. M06697.
                                 The recently amended and approved Accounting Policy 5900 has been included in the
                                 attached Accounting Policy and Procedures Manual.

   •  M06828    NSPI - Annual and Regulated Financial Statements - 2014 - April 15, 2015
                                 [Exhibit N-1 in Matter Number M06828] (9.0 megabytes, 391 pages)
                                 The Utility and Review Board's letter dated August 6, 2014, regarding NS Power's Annual Financial Statement filings,
                                 directed that the following reports be included with its annual filing:
                                 (a) NS Power Regulated financial statements & other UARB financial statement filings (See Attachments 1, 2, 3, 4 and 5)
                                 (b) NS Power Audited Financial statements (See Attachment 6)
                                 (c) NS Power Management Discussion & Analysis (See Attachment 7)
                                 (d) NS Power Management Information Circular (See Attachment 8)
                                 (e) NS Power Annual Information Form (See Attachment 9)
                                 (f) Emera Annual Report (See Attachment 10)
                                 Enclosed herein are copies of each of the documents referenced in (a) to (f) above.
                                 — Nova Scotia Power Inc. (NSPI) was created in 1992 through the privatization of the crown corporation
                                 Nova Scotia Power Corporation.  NSPI is a fully integrated regulated electric utility and is the primary electricity
                                 supplier in Nova Scotia, Canada.  NSPI has $4.3 billion of assets and provides electricity generation, transmission
                                 and distribution services to approximately 504,000 customers.  The Company owns 2,483 MW of generating capacity,
                                 of which approximately 50% is coal-fired; natural gas and/or oil comprise another 28% of capacity;
                                 hydro and wind total 19% and biomass-fuelled generation of 3%.
                                 — NSPI's rate base includes regulated assets and liabilities, materials and supplies and working capital.
                                 The net utility plant in service consists of the utility plant at its original cost less accumulated depreciation.
                                 — NSPI is regulated under a cost of service model, with rates set to recover prudently incurred costs of providing
                                 electricity service to customers, and provide an appropriate return to investors.  NSPI's regulated return on equity (ROE)
                                 range for 2011 was 9.1% to 9.6%, based on an actual average regulated common equity component of up to 40% of
                                 actual average regulated capitalization.  The 2012 General Rate Application (GRA) settlement adjusted the 2012
                                 targeted ROE range to 9.1% to 9.5% and the 2013 GRA decision reduced NSPI's targeted ROE range for 2013 and
                                 2014 to 8.75% to 9.25% for 2013 and 2014.  NSPI's targeted ROE range remains at 8.75% to 9.25% for 2015.
                                 — NSPI had 1,713 employees on December 31, 2014, approximately 48% of whom are unionized.

                                        Maritime Link across Cabot Strait       500 MW        670 000 horsepower
   •  M06821    NSPML - Nova Scotia Power Maritime Link Inc. - NSPML 2015 Q1 Quarterly Report - April 15, 2015
                                 — This [Exhibit N-1 in Matter Number M06821] is the Q1 2015 Quarterly Report for the Maritime Link as directed by the UARB.
                                 The Project remains on schedule with commissioning and commencement of operations scheduled for Q4 2017.
                                 — In this period, the Transmission Line Construction contract was signed in March 2015 with Abengoa S.A.
                                 This is the third largest contract of the project.  In total, about $1 billion worth of contracts have now been awarded...
                                 — NSP Maritime Link Inc. (NSPML) is an indirect wholly-owned subsidiary of Emera Inc., an energy and
                                 services company headquartered in Halifax, Nova Scotia.  Nova Scotia Power Inc. is an affiliate of NSPML.
                                                                                           References:
                                        •  Matter Number M06929 – NSPML - Maritime Link 2015 Q2 Quarterly Report - June 15, 2015
                                        •  Matter Number M06821 – NSPML - Maritime Link 2015 Q1 Quarterly Report - April 15, 2015
                                        •  Matter Number M06592 – NSPML - Maritime Link 2014 Q4 Quarterly Report - December 15, 2014
                                        •  Matter Number M06477 – NSPML - Maritime Link 2014 Q3 Quarterly Report - October 15, 2014
                                        •  Matter Number M06280 – NSPML - Maritime Link - 2013 Affiliate Code of Conduct Annual Report - June 13, 2014
                                        •  Matter Number M06279 – NSPML - Maritime Link 2014 Q2 Quarterly Report - June 13, 2014
                                        •  Matter Number M06191 – NSPML - Maritime Link 2014 Q1 Quarterly Report - April 15, 2014
                                        •  Matter Number M06024 – NSPML - Maritime Link 2013 Q4 Quarterly Report - December 13, 2013
                                        •  Matter Number M05419 – NSPML - Application for approval of the Maritime Link Project... - January 28, 2013
                                        •  Matter Number M05419 – NSP Maritime Link Incorporated (Re), 2013 NSUARB 154 (CanLII)    July 22, 2013
                                               §6.4.2  Submarine (underwater) and Land Cables
                                        •  Matter Number M05419 – NSP Maritime Link Incorporated (Re), 2013 NSUARB 242 (CanLII)    November 29, 2013
                                               §5.2  What should be the reporting requirements for NSPML during the course of the Maritime Link (ML) Project?
                                                       The reporting requirements are set out in §7 of the ML Regulations.
                                        •  Maritime Link Joint Development Agreement - Summary of the Commercial Agreements [1636 pages] - Dec. 17, 2012
                                               The Maritime Link shall consist of facilities for converting and transmitting energy and capacity from
                                               Newfoundland and Labrador to Cape Breton Island, Nova Scotia.  It will be designed, engineered and
                                               constructed to have a capacity of 500 megawatts and an initial service life of 50 years...

   •  M06806    NSPI WO - Brier Island Crossing (Digby County) - $2,581,168 - Authorization to Overspend (ATO) $369,095 - March 31, 2015
                                 This project will replace failed and deteriorated underwater power cables crossing the waters of Grand Passage
                                 from Long Island to Brier Island, Digby County, Nova Scotia.  In March 2010, one of the existing cables supplying
                                 the 197 customers on Brier Island failed.  The replacement of the failed cable and the remaining two cables will
                                 provide a reliable three phase supply for the customers of Brier Island.  Why do this project now?  A dive inspection
                                 of the remaining two phases serving Brier Island indicated that they are in a deteriorated state and are subject to
                                 failure.  The cable that failed and the two remaining phases were installed in the same year.  Currently, a special
                                 transformer configuration has allowed the company to convert the two phases to three phases to supply our three
                                 phase customers.  Should another cable fail however, NSPI will be unable to supply the three phase load by the
                                 remaining cable.  Why do this project this way?  The alternative to replacing the submarine cables is to construct
                                 a new overhead crossing.  This alternative would require a public consultation process, permitting and the securing
                                 of easements.  Based on previous experience, these activities could delay the commencement of construction
                                 by 14-16 months.  Any significant delay puts the reliability of the supply to Brier Island at risk.  For the option
                                 presented in this application, the necessary permits and easements are in place for the work to begin.
                                 An outside contractor will be performing the labour associated with this project.

   •  M06805    NSPI WO - ATO- Sacrificial Anode Installation Program Phase 1 - $815,277 - March 31, 2015
                                 Based on recent transmission line inspections, the age of NS Power infrastructure and the corrosion rate
                                 of steel once galvanization is breached, sacrificial anodes have been recommended by the Transmission
                                 and Distribution (T&D) Engineering group and have been proven effective in other jurisdictions to protect steel
                                 transmission structure assets and slow the rate of corrosion.  Due to the age of NS Power steel transmission
                                 structure assets, there are many steel structures with galvanization that is at or near the end of the anticipated
                                 life.  The cathodic protection provided by the installation of sacrificial anodes will effectively extend the life of the
                                 steel structure.  Once the galvanization is ineffective, the installation of sacrificial anodes protects the existing
                                 assets by deferring or preventing further deterioration.  Transmission inspections completed throughout 2014
                                 identified more advanced corrosion on transmission steel towers than originally anticipated in the ACE 2014
                                 filing of this Capital Item (CI).  This led to an increase in anode installations from 20 towers to 55 towers.

   •  M06804    NSPI - HYD (St. Margaret's Bay Hydroelectric System) - Mill Lake Unit #2 Refurbishment - $902,930 - March 31, 2015
                                              Authorization to Overspend (ATO)
                                 This project is to refurbish Mill Lake Unit 2 in order to return it to service.  The Mill Lake units have been out
                                 of service since 2008 due to penstock and scroll case integrity.  Unit 2 requires replacement of the penstock
                                 (last 30m), butterfly valve and refurbishment of the scroll case.  Due to investments made into the Coon Pond
                                 pipeline and intake structures, a potential 2 GWh of annual energy production for the Mill Lake Generating Station
                                 has been created.  Studies show that there is sufficient water to run both Mill Lake units for 16 hours per day.
                                 Enhancements to the water retaining and conveyance at Mill Lake along with the recent completion of the
                                 Coon Pond Dam upgrades and pipeline replacement require this project to be completed now.
                                 This is the last portion of this hydro system required to return this generating station to service.

   •  M06803    NSPI - ATO - L7009 Lidar Upgrades & Maintenance - $3,929,423 - March 31, 2015
                                 This transmission circuit is almost 40 years old and issues related to ground clearance from energized
                                 conductors have been identified.  The conductor will be cut and re-sagged to increase clearances and
                                 a number of structures will be replaced with taller poles as required to meet Canadian Standards Association
                                 clearance requirements.  This work will involve replacing 130 structures.

   •  M06802    NSPI WO - Hydro Asset Management Implementation - $590,884 - March 31, 2015
                                 NS Power's hydro system is a highly dispersed set of generating units – 55 generating units located at 37 power-
                                 houses on 17 different river systems.  With the successful implementation of the Thermal Asset Management Program,
                                 NS Power is now in a position to effectively apply similar asset management methodology to Hydro.

   •  M06801    NSPI - Fuel Nozzle Rotable Kit (for LM6000 combustion turbines) - $293,315 - March 31, 2015
                                 This project is for the purchase of a fuel nozzle rotable kit for use in LM6000 combustion turbines.  Fuel nozzles
                                 enable the appropriate fuel air mix to be delivered to the combustion chamber of a combustion turbine.  The fuel
                                 nozzles wear over time as a function of operating hours and load.  The refurbishment interval for fuel nozzles
                                 can be different than that of the major outage activities.  Furthermore, nozzle replacement can be conducted in
                                 24-48 hours and aligned with other minor maintenance activities.  Fuel nozzles wear as a function of service hours.
                                 As the nozzles deteriorate, there is a reduction in the quality and symmetry of firing and heating within the
                                 combustion chamber.  The effect is localized heating, uneven heat distribution within the combustion chamber,
                                 negative effects on combustion chamber condition, uneven heat distribution to the High Pressure Turbine.
                                 Fuel nozzle spares provide for opportune replacement of the nozzles to support optimum operating efficiency
                                 and reduce the risk of unit unavailability or a derating of a unit between major outage intervals.

   •  M06800    NSPI WO - HYD (Black River Hydro System, Kings County) - White Rock Pipeline Replacement - $685,805 - March 31, 2015
                                 This project will replace the existing wood stave pipeline with a modern concrete and fiberglass reinforced polymer
                                 (FRP) pipeline.  Why do this project?  The wood staves in the existing pipeline have deteriorated to the point of being
                                 rotted through in some sections.  This deterioration is causing significant head loss, leaks, as well as stability concerns
                                 for this hydroelectric development.  Why do this project now?  The condition of the pipeline is worsening and restrictions
                                 on using creosote as a preservative has led to increased deterioration of the pipeline.  The pipeline continues to deteriorate
                                 and with ice buildup during winter months the risk of pipeline failure continues to increase.  This project mitigates this risk
                                 with a self-supporting pipeline constructed of concrete and FRP that will also see efficiency gains for the generating station.
                                 Why do this project this way?  Pipeline replacement is the only option for long term reliable service as the pipe has reached
                                 a point of deterioration where patching / repairs is not feasible.  Replacing the pipeline with FRP provides efficiency gains
                                 and is also necessary as replacing with a wood-stave pipeline is not good practice.




Nova Scotia Utility and Review Board
Statement of Mandate – 2014-2015

The link in Footnote 1 (at the bottom of page 3) does not work.
Here's  the  corrected  link  (works  properly  in  all  browsers):
A copy of the summary strategic plan can be found on the Board's web site at
http://nsuarb.novascotia.ca/sites/default/files/PDFs/195115_strategic_plan_2011.pdf

Statement of Mandate – 2013-2014

Statement of Mandate – 2012-2013

Statement of Mandate – 2011-2012

Statement of Mandate – 2010-2011



 
M00000-M00999    M01000-M01999    M02000-M02999    M03000-M03999    M04000-M04999
M05000-M05499    M05500-M05999    M06000-M06199    M06200-M06399
M06400-M06599    M06600-M06799    M06800-M06999    M07000-M07199


In the “Electricity” section of the UARB website
Matter Numbers M06600 to M06799

      Matter
    Number


   •  M06799
   •  M06798
   •  M06797   
   •  M06796

   •  M06793    Department of Energy (COMFIT) - Request to the Board to approve a Standard Form Power Purchase Agreement
                        for use in the Developmental Tidal Array Feed-In Tariff Program - March 31, 2015              Hearing Notice
                                 —Minister of Energy Developmental Tidal Array FIT PPA Submission [Exhibit C-1 in Matter Number M06793] (261 pages)
                                 —Under Section 32 (1) of the Renewable Electricity Regulations (Regulations), the Minister of Energy (Minister) is
                                 required to prepare, in consultation with Nova Scotia Power Inc. (NSPI), a Power Purchase Agreement (PPA) to be used
                                 for the feed-in tariff program.  This PPA must also be approved by the Nova Scotia Utility and Review Board (Board).
                                 Although a PPA has already been prepared and approved for the Community Feed-In Tariff (COMFIT) program,
                                 the Minister does not believe that the COMFIT PPA fully suits the needs anticipated
                                 for a Developmental Tidal Array FIT PPA (Tidal FIT PPA).
                                 —Unlike the COMFIT PPA, a Tidal FIT PPA needs to anticipate both transmission and distribution grid connections.
                                 A Tidal FIT PPA also needs to address the fact that instream tidal is still a new, developing technology.  With the
                                 exception of COMFIT tidal, the remainder of the COMFIT program is proven technology entering into a
                                 straightforward commercial agreement.
                                 —Section 32 (1A) of the Regulations permit separate PPAs to be prepared and approved for different classes of generation
                                 facilities.  This document provides a summary of the process used by the Minister to draft a Tidal FIT PPA.  This process
                                 engaged key stakeholders through the development of the Tidal FIT PPA with the objective of achieving a consensus on
                                 final terms for the PPA that addressed as many items of concern of the key stakeholders while meeting the requirements
                                 of the Developmental Tidal Array FIT program and protecting the interests of NSPI's ratepayers.  Tidal turbines may be
                                 deployed as early as June 2015
and the Department of Energy (Department) hopes that efforts to minimize disputes by
                                 trying to achieve a consensus will facilitate receiving an approval from the Board by this date... [boldface emphasis added]
                                 —The proposed Tidal FIT PPA is intended to accommodate tidal generators connecting through the FORCE facilities
                                 (subject to the Control Agreement between NSPI and FORCE), or directly with NSPI's facilities...

                                      References:
•  Tidal power potentially worth billions to Maritimes, report finds  CBC News, April 24, 2015
•  Nova Scotia tidal energy industry could create 22 000 jobs – study  The Hants Journal, Windsor, April 23, 2015
•  Costly tidal power could also bring $1.1b boost  Chronicle-Herald, Halifax, April 23, 2015
•  OpenHydro gets $6.3m from Ottawa for Fundy tidal project  Chronicle-Herald, Halifax, April 15, 2015
•  Feds announce $6.3 million for tidal power project  The Citizen Record, Amherst, April 15, 2015
•  Parrsboro tidal turbines set to roll  Chronicle-Herald, Halifax, April 14, 2015
•  Small-scale power generation could shrink electricity costs  Chronicle-Herald, Halifax, April 3, 2015
•  Tidal research in Minas Passage uses radar tracking  Chronicle-Herald, Halifax, March 16, 2015
•  Halcyon's Scots Bay tidal project still a go  Chronicle-Herald, Halifax, March 9, 2015
•  Tidal firms get nod for Nova Scotia tariff  Chronicle-Herald, Halifax, December 19, 2014
•  Awards support tidal industry development  The Citizen Record, Amherst, December 19, 2014
•  Fundy Tidal inks deal to boost energy plans  Chronicle-Herald, November 21, 2014
•  Tidal technology gets scrutiny  Chronicle-Herald, Halifax, November 6, 2014
•  Parrsboro, Hantsport and Digby all vying for share of Bay of Fundy energy bonanza  The Citizen Record, Nov. 5, 2014
•  Nova Scotia in talks with Irish firm to expand tidal research centre  The Citizen Record, Amherst, November 4, 2014
•  Bay of Fundy power potential has energy companies lining up  CBC News, November 4, 2014
•  Installation of undersea power cables for tidal turbines complete  Chronicle-Herald, Halifax, October 31, 2014
•  Stakeholders ponder Fundy's future  Chronicle-Herald, Halifax, October 31, 2014
•  Cables laid successfully at tidal power site  The Citizen Record, Amherst, October 30, 2014
•  Asian firm sets Fundy test - Company to install turbine near Parrsboro  Chronicle-Herald, Halifax, October 29, 2014
•  Bay of Fundy tidal project draws closer to power generation  Chronicle-Herald, Halifax, October 20, 2014
•  Tidal power cables installed in Minas Passage  The Citizen Record, Amherst, October 20, 2014
•  Parrsboro looking at tidal power agreement with Digby, Hantsport  The Hants Journal, Windsor, September 29, 2014
•  Cable work to be “final piece” in tidal project  Chronicle-Herald, Halifax, September 10, 2014
•  Bay of Fundy FORCE study looking at tidal power turbine potential  CBC News, September 2, 2014
•  N.S., U.K. offer first joint tidal project request  Chronicle-Herald, Halifax, August 14, 2014
•  Parrsboro needs to get tidal ready  The Citizen Record, Amherst, June 9, 2014
•  Energy minister visits FORCE site  The Citizen Record, Amherst, June 4, 2014
•  Province commits $4 million to tidal power  The Citizen Record, Amherst, March 28, 2014
•  Nova Scotia and United Kingdom agree to work together on tidal energy research  The Citizen Record, March 4, 2014
•  Nova-Scotia and U.K. collaborate on tidal industry development  The Citizen Record, Amherst, March 4, 2014
•  Tidal energy could generate billions for Atlantic economy  CBC News, November 20, 2013


   •  M06792 NSPI - Power Line Technician Staffing Levels & Reliability of Service at Nova Scotia Power 2015 Report - March 31, 2015
                                 This report provides information concerning:
                                        •  Power Line Technician (PLT) staffing levels.
                                        •  2009-2014 outage complaint supervisor call-backs.
                                        •  2009-2014 customer survey results concerning outage response.
                                        •  2009-2014 service reliability statistics.
                                 NOTE: Five Information Requests (IRs) to NSPI, dated June 30, 2015 [Exhibit IRs in Matter Number M06792]
                                               Responses due: Tuesday, July 14, 2015

   •  M06789    NSP Maritime Link Inc. - Financial Statements, 2013 and 2014 - March 27, 2015
                                 — This 20-page document [Exhibit N-1 in Matter Number M06789] contains the consolidated financial statements
                                 of NSP Maritime Link Inc. which comprise the consolidated balance sheets as at December 31, 2014 and 2013,
                                 and the consolidated statements of income, cash flows and changes in equity for the years then ended, and
                                 a summary of significant accounting policies and other explanatory information...
                                 — NSP Maritime Link Inc. (NSPML) is an indirect wholly-owned subsidiary of Emera Inc., an energy and
                                 services company headquartered in Halifax, Nova Scotia.  Nova Scotia Power Inc. is an affiliate of NSPML
                                 (both are wholly-owned subsidiaries of Emera Inc.).  NSPML is a public utility by virtue of the Maritime Link Act
                                 and is subject to regulation under the Maritime Link Act and the Public Utilities Act by the Nova Scotia Utility
                                 and Review Board (UARB).  NSPML was formed to develop the Maritime Link Project (the Project) as per the
                                 terms set out in the commercial agreements between NSPML and Nalcor Energy.  As part of the agreements,
                                 NSPML will design, engineer, construct and commission the Project, which is a $1 560 000 000 electric
                                 transmission project that involves installing two 170-km underwater ±250 000-volt direct current transmission
                                 cables under Cabot Strait, and overhead transmission on Newfoundland Island and on Cape Breton Island. 
                                 The Maritime Link Financing Trust (MLFT) is a special purpose funding company created for the purpose of
                                 obtaining financing for the Project.  On November 29, 2013, the UARB gave its final approval of the Project
                                 which is expected to be complete in 2017.
                                 — NSPML's accounting policies are subject to examination and approval of the UARB.  All dollar amounts are
                                 presented in Canadian dollars.  Monetary assets and liabilities denominated in foreign currencies are converted
                                 to Canadian dollars at the exchange rates prevailing at the balance sheet date.  Construction work-in-progress
                                 is recorded at original cost, including allowance for funds used during construction (AFDUC) and the amortization
                                 of deferred financing costs.  Depreciation will commence once the asset goes into service, which is expected to be
                                 in late 2017, and is expected to be depreciated over 35 years. 
                                 — On April 23, 2014, MLFT completed its offering of $1.3 billion aggregate principal amount of 3.5 percent
                                 amortizing bonds at a price of $999.57 per $1 000 principal amount of bonds for aggregate gross proceeds of
                                 approximately $1.3 billion.  The bonds will be repaid via $20 million semi-annual payments beginning Dec. 1, 2020,
                                 and ending December 1, 2052.  The bonds are guaranteed by the Government of Canada under the
                                 Federal Loan Guarantee.  The net proceeds are being used to fund the construction of the Maritime Link Project.
                                 — On March 6, 2015, NSPML executed a Transmission Line Construction contract valued at about $200 million. 
                                 The scope of the work is scheduled to be completed over the next two years.  [emphasis added]

   •  M06760    Canso Electric Light Commission - 2015 Rate Application - March 13, 2015
                                               Municipality of District of Guysborough on behalf of Canso Electric Light Utility
                                 The Canso Electric Light Utility (the Utility) hereby applies to the Utility and Review Board for an amendment
                                 to its Schedule of Rates.  The Utility has recorded net losses since its previous owner, the Town of Canso,
                                 was dissolved (on July 1, 2012) and administration was transferred to the Municipality of the District
                                 of Guysborough.  The Utility currently is operated and maintained through a service agreement with
                                 Emerea Utility Services.  The Municipality has actively pursued a sale of the Utility – so far without
                                 success – and feels that it needs to establish a rate structure that will place the Utility in a sustainable
                                 position.  To this end, a rate study has been commissioned that will provide direction to improve the
                                 financial health.  The rate application will move the Utility's rates closer to comparable customer levels
                                 within the Nova Scotia Power (NSP) franchise area.  NSP is the most likely purchaser of the Utility.
                                 It is proposed that the Utility seek approval for increases to its Domestic and Small Industrial classes
                                 of 10% and 7.5% respectively.  The Domestic requirement is recovered by increasing the energy charge
                                 only by 11.6%, while the Small Industrial increase is applied across-the-board.  Canso Electric Light Utility's
                                 Application is enclosed... Present and proposed rates are attached as Appendices A and B respectively...
                                                                                          Reference:
                                        •  Town of Canso Electrical Utility Rate and Regulation Review [33 pages] - November 15, 2010

   •  M06756    NSPI - Filing re North American Electric Reliability Corporation - Fourth Quarter Q4 2013 Application - March 9, 2015
                       Correction to 2013 Q4 NERC Application [Exhibits N-1 and N-1 (i) in Matter Number M06756] - Cross Reference with M06132
                                 Nova Scotia Power Incorporated (NSPI) wishes to advise the Utility and Review Board of a correction required to
                                 its May 30, 2014 letter and the associated Attachment 1... Please refer to the enclosed revised Attachment 1 in the
                                 last paragraph of the document for the revision.  This revised Attachment 1 replaces the original Attachment 1
                                 included with NS Power's letter dated May 30, 2014.
                                 ...Footnote 12 of Table 1 states conditions under which it is acceptable to experience "Non-Consequential Load Loss".  Attachment 1 details the
                                 conditions under which such load loss is acceptable.  Nova Scotia Power relies on this Footnote (this was the intent of Footnote "b" in the previous
                                 versions of TPL-001 through TPL-004) to permit imports from New Brunswick into Nova Scotia above 100 MW.  Nova Scotia Power has previously
                                 filed documents with the Board to explain this practice.  These are provided in Attachment 2, Nova Scotia Intertie and Transmission Constraints Report,
                                 dated December 2013, previously filed in Matter Number 06042 and Nova Scotia Transmission Interconnection Import Issues, dated November, 2005.
                                 NERC has correctly applied this footnote to Category P1 events in Table 1, thereby permitting Non-Consequential Load Loss for loss of any Extra High
                                 Voltage (EHV, or 345kV) single generator, transmission circuit, transformer, shunt device or single pole of a DC line.  However it is not applied to
                                 Category P2 EHV events, such as bus section faults or internal breaker faults, even though the consequences would be the same... [emphasis added]

   •  M06743    NSPI - Nova Scotia Power System Operator (NSPSO) 2014 Wholesale Market Report - February 27, 2015
                                 — Since the NS Power electrical system is interconnected with the North American bulk power system, NS Power
                                 is required to comply with standards and codes as governed by the North American Electric Reliability Corporation
                                 (NERC) and the Northeast Power Coordinating Council (NPCC).  This obligation to comply extends to Market
                                 Participants and generators interconnected with the Nova Scotia Power grid. 
                                 Links to the applicable standards and codes are published on the OASIS website.
                                 — The Nova Scotia Wholesale Electricity Market was opened to competition effective February 1, 2007.
                                 At that time, the Nova Scotia Wholesale Electricity Market Rules, which define the rights and obligations
                                 of the Nova Scotia Power System Operator (NSPSO) and all Market Participants, also came into effect.
                                 This report on the operation of the Wholesale Electricity Market in 2014 provides information on thirteen
                                 areas as specified by the Nova Scotia Utility and Review Board in its letter dated March 10, 2008.
                                 This is the eighth Wholesale Market Report prepared by the NSPSO.
                                 The last report was filed with the UARB on March 3, 2014.
                                 — The triennial 5 year assessment of the Maritime Area as set out in Section 3.3.1.4 was completed by
                                 NB Power, the Maritime Electric Company Ltd., Northern Maine Independent System Administrator, Inc.,
                                 and the Nova Scotia Power System Operator (NSPSO) in accordance with the requirements of the
                                 Northeast Power Coordinating Council, Inc. (NPCC) Regional Reliability Directory #1 Appendix D.
                                 The report was posted on the NPCC site on January 29, 2015. 
                                 A link to this report is available on the OASIS site under Forecasts and Assessments.

The report itself is titled "NPCC - 2014 MARITIMES AREA - INTERIM
REVIEW  OF  RESOURCE  ADEQUACY".  The phrase "The triennial
5 year assessment of the Maritime Area" is a description of the report,
rather than  the  actual  title  of the report.  The file name of the report
is   "Maritimes  Interim  2014"   as    listed    under    NPCC - Library.
per email dated March 23, 2015, from Mark Peachy,
Manager, Capital Filings, Nova Scotia Power Inc.,


                                                                                          References:
                                        •  Matter Number M06743 – Nova Scotia Power System Operator (NSPSO) 2014 Wholesale Market Report
                                        •  Matter Number M06133 – Nova Scotia Power System Operator (NSPSO) 2013 Wholesale Market Report
                                        •  Matter Number M05565 – Nova Scotia Power System Operator (NSPSO) 2012 Wholesale Market Report
                                        •  Matter Number M04842 – Nova Scotia Power System Operator (NSPSO) 2011 Wholesale Market Report
                                        •  Matter Number M03959 – Nova Scotia Power System Operator (NSPSO) 2010 Wholesale Market Report
                                        •  Matter Number M02762 – Nova Scotia Power System Operator (NSPSO) 2009 Wholesale Market Report

Nova Scotia Power Incorporated
Open Access Transmission Tariff - 2014 Schedules
Regulation and Frequency Response Service is necessary to provide for
the continuous  balancing  of resources  (generation and interchange) with
load and for  maintaining  scheduled Interconnection  frequency  at 60 hertz.
Regulation and Frequency Response Service is accomplished by committing
on-line generation whose output is raised or lowered (predominantly through
the use of automatic generating control equipment) as  necessary  to  follow
the moment-by-moment  changes in load.  The  obligation  to  maintain this
balance between resources and load lies with the Transmission Provider...


History of Open Access Transmission Tariff (OATT) Reform

On April 24, 1996 the United States Federal Energy Regulatory
Commission (FERC or Commission) issued Order No. 888 which
required  public  utilities  to provide  open  access  transmission
service  on  a  basis  comparable  to the  transmission  service
they provide themselves.  Specifically, Order No. 888 required
all public utilities that own, control or operate facilities used for
transmitting   electric   energy   in  interstate  commerce  to  file
open access non-discriminatory transmission tariffs that contain
minimum  terms  and  conditions  of non-discriminatory service...

In a companion order the Commission issued Order No. 889 at the same
time  which  established  rules  governing  Open  Access  Same-time
Information System (OASIS)
and prescribing standards of conduct.

The United States Federal Energy Regulatory Commission (FERC)
has  no  authority  in  Canada  but  it  does  impose  a  reciprocity
rule;  if Canadian  firms  use  states'  OATTs  to export to the US
then, in  return,  they  must  also  make  OATTs  available  to
whomever  wishes  to  use  their  transmission  systems.

   •  M06740    Heritage Gas Limited - Amendments to Natural Gas Distribution Service Rules - March 4, 2015


•  M06738    NSPI - 2014 Annual FAM (Fuel Adjustment Mechanism) Report - March 2, 2015

NSPI Commentary 2014
Emissions Regulations

Nova Scotia Power (NSPI) is required to manage air emissions to annual fleet wide limits, as per
the NS Air Quality Regulations and the NS Greenhouse Gas (GHG) Emission Regulations.
NSPI has been fully compliant with legislated emission targets each year.


For 2014, the fleet-wide limit on air emissions for sulphur dioxide (SO2) was 72,500 tonnes per year.
The emissions of SO2 were within these limits for 2014 at 60,902 tonnes.  The SO2 annual emission
limit will remain at 72,500 tonnes in 2015.  But, from 2015 to the end of 2019 there will also be a
compliance limit total of 304,500 tonnes for SO2 emissions, which is equivalent to an annual
average limit of 60,900 tonnes.


The 2014 limit on annual emissions of mercury (Hg) was 65 kg.  NSPI continued the operation
of seven sorbent injection systems that were installed in 2009.  The mercury emissions were within
this limit in 2014 at 54.0 kg.  The 2015 emission limit for mercury will remain at 65 kg.  Under current
regulations, any NSPI emissions of Hg above 65 kg for 2010-2013 must be made up by 2020.


NSPI manages its actual air emissions (SO2 and to some extent mercury) by purchasing and
combusting specific quality fuels and procuring power from other sources (i.e., Imports and
Independent Power Producers), and by increasing the amount of rewneable generation.


The 2014 cap for annual emissions of nitrogen oxides (NOx) was 21,365 tonnes.  NSPI continued
the operation of the low NOx Combustion Firing Systems (LNCFS) on all Lingan units, Point Tupper
and Trenton 6.  These LNCFS additions represent the primary approach to reduce NOx emissions.
Emissions for 2014 were 16,902 tonnes.  The NOx annual emission limit will remain at 21,365 tonnes
in 2015.  But, from 2015 to the end of 2019 there will also be a compliance limit total of 96,140 tonnes
for NOx emissions, which is equivalent to an annual average limit of 19,228 tonnes.


The GHG emission limit for the three-year period of 2014-2016 has been set at 26.32 million tonnes
CO2eq.  This equates to an approximate target of 8.98 million tonnes in 2014, 8.80 million tonnes in
2015, and 8.54 million tonnes in 2016.  The 2014 emissions were 7,134,950 tonnes of CO2eq, well
below the 2014 target.  In addition, NSPI will be applying for GHG emission credit for 2014, related
to tranmission upgrades to support renewable generation.


In addition to these fleet-wide caps, each generating facility operates within an Industrial Operating
Approval which requires ground level ambient air quality to be maintained, plume visibility to be within
limits and, in some cases, specific emission standards to be met.  This is accomplished by maintaining
the plant equipment in good working order and operating the plant within the specified limits.


References:
•  Matter Number M06738 – Nova Scotia Power Inc. - 2014 Annual FAM (Fuel Adjustment Mechanism) Report
•  Matter Number M06142 – Nova Scotia Power Inc. - 2013 Annual FAM (Fuel Adjustment Mechanism) Report
•  Matter Number M05555 – Nova Scotia Power Inc. - 2012 Annual FAM (Fuel Adjustment Mechanism) Report
•  Matter Number M04865 – Nova Scotia Power Inc. - 2011 Annual FAM (Fuel Adjustment Mechanism) Report
•  Matter Number M03958 – Nova Scotia Power Inc. - 2010 Annual FAM (Fuel Adjustment Mechanism) Report
•  Matter Number M02791 – Nova Scotia Power Inc. - 2009 Annual FAM (Fuel Adjustment Mechanism) Report
•  Matter Number M01866 – Nova Scotia Power Inc. - Mercury Sorbent Cost Recovery – June 9, 2009             

•  Total System Emissions - NSPI All Generating Plants


Also see:

•  CO2eq Equivalent carbon dioxide  Wikipedia

• The Canadian Electricity Association (CEA) Mercury Program

• The Canadian Electricity Association (CEA) - Understanding Mercury

•  Multi-Technology, Mercury Abatement Program, Implementation
and Performance at Nova Scotia Power
  September 2010

• Technical Review of Mercury Technology Options for Canadian Utilities -
A Report to the Canadian Council of Ministers of the Environment
(CCME)  March 2005


• Canada-wide Standard for Mercury Emissions from Coal-fired Electric Power Generation Plants
– 2012 Progress Report
   May 2014
         — (page 22)   Nova Scotia has amended its provincial  Air  Quality  Regulations  to extend
achievement of the  65 kg  cap  to 2014 from 2010, with annual declining  emission  caps from 2010
to 2013.  In addition  the  province  has  established  a cap of  35 kg  in 2020.   The  annual  emission
allocations under provincial regulation for the years 2010 to 2020 are identified in the following tables...
             — (page 3)   Canada-wide:  In the  baseline  year of 2003,  2695 kg  of mercury were emitted
and there was a total of 3725 kg  of mercury in the amount of coal burned.  This represented a capture
rate of less than 28%.  In 2012, 826 kg of mercury were emitted and the total mercury contained in the
coal  burned  was  1868 kg  representing  a  capture  rate  of  56%.  Although  this  is  not  equal  to  the
Canada-wide Standards for Mercury Emissions from Coal-fired Electric Power Generation Plants (CWS)
goal of 60% capture, it does represent a nearly  70%  reduction in total emissions from 2003.  The 2010
emission caps were expected  to produce a  52-58%  reduction  in  total  emissions.  While the goal for
capture rate has not yet been achieved, absolute emissions have been reduced more than expected
through  a  combination  of  reduced  coal  consumption  and  emissions  abatement...


• U.S. Power Plant Emissions Report Reflects Industry's Transition to Cleaner Energy   Jul 31, 2012
Latest data on top 100 U.S. power producers show declining SO2, NOx and CO2 emissions...

   •  M06733    EfficiencyOne Application...Supply Agreement...EfficiencyOne and Nova Scotia Power Inc. - February 27, 2015
                                 – In the Matter of an Application by EfficiencyOne for Approval of a Supply Agreement for Electricity Efficiency
                                 and Conservation Activities between EfficiencyOne and Nova Scotia Power Inc. the establishment of a final
                                 agreement between the parties, and approval of a 2016-2018 Demand Side Management (DSM) Resource Plan
                                 – DECISION: The Board approves a DSM Plan for 2016-2018 in the aggregate amount of $102,150,000.
                                 Approved spending is $33,210,000 during 2016; $34,020,000 during 2017; and $34,920,000 in 2018.
                                 Findings and directives are summarized at paragraphs 138-148.
                                                                                           Reference:
                                        •  Matter Number M06733 – 2015 NSUARB 204  [66 pages] - UARB Decision - August 12, 2015

   •  M06732    NPCC - Northeast Power Coordinating Council - Q4 2014 Application - Regional Reliability Criteria - February 26, 2015
                                 — Since the NS Power electrical system is interconnected with the North American bulk power system, NS Power
                                 is required to comply with standards and codes as governed by the North American Electric Reliability Corporation
                                 (NERC) and the Northeast Power Coordinating Council (NPCC).  This obligation to comply extends to Market
                                 Participants and generators interconnected with the Nova Scotia Power grid. 
                                 Links to the applicable standards and codes are published on the OASIS website.
                                 — Fourth quarter 2014 Aplication of the Northeast Power Coordinating Council, Inc. for approval of Regional Reliability Criteria.
                                 The Northeast Power Coordinating Council, Inc. (NPCC) hereby submits to the Nova Scotia Utility and Review Board (NSUARB)
                                 an application for approval of the retirement of the NPCC Regional Reliability Criteria contained in Directory #3, Maintenance
                                 Criteria for Bulk Power System (BPS) Protection (Directory #3).  This quarterly filing covers the time period of October 1, 2014
                                 through December 31, 2014.  NPCC respectfully requests that, based on a vote of the NPCC Full Members on October 15, 2014,
                                 the Regional Reliability Criteria contained in Directory #3 be retired effective April 1, 2015 in the Province of Nova Scotia...
                                              These criteria shall apply to all protection of the NPCC bulk power system, including Type One special protection systems and protection
                                              required for the NPCC Automatic Underfrequency Load Shedding Program.  Automatic underfrequency load shedding protection systems
                                              and generator underfrequency tripping relays are not generally located at bulk power system stations; however, they have a direct effect on
                                              the operation of the bulk power system during major emergencies, and as such, they are subject to these criteria...
                                 ♦  See Memorandum of Understanding between Nova Scotia Power Inc. and the Northeast Power Coordinating Council, Inc.
                                                        and the North American Electric Reliability Corporation (signed May 11, 2010)
                                 ♦  Pursuant to the terms of the MOU with Nova Scotia Power Inc., enclosed is their recommendation to
                                                        the Nova Scotia Utility and Review Board supporting the adoption of NERC Reliability Standards
                                                        and NPCC Criteria in that province... (dated December 17, 2010)
                                 ♦  See Application by North American Electric Reliability Corporation for approval of its Reliability Standards,
                                                        and an application by Northeast Power Coordinating Council, Inc. for approval of its
                                                        Regional Reliability Criteria (UARB Order dated July 20, 2011)

   •  M06728    NERC - North American Electric Reliability Corporation - Q4 2014 - Application...Approval of Reliability Standards - February 23, 2015
                                 Some or all of NERC's Reliability Standards are mandatory in the Canadian provinces of Alberta, British Columbia, Manitoba,
                                 New Brunswick, Nova Scotia [boldface emphasis added], Ontario, Quebec, and Saskatchewan.
                                                                                           References:
                                        •  Matter Number M06890 – NERC - North American Electric Reliability Corporation - Q1 2015 - May 13, 2015
                                        •  Matter Number M06728 – NERC - North American Electric Reliability Corporation - Q4 2014 - February 23, 2015
                                        •  Matter Number M06545 – NERC - North American Electric Reliability Corporation - Q3 2014 - November 26, 2014
                                        •  Matter Number M06525 – NSPI - Onslow 345 kV Node Swap - November 14, 2014
                                        •  Matter Number M06427 – NERC - N.A. Electric Reliability Corporation - 2015 Business Plans etc. - Sep. 17, 2014
                                        •  Matter Number M06363 – NERC - North American Electric Reliability Corporation - Q2 2014 - August 15, 2014
                                        •  Matter Number M06294 – NSPI - Protection Risk Reduction 67N-Onslow 230kV - $2,870,285 - June 25, 2014
                                        •  Matter Number M06258 – NERC - North American Electric Reliability Corporation - Q1 2014 - May 20, 2014
                                        •  Matter Number M06132 – NERC - North American Electric Reliability Corporation - Q4 2013 - February 28, 2014
                                        •  Matter Number M06011 – NERC - North American Electric Reliability Corporation - Q3 2013 - November 26, 2013
                                        •  Matter Number M05944 – NERC - N.A. Electric Reliability Corporation - 2014 Business Plans etc. - Nov. 04, 2013
                                        •  Matter Number M05862 – NERC - North American Electric Reliability Corporation - Q2 2013 - August 30, 2013
                                        •  Matter Number M05713 – NERC - North American Electric Reliability Corporation - Q1 2013 - May 31, 2013
                                        •  Matter Number M04460 – NERC - First NERC Quarterly Application...Approval...Reliability Standards... - Sep. 06, 2011
                                        •  Matter Number M04025 – NSPI - Review...Reliability of Service at NSPI - April 04, 2011
                                        •  Matter Number M03815 – NSPI - Backup Control Centre - $3,222,066 - December 24, 2010
                                        •  Matter Number M03324 – NERC - NERC Reliability Standards; and NPCC Regional Reliability Criteria - June 29, 2010
                                        •  Matter Number M01989 – NSPI - CIP Standards Implementation - $422,923 - July 22, 2009
                                        •  Matter Number M01871 – NSPI - Report to the UARB Regarding NSPI/NB Power Interconnection - June 30, 2009

   •  M06699    NSPI - Regulation 3.6 - 2015 Net Metering Report - January 30, 2015
                                 — In the Utility and Review Board's Order dated April 14, 2011 regarding NS Power's application to amend
                                 Regulation 3.6 - Net Metering, the Board stated: NSPI is to file an annual report with the Board by January 31st
                                 each year which provides a listing and details regarding each net metered customer generator connected to each
                                 distribution feeder...

                                 — This [pages 3-8 of Exhibit N-1 in Matter Number M06699] is NS Power's 2015 Net Metering Report
                                 which includes all net metering customers as of December 31, 2014, and provides the source,
                                 size, location, feeder and application of aggregation for each customer... There are a total
                                 of 192 installed net metering generation units with 13 customers applying aggregation.
                                 The total rated generator capacity of all subscribed customers is approximately 1,421.7 kilowatts (1906 horsepower)...

   •  M06697    NSPI - Request for Approval of Amendments to Accounting Policy 5900 - Income Taxes - February 4, 2015
                                 Nova Scotia Power Inc. is subject to federal and provincial income taxes at prescribed rates applied to taxable income.

   •  M06696    NSPI - ATO - Distribution Routines - $23,536,221 - ACE $22,334,401 - ATO $1,201,821 - January 30, 2015
                                               UARB Letter to NSPI - Assigning Matter Numbers - Q4 2014  February 4, 2015

   •  M06695    NSPI - ATO - Transmission Routines - $5,352,171 - ACE $4,677,539 - ATO $674,633 - January 30, 2015
                                               UARB Letter to NSPI - Assigning Matter Numbers - Q4 2014  February 4, 2015

   •  M06694    NSPI - HYD - St. Margaret's Bay - Sandy Lake Fish Passage - $3,926,079 - January 30, 2015
                                               UARB Letter to NSPI - Assigning Matter Numbers - Q4 2014  February 4, 2015
                                 NS Power has taken a staged approach to the design and construction of the fish passage infrastructure
                                 on the St. Margaret's Bay (STM) Hydro System.  The St. Margaret's Bay system is being evaluated for a
                                 fish passage that starts at the mouth of the Little Indian River and extends to the upper reaches of the
                                 Big Indian watershed.  This will include passage beyond barriers at Little Indian Lake, Sandy Lake and
                                 Big Indian Lake.  The initial phase of design required a review of various conceptual design options by an
                                 outside consultant.  Based on those initial designs, NS Power has moved to a detailed design of a fish
                                 ladder for the Sandy Lake Dam.  Within this project, NS Power is completing fish passage at Sandy Lake
                                 as well as evaluating and completing minor modifications required at the Little Indian Lake outlet
                                 to remove any potential barriers.

   •  M06693    NSPI - HYD - Wrights Lake Dam Refurbishment - $1,600,449 - ACE $2,242,751 - January 30, 2015
                                               UARB Letter to NSPI - Assigning Matter Numbers - Q4 2014  February 4, 2015
                                 In 2009, NS Power carried out a flood study and external dam safety review of its St. Margaret's Bay Hydro
                                 system in accordance with the Canadian Dam Association's Dam Safety Guidelines.  The external dam safety
                                 review concluded that the concrete dam and spillway structure at Wright's Lake are in need of refurbishment,
                                 and the factor of safety under ice loading conditions is below the required acceptance criteria.  In addition,
                                 the embankment dams have insufficient minimum freeboard during flood conditions, and the slopes of the
                                 embankment dams do not meet current stability requirements.  In the interim, water levels have been kept
                                 at a lower level to mitigate this risk.  Since 1986, NS Power has carried out dam safety projects on a priority
                                 basis based on risk.  Based on the current condition of the Wright's Lake dam and to mitigate the risk of
                                 breaching or overtopping of the dam, this work will be completed in 2015.

   •  M06692    NSPI - IT - Printer Fleet Refresh - $349,026 - ACE $500,000 - Forecast: $349,026 - January 30, 2015
                                               UARB Letter to NSPI - Assigning Matter Numbers - Q4 2014  February 4, 2015
                                 This project consists of the replacement, through a capital lease, and rollout of 97 Multi-Function Devices (MFDs).
                                 Each unit provides printing, faxing, scanning and photocopying services to NS Power.  Why do this project now?
                                 The original four-year lease for the MFD fleet expired in July 2012.  At that time, NS Power extended the lease as
                                 these assets were still in good working condition and meeting the needs of the business.  The units have now reached
                                 the end of their service life.  In September 2014, NS Power initiated a Request For Proposal process for the replacement
                                 of these MFDs.  Final quantities and individual unit requirements were not finalized until late November 2014.  Why do
                                 this project this way?  Continued maintenance on the current MFDs is not a practical solution as the equipment has
                                 exceeded its expected useful life and must be replaced.  Leasing these units is the preferred option, as ongoing mainten-
                                 ance, repairs and disposal at end of life is not required.  Standard industry practice is to lease equipment such as this.
                                 Accounting Standards Codification 840.10.25.1 requires that this be treated as a capital lease.  This standard states
                                 "The lessee shall measure a capital lease asset and capital lease obligation initially at an amount equal to the present
                                 value at the beginning of the lease term of minimum lease payments during the lease term".

   •  M06691    NSPI - HYD - Avon #2 Generator Stator Rewind - $633,484 - ACE $694,096 - January 30, 2015
                                               UARB Letter to NSPI - Assigning Matter Numbers - Q4 2014  February 4, 2015
                                 This project consists of design, manufacture of the replacement stator coils, disassembly of the generator,
                                 removal of the old stator coils, core testing, and installation of new coils, reassembly and testing of the generator.
                                 In 2009 and 2010, the Avon 2 generator had two stator winding faults (phase to ground) in which the stator coil
                                 ground wall insulation failed.  These failures were addressed through small repairs at the time.  An investigation
                                 revealed the insulation is prone to moisture infiltration while the unit is off-line, or if there is water leakage near
                                 the stator while the unit is running.  If the stator is energized with damp, porous insulation, the likelihood of failure
                                 is high.  A phase-to-phase failure occurred in July 2014, which has increased the probability of similar failures
                                 occurring on this unit in the future.  This type of failure can cause damage to the stator winding and core.
                                 Why do this project now?  The stator insulation in this unit is prone to failure.  If a phase-to-phase fault were to
                                 occur again, there could be damage to the stator winding and core which would take up to 12 months to repair.
                                 In addition to the cost of the stator rewind there would be a year of lost generation and cost to repair or replace
                                 the core.  The generation from NS Power's legacy hydro facilities qualifies under the provisions of the Nova Scotia
                                 Renewable Electricity Regulations.  Generation from hydro facilities is an important part of NS Power's compliance
                                 plan to serve 25% of sales from qualifying renewable generation sources.  Why do this project this way?
                                 Rewinding generator stators is standard industry practice when the other major generator components (core,
                                 frame, brackets and rotor) are believed to have 20+ years of remaining service life.  Replacement of the stator
                                 would be a significantly more expensive alternative with no added benefits.

   •  M06690    NSPI - POT (Point Tupper) Bunker C Tank Refurbishment - $2,391,564 - ACE $2,239,835 - January 30, 2015
                                               UARB Letter to NSPI - Assigning Matter Numbers - Q4 2014  February 4, 2015
                                 The Point Tupper Heavy Oil Tank, originally installed in 1968, is required to provide fuel to Unit 2 boiler for startup,
                                 support energy when firing one coal pulverizing mill, and is also capable of providing enough fuel for full load.
                                 For a thorough inspection to be perfomed, this tank has to be empty.  At the time of the ACE 2014 filing,
                                 detailed inspections were not completed on this tank.  A second API 653 inspection was performed in 2014.
                                 Based on the most recent inspection, repairs are now required to return the tank to long term service.  An
                                 In-Service American Pertroleum Institute API-653 inspection of the Bunker C Tank, carried out in December 2010
                                 per Thermal Maintenance Practices, identified two areas of concern.  First, there was thinning on the outer
                                 projection approaching the minimum allowable thickness per API-653 section 4.4.5.4.  Second, there was
                                 corrosion visible on the bottom side of the tank, the extent of which cannot be quantified without performing
                                 a floor inspection from inside the empty tank.  The API inspection report advised that the tank's outer projection
                                 would be at minimum thickness in 2014 based on present corrosion rates.  Subsequent ultrasonic thickness
                                 measurements on the outer projection in March 2012 show that the wall thickness is less than minimum thickness
                                 on the outer projection several feet away from the original area of concern.  This project includes the removal of
                                 a ring of tank floor at the outer rim of the tank and installing a new annular ring to address thinning of the existing
                                 floor plate.  Other repairs include welding repairs at manways, pad welding of pits and thinned areas, removal of
                                 obsolete equipment, replacement of walkway handrail, and some civil work to improve drainage in the dyke and
                                 redirect water away from the tank.  In order to retain the ability to fire Bunker C oil, the station must either refurbish
                                 or replace the Bunker C tank with another means of storage.  Refurbishing the tank is the most cost-effective means
                                 to restore availability of Bunker C for the Point Tupper Generating Station.  Replacing the tank would cost, at minimum,
                                 approximately $300k more than refurbishment, with no additional benefit.

   •  M06689    NSPI - (Tufts Cove) TUC5 LM6000 - Engine 191-332 Refurbishment - P&A - $7,768,463 - January 30, 2015
                                               UARB Letter to NSPI - Assigning Matter Numbers - Q4 2014  February 4, 2015
                                 Engine Serial Number 191-332, installed in TUC Unit 5 experienced an internal oil system failure and subsequent
                                 oil leak in October 2014.  The engine could not operate with this leak present.  This oil leak exposed the engine
                                 enclosure to a potential fire hazard and this could have led to internal engine damage.  The engine was immediately
                                 removed and shipped to a maintenance facility for disassembly, assessment and refurbishment.  As this engine was at
                                 approximately 41,000 operating hours, which is near its 50,000 hour (nominal interval) maintenance interval, it is prudent
                                 to conduct those interval maintenance activities at this time as opposed to opening up the engine again in the near future.

   •  M06685    NSPI - Revised Plan of Administration (POA) and Fuel Adjustment Mechanism (FAM) tariff - January 30, 2015
                                 The applicable charges for electric service to NS Power's retail and municipal customers shall be
                                 increased or decreased by an amount calculated to the nearest 0.001 cent per kWh ($0.000 01 per kWh)
                                 to recover or credit the difference in actual fuel cost from the costs in base rates...
                                                                Reference:
                                        •  Matter Number M06685 – 2015 NSUARB 28 - UARB Order - February 17, 2015

   •  M06683    NSPI - Renewable Energy Feed In Tariffs - Fourth Annual COMFIT Annual Report - January 30, 2015
                                 COMFIT projects are approved by the Minister of Energy in accordance with the Renewable Electricity Regulations.
                                 Projects totaling approximately 240 MW (322 000 horsepower) have been approved to date.
                                 A complete list of approved COMFIT projects is available.

   •  M06674    Friends of Harmony/Camden, Greenfield and Surrounding Areas - Appeal of a Decision...Minister of Energy - Jan. 23, 2015
                                 — Greenfield COMFIT Wind Farm #183 - Production capacity: 3.2 MW (3900 horsepower) - 2 GE 1.6 MW turbines
                                 Located on Weatherby Ridge, Greenfield, Colchester County, about nine km east southeast from downtown Truro
                                 — The purpose of the proposed undertaking is to provide 3.2 MW of wind power into the local distribution grid
                                 in Greenfield, Colchester County, NS.  The Project will consist of two 1.6 MW wind turbines on privately owned
                                 land.  Pending approval to proceed, construction is anticipated to commence winter 2014 with operations to begin
                                 in winter 2015.  On January 28, 2015, the Minister of Environment released a decision concerning this review.
                                 The Minister decided to approve the undertaking...
                                 — On March 27, 2015, the UARB issued its decision to allow the Appeal to proceed.
                                                                                           References:
                                        •  Matter Number M06674 – 2015 NSUARB 140 - UARB Decision - May 25, 2015
                                        •  Wind farm foes get green light to carry on appeal   Chronicle-Herald, Halifax - March 30, 2015
                                        •  Matter Number M06674 – 2015 NSUARB 65 - UARB Decision - March 27, 2015
                                        •  Matter Number M06673 – Appeal by Friends of Harmony/Camden/Greenfield... - January 23, 2015
                                        •  Matter Number M06329 – Friends of Harmony/Camden, Greenfield and Surrounding Areas - July 21, 2014
                                        •  Residents weigh in against turbine plan   Chronicle-Herald, Halifax - July 22, 2014
                                        •  MLA files citizens' petition in Province House over Greenfield wind turbine project concerns
                                                                The Labradorian, Happy Valley-Goose Bay - April 25, 2014
                                        •  Colchester County approves new wind turbine bylaw   The Daily News, Truro - October 30, 2013
                                        •  Open house planned for wind farm site   The Daily News, Truro - May 28, 2013
                                        •  Greenfield Wind Farm Environmental Assessment Registration  November 2013
                                        •  Matter Number M05416 – NSCA - South Canoe WP - 2013 NSCA 134 (Unsigned copy - HTML CANLII)  Nov. 26, 2013

   •  M06673    Appeal by Friends of Harmony/Camden/Greenfield and Surrounding Areas - January 23, 2015
                                               This Notice of Appeal is submitted in a letter, via email and fax,
                                               further to a discussion...respecting the form and manner of appeal.
                                 — TAKE NOTICE that the Appellant, the community group "Friends of Harmony/Camden, Greenfield
                                 and Surrounding Areas"...pursuant to Section 48 of the Renewable Electricity Regulations under
                                 the Electricity Act...hereby appeals...the decisions made by the Minister of Energy regarding
                                 Affinity Wind LP Greenfield COMFIT Wind Farm #183 (Project #183) (Greenfield project)...
                                                                                           References:
                                        •  Wind farm foes get green light to carry on appeal   Chronicle-Herald, Halifax - March 30, 2015
                                        •  Matter Number M06674 – 2015 NSUARB 65 - UARB Decision - March 27, 2015
                                        •  Matter Number M06673 – Appeal by Friends of Harmony/Camden/Greenfield... - January 23, 2015
                                        •  Matter Number M06329 – Friends of Harmony/Camden, Greenfield and Surrounding Areas - July 21, 2014
                                        •  Residents weigh in against turbine plan   Chronicle-Herald, Halifax - July 22, 2014
                                        •  MLA files citizens' petition in Province House over Greenfield wind turbine project concerns
                                                                The Labradorian, Happy Valley-Goose Bay - April 25, 2014
                                        •  Colchester County approves new wind turbine bylaw   The Daily News, Truro - October 30, 2013
                                        •  Open house planned for wind farm site   The Daily News, Truro - May 28, 2013
                                        •  Greenfield Wind Farm Environmental Assessment Registration  November 2013

   •  M06662    Berwick Electric Commission - 2015 Flow Through Application - January 14, 2015
                                        2015 NSUARB 11 - UARB Decision - January 20, 2015 - New rates effective January 1, 2015
                                 Domestic Service
                                              Service Charge: $18.87 per month
                                              Energy Charge: 13.13¢ per kilowatt hour for all consumption
                                              Minimum bill: $18.87 per month
                                 Domestic Service Time-of-Day Rate (optional)
                                              Base Charge: $23.19 per month
                                              Energy Charge: 7.98¢ per kWh  or  13.13¢ per kWh  or  25.83¢ per kWh
                                                                        depending on time-of-day and day-of-week and month-of-year
                                                                        (for details see page 5 of 2015 NSUARB 11)
                                              Minimum Monthly Charge: The minimum monthly charge shall be $23.19
                                 Energy Rebate (refund of the Provincial portion of the Harmonized Sales Tax)
                                              Energy Rebate for Residential Electricity Users

   •  M06661    Town of Mahone Bay Electric Utility - 2015 Flow Through Application - January 14, 2015
                                        2015 NSUARB 10 - UARB Decision - January 19, 2015 - New rates effective January 1, 2015
                                 Domestic Service
                                              Three-Wire (120/240 volts) Service Charge: $11.58 per month
                                              Energy Charge: 14.5821¢ per kilowatt hour for the first 200 kilowatt hours per month
                                                                         12.5503¢ per kilowatt hour for all additional consumption.
                                                                         The Fuel Adjustment Mechanism (FAM) recovery charge in the amount
                                                                         of 0.552 138¢ per kWh for the current year, shall apply in addition to the energy charge.
                                              Minimum bill: $11.58 per month
                                 Domestic Service Time-of-Day Rate (optional)
                                              Base Charge: $$22.41 per month
                                              Energy Charge: (7.2917 + 0.552 138)¢ per kWh  or  (12.5503 + 0.552 138)¢ per kWh
                                                                        depending on time-of-day and day-of-week and month-of-year
                                                                        (for details see page 7 of 2015 NSUARB 10)
                                               Minimum Monthly Charge: The minimum monthly charge shall be $22.41
                                 Energy Rebate (refund of the Provincial portion of the Harmonized Sales Tax)
                                              Energy Rebate for Residential Electricity Users

   •  M06660    NSPI - Maritime Link-Related Transmission Capital Work - Replace L-6513, Upgrade... - $22,067,148 - January 14, 2015
                                 L-6513 was originally built in 1965 utilizing a wood pole H-frame with timber cross arm design and is approaching
                                 its 50th year of service.  This project consists of building a new transmission line (L-6613) to replace the adjacent
                                 line (L-6513) for a designed operating temperature of 100°C utilizing 1113 kcmilNOTE 1 Beaumont conductor.
                                 This replacement line with upgraded operating temperature is necessary to support the additional energy from the
                                 Maritime Link (ML).  Presently L-6513 has an operating temperature of 50°C, with a summer rating of 110 MVA
                                 and a winter rating of 165 MVA.  Also included in this project is the upgrading of protection schemes at both the
                                 1N-Onslow and 74N-Springhill substations to accommodate the increase in megawatt capacity introduced by
                                 the ML Project.  The new 138 kV transmission line L-6613 shall parallel the existing line L-6513 on a common
                                 right-of-way (ROW) for most of the 64.7 km from the 1N-Onlsow to 74N-Springhill substations.  The new line shall
                                 be constructed in the old line L-6514 ROW (previously known as the Old Canada Electric Transmission Line).
                                 Metering presently associated with MW, MVAR and MVA flows at both the 1N-Onslow and 74N-Springhill terminals
                                 is scaled for 150 MVA full scale.  Current transformer ratios and local metering will be modified from the existing
                                 600/5 amperes to 1200/5 amperes to allow for full scale 300 MVA indication...
                                             [Note 1 (cross-section area of conductor):   1113 kcmil = 1113 thousand circular mils = 1,113,000 circular mils]

   •  M06656    NERC - North American Electric Reliability Corporation - Risk Based Registration...Rules...Revisions - January 6, 2015
                                 This filing is for informational purposes only, and NERC is not requesting any action with regard to this filing.
                                 NERC's Risk-Based Registration initiative seeks to ensure that the right entities are subject to the right
                                 set of applicable Reliability Standards, using a consistent approach to risk assessment and registration.
                                 NERC's mission is to assure the reliability of the Bulk-Power System and as an organization, NERC has
                                 been transforming its approaches to compliance and enforcement to be forward-looking with a focus on high
                                 reliability risk areas.  As NERC has matured in its role as the Electric Reliability Organization (ERO), it has
                                 shifted the paradigms for compliance and enforcement, and for drafting results-based Reliability Standards.
                                 Additionally, and likewise, implementation of the NERC Registry Criteria over the last eight years has yielded
                                 a wealth of experience and information.  Informed by these efforts and consistent with these developments in
                                 the framework for compliance, enforcement, and Reliability Standards, NERC is proposing to reform registration
                                 in a manner that will drive the registration program toward a mature end-state...
                                                                                           References:
                                        •  Matter Number M06656 – NERC - North American Electric Reliability Corporation - Rules Revisions - Jan. 6, 2015
                                        •  Matter Number M06545 – NERC - North American Electric Reliability Corporation - Q3 2014 - November 26, 2014
                                        •  Matter Number M06525 – NSPI - Onslow 345 kV Node Swap - November 14, 2014
                                        •  Matter Number M06427 – NERC - N.A. Electric Reliability Corporation - 2015 Business Plans etc. - Sep. 17, 2014
                                        •  Matter Number M06363 – NERC - North American Electric Reliability Corporation - Q2 2014 - August 15, 2014
                                        •  Matter Number M06294 – NSPI - Protection Risk Reduction 67N-Onslow 230kV - $2,870,285 - June 25, 2014
                                        •  Matter Number M06258 – NERC - North American Electric Reliability Corporation - Q1 2014 - May 20, 2014
                                        •  Matter Number M06132 – NERC - North American Electric Reliability Corporation - Q4 2013 - February 28, 2014
                                        •  Matter Number M06011 – NERC - North American Electric Reliability Corporation - Q3 2013 - November 26, 2013
                                        •  Matter Number M05944 – NERC - N.A. Electric Reliability Corporation - 2014 Business Plans etc. - Nov. 04, 2013
                                        •  Matter Number M05862 – NERC - North American Electric Reliability Corporation - Q2 2013 - August 30, 2013
                                        •  Matter Number M05713 – NERC - North American Electric Reliability Corporation - Q1 2013 - May 31, 2013
                                        •  Matter Number M04460 – NERC - First NERC Quarterly Application...Approval...Reliability Standards... - Sep. 06, 2011
                                        •  Matter Number M04025 – NSPI - Review...Reliability of Service at NSPI - April 04, 2011
                                        •  Matter Number M03815 – NSPI - Backup Control Centre - $3,222,066 - December 24, 2010
                                        •  Matter Number M03324 – NERC - NERC Reliability Standards; and NPCC Regional Reliability Criteria - June 29, 2010
                                        •  Matter Number M01989 – NSPI - CIP Standards Implementation - $422,923 - July 22, 2009
                                        •  Matter Number M01871 – NSPI - Report to the UARB Regarding NSPI/NB Power Interconnection - June 30, 2009

   •  M06655    Lunenburg Electric Utility - 2015 Flow Through Application - January 13, 2015
                                        2015 NSUARB 8 - UARB Decision - January 15, 2015 - New rates effective January 1, 2015
                                 Domestic Service
                                              Service Charge: $12.06 per month
                                              Energy Rate: 14.483¢ per kilowatt hour for the first 200 kilowatt hours per month
                                                                     13.077¢ per kilowatt hour for all additional consumption
                                                                     but in no case shall the average price per kilowatt hour on the whole bill, including
                                                                     the service charge, be less than 14.057¢ in any billing period
                                              Minimum bill: $12.06 per month
                                 Domestic Service Time-of-Day Rate (optional)
                                              Base Charge: $22.85 per month
                                              Energy Rate: 8.244¢ per kWh  or  13.077¢ per kWh  or  26.154¢ per kWh
                                                                    depending on time-of-day and day-of-week and month-of-year
                                                                   (for details see page 6 of 2015 NSUARB 8)
                                              Minimum Monthly Charge: The minimum monthly charge shall be $22.85
                                 Energy Rebate (refund of the Provincial portion of the Harmonized Sales Tax)
                                              Energy Rebate for Residential Electricity Users

   •  M06652    Riverport Electric Light Commission - 2015 Flow Through Application - January 9, 2015
                                        2015 NSUARB 5 - UARB Decision - January 14, 2015 - New rates effective January 1, 2015
                                 Domestic Service
                                              Service Charge: $12.03 per month where service is through a two or three wire service
                                              Energy Rate: 14.49¢ per kilowatt hour for the first 200 kilowatt hours per month
                                                                     12.99¢ per kilowatt hour for all additional consumption in any billing period,
                                                                     but in no case shall the average price per kilowatt hour on the whole bill, including
                                                                     the service charge, be less than 13.59¢ in any billing period
                                              Minimum bill: $12.03 per month where service is through either two or three wire service
                                 Domestic Service Time-of-Day Rate (optional)
                                              Base Charge: $20.83 per month
                                              Energy Rate: 8.38¢ per kWh  or  12.99¢ per kWh  or  25.98¢ per kWh
                                                                   depending on time-of-day and day-of-week and month-of-year
                                                                   (for details see page 6 of 2015 NSUARB 5)
                                              Minimum Monthly Charge: The minimum monthly charge shall be $20.83
                                 Energy Rebate (refund of the Provincial portion of the Harmonized Sales Tax)
                                              Energy Rebate for Residential Electricity Users

   •  M06644    NSPI - Maritime Link Changes to Affiliate Code and Guidelines - December 19, 2014
                                              References: Affiliate Code of Conduct (M06268) and Maritime Link (M05419)
                                 — NSPI Revised Code of Conduct - Redline Version  [Exhibit N-2 in Matter Number M06644]
                                 — Revised 2014 Guideline 11 - Separation of Financial Records - Redline Version [Exhibit N-4 in Matter Number M06644]
                                 In its Supplemental Decision (2013 NSUARB 242) on the Maritime Link Application (M05419)
                                 dated November 29, 2013, the Utility and Review Board noted the following:
                                 — Nalcor Forecast - On a monthly basis during the Term, Nalcor will provide a good faith forecast
                                 to NSPI of Available Energy forecasted to be available for sale to NSPI for the following 24 months,
                                 up to a maximum of 1.8TWh per Contract Year (each such forecast is a "Nalcor Forecast"). The Nalcor Forecast
                                 shall include a forecast of the total Available Energy denominated by Peak Hours and Off-Peak Hours for each
                                 month, all being capable of delivery at the Delivery Point... Counsel for the Province expressed
                                 the concern that this information should not be shared by NSPI with Emera or its affiliates...

   •  M06623    Antigonish Electric Utility - 2015 DSM Flow Through Rates - December 23, 2014
                                        2015 NSUARB 4 - UARB Decision - January 12, 2015 - New rates effective January 1, 2015
                                 Domestic Service
                                               Base Charge: $14.42 per month
                                               Energy Rate: 12.037¢ per kilowatt hour for all consumption
                                 Domestic Service Time-of-Day Rate (optional)
                                               Base Charge: $20.13 per month
                                               Energy Rate: 8.403¢ per kWh  or  12.037¢ per kWh  or  23.249¢ per kWh
                                                                     depending on time-of-day and day-of-week and month-of-year
                                                                     (for details see page 9 of 2015 NSUARB 4)
                                               Minimum Monthly Charge: The minimum monthly charge shall be $20.13
                                 Energy Rebate (refund of the Provincial portion of the Harmonized Sales Tax)
                                               Energy Rebate for Residential Electricity Users

   •  M06614    NSPI - Natural Gas Report - April 1, 2014 to October 31, 2014 - December 22, 2014
                                 — NSPI Natural Gas Report April 1, 2014 - October 31, 2014 [Exhibit N-1 in Matter Number M06614]

   •  M06613    NSPI - Revised Fuel Adjustment Mechanism (FAM) Plan of Administration - December 19, 2014
                                 — NSPI Revised FAM Plan of Administration - Redline Version [Exhibit N-1 in Matter Number M06613]

Each January 1  through  December 31  period  shall  constitute  a  distinct  FAM year.   Under the FAM, an  adjustment  will be made
once per year to reflect the  over-  or  under-recovery starting in the FAM's second year of operation (2010).  This document describes
the plan  for  administering  Nova Scotia Power Inc.'s  Fuel  Adjustment  Mechanism (FAM),  which was  approved  by the Nova Scotia
Utility and Review Board (Board) in its  decision  letter  issued  on December 11, 2008.   The FAM provides for the recovery of fuel and
purchased  power costs beginning January 1, 2009.   The Plan of Administration (POA)  outlines  the  application  and  operation  of the
FAM... The Base Cost of Fuel can be reset in a General Rate Application or  every  second  year as part of the FAM adjustment process.
A forecast of costs and load for the succeeding test year will be used to set the Base Cost of Fuel.  The change in the Base Cost of Fuel
will be  reflected  in  customers'  rates  going  forward  and will be applied to each customer class in a manner consistent with the Cost of
Service Study (COSS).   Stakeholders  shall  have  the  opportunity  (and access to information) to  challenge  the implementation of the
methodology and  the  contents  of  any  forecast  prior  to  its  use  in  resetting  the  Base Cost of Fuel.  Both the implementation of the
methodology and the forecasts will be the subject of a formal Board proceeding in which stakeholders will have their current rights as in
general rate cases.  Stakeholders shall have the opportunity  to  challenge  NS Power's fuel costs (and to secure access to information)
at each annual hearing before the Board consistent with  their  current  rights in general rate cases... The FAM will only pass through a
portion of the difference between actual costs and the Base Cost of Fuel to customers calculated on a ¢/kWh basis.  For variances up
to $50 million on a $/MWh basis  (Actual Fuel Costs - [(Actual Sales) × (Base Fuel $/MWh)]),  90% of any savings or increases will be
passed from NS Power to customers.  NS Power  will  remain  responsible  for 10%  of the  increase  or retain 10% of the fuel savings.
The portion of any  annual  variance  in  excess  of  $50 million  will  be  the  responsibility  of customers.  The maximum effect of the
incentive for NS Power in any one year is $5 million.  Interest will be added to all over- or under-balance amounts and calculated
at NS Power's Allowance for  Funds  Used  During  Construction (AFUDC).  Subject to the foregoing incentive, the FAM
will recover fuel cost changes resulting from over- or under-recovery amounts, including an Actual Adjustment (AA)
and a Balancing Adjustment (BA) for each rate class.  The FAM adjustment is the difference between actual
fuel cost and the Base Cost of Fuel (subject to the incentive) and will be calculated on a ¢/kWh basis...

   •  M06608    Arthur Alexander Ormiston and Elaine Frampton, c/o Cupids Cove Developments Ltd. - December 18, 2014
                                 A Claim by Arthur Alexander Ormiston and Elaine Frampton... regarding the expropriation of land by NSP Maritime Link Inc.

 
M00000-M00999    M01000-M01999    M02000-M02999    M03000-M03999    M04000-M04999
M05000-M05499    M05500-M05999    M06000-M06199    M06200-M06399
M06400-M06599    M06600-M06799    M06800-M06999    M07000-M07199


In the “Electricity” section of the UARB website
Matter Numbers M06400 to M06599

      Matter
    Number


                                        Maritime Link across Cabot Strait       500 MW        670 000 horsepower
   •  M06592    NSPML - Nova Scotia Power Maritime Link Inc. - NSPML 2014 Q4 Quarterly Report - December 15, 2014
                                 — This [Exhibit N-1 in Matter Number M06592] is the Q4 2014 Quarterly Report for the Maritime Link as directed by the UARB.
                                 1.0 Introduction
                                 2.0 Update of Project Schedule...
                                            2.1 Gates and Milestones
                                            2.2 Commercial Activities
                                                   2.2.1 Land Access Agreements
                                                   2.2.2 Funding
                                                   2.2.3 Joint Development Agreements
                                            2.3 Engineering Activities
                                            2.4 Submarine Cables (Marine)
                                            2.5 Horizontal Directional Drilling (HDD) Boreholes (NS and NL)
                                            2.6 Converter Stations
                                            2.7 Right of Way Clearing Contractor(s) – Transmission Lines
                                            2.8 Construction Contractor(s) – Transmission Lines
                                            2.9 Construction Contractor(s) – Site Preparation
                                                         The designs for the grounding sites, including the breakwaters in NS and NL, were completed
                                                         for the Request for Proposals (RFP) which was issued and closed in October 2014.  The proposals
                                                         are being evaluated and construction of the grounding site marine breakwaters are scheduled to
                                                         begin in 2015.  The designs of the grounding site electrical specifications are in development and
                                                         will be included in the RFP scheduled to be issued in 2015.
                                            2.10 Granite Canal Accommodations Construction
                                            2.11 Granite Canal Accommodations Operations
                                            2.12 Construction Contractor(s) – Other
                                 3.0 Updated Cost Summary

This is the Q4 2014 quarterly report for the Maritime Link as directed by the UARB...
The Independent Engineer, MWH Canada, Inc., (formerly Montgomery Watson Harza)
acting  on  behalf  of  the  Government  of  Canada,  participated  in a  site  visit for the
Maritime Link (ML) Project  during  October  in both  NS  and  NL.  The IE was accom-
panied by  a  representative  of  Natural Resources Canada as well as representatives
from NSPML.  Please refer to Attachment 7 for a copy of the Report from the site visit...

                                                                                           References:
                                        •  Matter Number M06821 – NSPML - Maritime Link 2015 Q1 Quarterly Report - April 15, 2015
                                        •  Matter Number M06592 – NSPML - Maritime Link 2014 Q4 Quarterly Report - December 15, 2014
                                        •  Matter Number M06477 – NSPML - Maritime Link 2014 Q3 Quarterly Report - October 15, 2014
                                        •  Matter Number M06280 – NSPML - Maritime Link - 2013 Affiliate Code of Conduct Annual Report - June 13, 2014
                                        •  Matter Number M06279 – NSPML - Maritime Link 2014 Q2 Quarterly Report - June 13, 2014
                                        •  Matter Number M06191 – NSPML - Maritime Link 2014 Q1 Quarterly Report - April 15, 2014
                                        •  Matter Number M06024 – NSPML - Maritime Link 2013 Q4 Quarterly Report - December 13, 2013
                                        •  Matter Number M05419 – NSPML - Application for approval of the Maritime Link Project... - January 28, 2013
                                        •  Matter Number M05419 – NSP Maritime Link Incorporated (Re), 2013 NSUARB 154 (CanLII)    July 22, 2013
                                               §6.4.2  Submarine (underwater) and Land Cables
                                        •  Matter Number M05419 – NSP Maritime Link Incorporated (Re), 2013 NSUARB 242 (CanLII)    November 29, 2013
                                               §5.2  What should be the reporting requirements for NSPML during the course of the Maritime Link (ML) Project?
                                                       The reporting requirements are set out in §7 of the ML Regulations.

Maritime Link - connecting Muskrat Falls with Nova Scotia

Maritime Link - connecting Muskrat Falls with Nova Scotia
Source: NSPML Quarterly Report, December 2014 - Attachment 6, Page 4 of 5

The Maritime Link Transmission Project

The Maritime Link Project involves the design, construction, operation and maintenance of the 500-megawatt high-voltage
direct  current  transmission line, as well as a 230 kilovolt high-voltage alternating current transmission line and associated
infrastructure, between Granite Canal, Newfoundland and Labrador, and Woodbine, Nova Scotia.  Key components include
two 170-km high-voltage underwater cables across the Cabot Strait, nearly 50 km of overland transmission in Nova Scotia,
nearly 300 km of  overland  transmission  in  Newfoundland,  as well as related  land-based  equipment and infrastructure
(e.g., converter stations, grounding facilities).  The Project will deliver  986,000  megawatt  hours annually (or about 8% to
10% of Nova Scotia's annual electricity demand) of  energy  generated  by Nalcor Energy's Lower Churchill Project (LCP),
which is  expected  to  be  operational  by the  end  of 2017.  The Project will provide Nova Scotia with a more diversified
portfolio of  energy  options  and  reduce  dependency  on existing commercial-scale  carbon-based  generation facilities.
It will also provide Newfoundland and Labrador greater interconnection and access to other electricity markets through a
new regional loop.  The Project is based on  major  transaction  agreements  with Nalcor Energy, which has committed to
deliver 20% of the LCP generation in exchange for Emera's paying for, engineering, constructing, maintaining and owning
the Project and the  electricity  transmission  rights  within Nova Scotia.  NSPML will own the Project's assets for 35 years
following the beginning of  commercial  operation,  after which ownership will be transferred to Nalcor Energy.  The project
company, NSPML, was established as a utility company under Nova Scotia laws.  It is regulated by the Nova Scotia Utility
and Review Board (UARB) and will benefit from a  regulated  revenue  requirement, which covers all approved operating
and maintenance costs, debt service and UARB-approved return on equity.  All costs  "prudently  incurred,"  as defined by
the UARB, will be passed through to  rate  payers,  who will essentially be bearing volume, market and performance risks.
DBRS (originally known as Dominion Bond Rating Service)  views  the  technology  risk  pertaining  to  the  Project as low
to medium,  based  on  the  proven  equipment  to be  used  and  performance  data  from  existing  transmission  assets.
However, the installation of the  two  170-km  underwater  cables  is  not  a trivial  task  and is  not  considered  low risk.
The  fabrication  and  installation  of  the  cables  will  be  provided  on  a  fixed-price  basis.   Work  has  started
in 2014  with  completion  and  beginning  of   commercial   operations   scheduled  for  2017.
The  total  gross  budget  for  the  Project  is  estimated  to  be  $1.58 billion.

   •  M06582    Heritage Gas Limited - Natural Gas Storage Services Costs Application - December 11, 2014
                                 – Alton Natural Gas Storage LP (Alton) proposes to establish a large underground gas storage facility near
                                 Alton in Colchester County, Nova Scotia.  Heritage Gas Limited (Heritage), a company regulated by the
                                 Nova Scotia Utility and Review Board, wants to use the new facility.  In a Decision dated February 20, 2014,
                                 the Board determined that storage costs could be included in Heritage's cost of service.  On December 10, 2014,
                                 Heritage filed an Application (M06740) with the Board for approval of the treatment, and the recovery, of
                                 natural gas storage service costs.
                                 – The parties to this proceeding were: Heritage Gas; Alton; the Consumer Advocate, appointed by the Board;
                                 Nova Scotia Power Incorporated (which generates most of the electricity in Nova Scotia, and a major user of
                                 natural gas); and the Nova Scotia Department of Energy.
                                 – Underground storage of natural gas (for example in large caverns) is a common practice around the world.
                                 Benefits include lower costs for natural gas customers, and improved security of supply.  All parties in this
                                 proceeding agree that, for exactly these reasons, this proposal promises to be beneficial to natural gas
                                 customers in Nova Scotia, indirectly including everyone who buys electricity from NS Power Inc.
                                 – The proposed storage facility will give Heritage the opportunity to buy extra natural gas when prices are lower.
                                 Later, when prices are higher, Heritage will be able to use the cheaper stored gas, and pass on the saving to its
                                 customers.  In the present instance, the parties agree the savings may be large indeed.  For example, an expert
                                 witness retained by Heritage suggests they may amount to around $17 million a year.
                                 – Further, the presence of a large quantity of stored gas provides a margin of safety in the event that supplies
                                 of natural gas coming into the province are – for whatever reason – interrupted or impaired.
                                 – On October 20, 2014, Heritage and Alton entered into an agreement (termed a "Precedent Agreement") for
                                 natural gas storage service, which forms the basis of the revenue requirement referred to in this Application...
                                                                                          References:
                                               • Application by Heritage Gas Limited for approval...natural gas storage service costs   June 4, 2015
                                               Heritage Gas Limited (Re), 2015 NSUARB 147 (CanLII)   June 4, 2015

   •  M06564    NSPI WO - TRE (Trenton) Bunker C System Upgrades - $469,838 - December 2, 2014
                                 The Trenton Generating Station's operating approval requires that the current Bunker C oil storage / delivery system be
                                 assessed to ensure compliance with current codes and regulations.  This third party assessment has been completed as
                                 requested as well as filed with Nova Scotia Environment (NSE).  The purpose of this project is to address the recommen-
                                 dations associated with the report and upgrade the Bunker C system at the Trenton Generation Station.  The project will
                                 improve the overall reliability of the system.  Trenton Generating Station has boilers that are designed to burn coal, and
                                 like other coal burning facilities, it uses heavy fuel oil (Bunker C) as a backup fuel.  Bunker C oil is stored in an above
                                 ground storage tank on site.  The storage tank was constructed in 1968, and when filled to capacity, provides enough
                                 fuel for one unit to operate exclusively on oil at full load for approximately six days.  Availability of Bunker C is critical to
                                 allow uninterrupted operation of the plant for contingency purposes.  Firing Bunker C can also increase plant output in
                                 the event coal quality degrades during winter months.  Prior to the Operating Approval renewal, the Bunker C storage
                                 and delivery system was maintained to the standards of the day of construction.  Changes in the operating approval
                                 now require this system be brought up to today's standards.  As stipulated by NSE, NS Power is required to conduct a
                                 Petroleum Storage Tank System Assessment, with the purpose of assessing petroleum storage tanks and associated
                                 works against the "Nova Scotia Standards for Construction and Installation for Petroleum Storage Tank Systems,"
                                 current edition and the "Nova Scotia Petroleum Management Regulations."  The Approval Holder will undertake the
                                 necessary maintenance or upgrades within one year of being identified.  If these deficiencies cannot be corrected within
                                 one year of being identified, then the reasons shall be submitted in writing 60 days prior to the deadline with a proposal
                                 for a revised schedule, and a request for an extension.  This project will address the required upgrades to the Bunker C
                                 System in order to meet environmental compliance for current standards.  Why do this project?  The upgrades to the
                                 Bunker C System are required to maintain compliance with the Trenton Plant operating approval and will upgrade the
                                 Bunker C system to current standards.  It will also improve reliability of the Bunker C Fuel System.

   •  M06563    NSPI WO - TRE 5 (Trenton) 5-2 Boiler Feedwater Pump Refurbishment P&A (Planned & Advanced) - $474,925 - December 2, 2014
                                             ["Planned & Advanced" (P&A) refers to projects pulled forward from future years for completion in the current year.]
                                 The 5-1 and 5-2 boiler feedwater pumps (BFP) installed on Trenton Unit 5 are Byron Jackson double-case, 9-stage pumps
                                 which supply 1260 gallons per minute (5730 litres per minute) of feedwater to the boiler.  The pumps are  built  with  an
                                 external  pressure  retaining  housing  which  surrounds  an  internal "volute".  The volute  includes  rotating  elements
                                 (shaft, impellers) which pressurize water  –  to  the  pressure  existing  in  the  boiler  during  normal  operation (in the vicinity
                                 of 13,000 kPa or 1900 pounds per square inch)  –  as it flows through the pump.  There is a spare volute assembly which is
                                 installed in either pump during pump rebuilds.  The volute that is removed during a rebuild is refurbished and becomes the
                                 new spare.  The BFPs were installed as part of the original equipment in 1969,  In order to generate full load, Trenton Unit 5
                                 requires  both  pumps  to  be  in  operation.   The  Unit  is  derated  to an  average  capacity  of 80MW with only one BFP in
                                 operation (70MW deration).  On May 2, 2014, the 5-2 pump motor began drawing excessive current, so Trenton 5 Unit load
                                 was reduced in an effort to minimize the load on the pump while the issue was investigated.  Vibration analysis determined
                                 that the pump was in distress, and the pump was taken out of service and dismantled for inspection.  Upon disassembly
                                 and inspection of the 5-2 BFP, it was found that the thrust bearing retaining nut had disengaged from the shaft, allowing the
                                 rotating  assembly  to  move  approximately  0.500 inch  (about 12mm)  out  of  position  toward the motor.  The internal
                                 clearance between the rotating and stationary components is approximately 0.120 inch (about 3mm) in either direction.
                                 Therefore, this movement resulted in extensive damage to the rotating element (shaft and all nine impellers) and stationary
                                 parts (including volute casting, wear rings and seal bushings).  The pump must be refurbished so that a spare is on hand
                                 in the event of unexpected volute failure.  This will reduce the time to return the pump to service and the unit to full load.
                                 As part of NS Power's insurance agreement, a spare must be on hand in the event of a failure.  Planning assumptions
                                 include an average derate of 70MW for twelve weeks in the event of failure.

   •  M06562    NSPI WO - HYD (Hydro) - Tom's Lake Spillway Refurbishment U&U - $612,312 - December 2, 2014
                                 This project includes the refurbishment of the Tom's Lake Spillway, located on the Dickie Brook River System, by
                                 extending the length of the spillway and improving the spill channel profile.  Erosion in the spillway channel has
                                 progressed over the last few years.  In May 2014, inspection found that the erosion was further along than anticipated,
                                 requiring the work to be completed immediately.  The erosion is now starting to progress into the spillway toe from the
                                 spillway channel.  Why do this project?  Erosion in the spillway channel has progressed over the last few years.
                                 In May 2014, inspection found that the erosion was further along than anticipated, requiring the work to be completed
                                 immediately.  Erosion is now at the point that the structural adequacy of the spillway is compromised.  Its current
                                 condition would not allow for a spill event to take place safely.  In the event of a spill event, NS Power would be forced
                                 to drain the Tom's Lake head pond in order to prevent further damage to the dam.  Why do this project now?
                                 The erosion in the spillway channel is impeding on the toe of the spillway, structural adequacy is affected and is
                                 threatening the structure.  This refurbishment is being completed now in order to avoid dewatering the head pond to
                                 retain the structural stability of the spillway.  The current condition of the spillway is not adequate to deal with a spill
                                 event, which could occur in the spring of 2015, and would force the dewatering of the head pond.  As of 2015,
                                 generation  from  NS Power's  legacy  hydro  facilities  will  qualify  under  the  provisions  of  the  Nova  Scotia
                                 Renewable Electricity Regulations.  Generation from hydro facilities is an important part of NS Power's
                                 compliance plan to serve 25% of sales from qualifying renewable generation sources.  In May 2014, inspection
                                 found that the erosion was further along than anticipated, requiring the work to be completed immediately.  Moreover,
                                 the project was originally estimated to be completed for less than $250,000 and not requiring UARB approval.
                                 Further scoping showed additional work needed to be completed.

   •  M06561    NSPI WO - LIN (Lingan) E-Gallery Floor Replacement U&U - $950,629 - December 2, 2014
                                 The E coal gallery is the main support structure for the two conveyor belts carrying coal into the building servicing the
                                 four units at the Lingan Generating Station.  The floor of the structure is steel plate, which has deteriorated due to the
                                 corrosive nature of coal and the wet conditions caused by washing down the gallery for general maintenance.  In early
                                 2014, the deterioration was found to be such where access to the E-Gallery was no longer safe.  The centre walkway
                                 has grating installed and has not experienced the same amount of deterioration as under the two belts where in some
                                 cases holes have developed.  This project includes the replacement of the steel floor and some structural steel
                                 refurbishments to allow for complete access of the gallery for operational and maintenance requirements.  Why do
                                 this project?  It is essential to have E-belt and the E Coal Gallery completely operational to ensure reliable electric
                                 energy production.  The E-gallery is the only route for fuel to get to the boilers.  The floor structure is essential for
                                 full access around the belts for long term maintenance and reliability.  Why do this project now?  The floor must be
                                 replaced now to mitigate any long term potential safety risks associated with the deteriorating floor.  In the interim,
                                 limited access for maintenance to the belts is being gained by using fall protection equipment.  Guard rails have
                                 been installed to keep personnel from accessing areas where conditions are not safe.   Why do this project this way
                                 Replacement of the E Gallery floor is the only option as long term full access of the belts is required for maintenance
                                 and reliability.  In the short term, fall restraint and protection is required for limited access to the belts.  There is still
                                 access down the center walkway, as inspection has shown it has not deteriorated as quickly as the floor under the belts.

   •  M06560    NSPI WO - CT (Combustion Turbine) Burnside Unit #3 Generator Refurbishment U&U - $2,567,808 - December 2, 2014

   •  M06555    NSPI - 2014 Cost of Service Study Progress Update - [373 pages] - November 28, 2014

   •  M06552    NSPI - DSM (Demand Side Management) Plan 2016-2018 - December 1, 2014
                                        –  Letter to UARB from Energy Minister Younger [Exhibit "Doreen Friis.pdf" in Matter Numbers M06552 and M05522]
                                 ...I (Energy Minister Younger) would like participants in the regulatory process to understand the government's purpose
                                 in creating the language in the Electricity Efficiency and Conservation Restructuring (2014) Act. The intent of the deferral
                                 of $35 million in costs for Efficiency Nova Scotia is to generally recognize that efficiency programs are an investment.
                                 As such, it is reasonable to capilatize the cost of the program and to allocate the expenses to the extent possible, in the
                                 year the benefits are received.  Those benefits are the reduced electricity generation costs, so our intent is to recognize
                                 the expenses over the period of time when the benefits are realized.  This approach was chosen because there is a
                                 challenge in expensing costs in the year they are incurred since the benefits are not immediately realized...

   •  M06545    NERC - North American Electric Reliability Corporation - Q3 2014 - Application...Approval of Reliability Standard - Nov. 26, 2014
                                 Some or all of NERC's Reliability Standards are mandatory in the Canadian provinces of Alberta, British Columbia, Manitoba,
                                 New Brunswick, Nova Scotia [boldface emphasis added], Ontario, Quebec, and Saskatchewan.
                                 —The North American Electric Reliability Corporation (NERC) hereby submits to the Nova Scotia Utility and Review Board
                                 (NSUARB) an application for approval of the NERC Reliability Standards and an updated NERC Glossary of Terms
                                 approved by the United States Federal Energy Regulatory Commission (FERC or the Commission).  This filing covers
                                 (updates and revisions made during) the time period from July 1, 2014 through September 30, 2014.  NERC requests that,
                                 as specified herein, these Reliability Standards and the associated NERC Glossary of Terms be made mandatory* and
                                 enforceable for users, owners, and operators of the Bulk-Power System within the Province of Nova Scotia.
                                        –  The mission and programs of NERC extend to the United States and Canada.
                                             NERC's primary objective is to ensure that Reliability Standards are adopted as mandatory
                                             and that there is an effective oversight and enforcement regime in all jurisdictions.
                                             The provinces of Nova Scotia, New Brunswick, Quebec and Ontario are included within the boundaries of NPCC.
                                        * Note: NERC standards are now (November 2014) mandatory in Nova Scotia.
                                                                                           References:
                                        •  Matter Number M06656 – NERC - North American Electric Reliability Corporation - Rules Revisions - Jan. 6, 2015
                                        •  Matter Number M06545 – NERC - North American Electric Reliability Corporation - Q3 2014 - November 26, 2014
                                        •  Matter Number M06525 – NSPI - Onslow 345 kV Node Swap - November 14, 2014
                                        •  Matter Number M06427 – NERC - N.A. Electric Reliability Corporation - 2015 Business Plans etc. - Sep. 17, 2014
                                        •  Matter Number M06363 – NERC - North American Electric Reliability Corporation - Q2 2014 - August 15, 2014
                                        •  Matter Number M06294 – NSPI - Protection Risk Reduction 67N-Onslow 230kV - $2,870,285 - June 25, 2014
                                        •  Matter Number M06258 – NERC - North American Electric Reliability Corporation - Q1 2014 - May 20, 2014
                                        •  Matter Number M06132 – NERC - North American Electric Reliability Corporation - Q4 2013 - February 28, 2014
                                        •  Matter Number M06011 – NERC - North American Electric Reliability Corporation - Q3 2013 - November 26, 2013
                                        •  Matter Number M05944 – NERC - N.A. Electric Reliability Corporation - 2014 Business Plans etc. - Nov. 04, 2013
                                        •  Matter Number M05862 – NERC - North American Electric Reliability Corporation - Q2 2013 - August 30, 2013
                                        •  Matter Number M05713 – NERC - North American Electric Reliability Corporation - Q1 2013 - May 31, 2013
                                        •  Matter Number M04460 – NERC - First NERC Quarterly Application...Approval...Reliability Standards... - Sep. 06, 2011
                                        •  Matter Number M04025 – NSPI - Review...Reliability of Service at NSPI - April 04, 2011
                                        •  Matter Number M03815 – NSPI - Backup Control Centre - $3,222,066 - December 24, 2010
                                        •  Matter Number M03324 – NERC - NERC Reliability Standards; and NPCC Regional Reliability Criteria - June 29, 2010
                                        •  Matter Number M01989 – NSPI - CIP Standards Implementation - $422,923 - July 22, 2009
                                        •  Matter Number M01871 – NSPI - Report to the UARB Regarding NSPI/NB Power Interconnection - June 30, 2009
                                                                                           Also See:
                                                      •  North American Electric Reliability Corporation  NERC website
                                                      •  North American Electric Reliability Corporation  Wikipedia
                                                      •  NERC's Staff Expertise Recognized by IEEE Engineering Group  July 31, 2014
                                                      •  Keeping the Electricity Moving: NERC Guards the Bulk Power Grid  ASME
                                                      •  Reliability Standards  NERC
                                                      •  Reliability Standards for the Bulk Electric Systems of North America  complete set, 1838 pages
                                                      •  Integrated Bulk Power System Risk Assessment Concepts  NERC  (Chrome browser recommended)
                                                      •  Reliability – Canadian Electricity Association
                                                      •  ISO RTO   Independent System Operator (ISO)   Regional Transmission Organization (RTO)



Reference:
Memorandum of Understanding
between
Nova Scotia Power Incorporated
and
The Northeast Power Coordinating Council Inc.
and
The North American Electric Reliability Corporation
May 9, 2010
This Memorandum of Understanding (MOU) between Nova Scotia Power Incorporated (NSPI), the
Northeast  Power  Coordinating  Council  Inc.  (NPCC)  and  the  North  American  Electric  Reliability
Corporation (NERC),   supports   the  December 22, 2006  Memorandum  of  Understanding  between
the Nova Scotia  Utility  and  Review  Board  (NSUARB, Board)  and NERC.  This MOU sets forth mutual
understandings of the signatories in relation to the approval and  implementation  of mandatory NERC
Reliability Standards and NPCC Regional Reliability Criteria in Nova Scotia and other related matters.

   •  M06536    NSPI - 2015 FAM AA/BA - November 27, 2014
                                 In the matter of the 2015 Fuel Adjustment Mechanism (FAM) proceeding related
                                              to the Actual Adjustment (AA) and Balance Adjustment (BA) recovery values
                                                                                           Reference:
                                        •  Matter Number M06536 – UARB Decision - December 12, 2014
                                                                     Fuel Adjustment Mechanism (FAM)...(AA)...(BA) for 2015

   •  M06525    NSPI WO - Onslow 345 kV Node Swap - Maritime Link Related Transmission Capital Work - November 14, 2014
                                 This project is to swap the node locations of Line L-8003 and Transformer 67N-T82 on Bus 67N-B82 and add a new
                                 345kV Breaker and two Isolation Switches at the 67N-Onslow Substation (345kV).  This will create a new node between
                                 the existing Breaker 67N-815 and the new breaker 67N-816.  Why do this project?  As a result of the additional generation
                                 associated with the Maritime Link Project, the system impact study identified the potential for a system voltage collapse
                                 based on the current configuration of the 67N-Onslow Substation (345kV).  Presently, Breaker 67N-812 is located between
                                 Line L-8002 and L-8003 and failure of this circuit breaker will result in the loss of both lines.  To avoid this contingency it is
                                 proposed to swap Line L-8003 and Transformer 67N-T82 nodes in association with the addition of Breaker 67N-816.
                                 Why do this project now?  Completing this project now will eliminate the system constraints that would be introduced if the
                                 Maritime Link project were to be completed before this work is carried out.  In addition, completing this work now will
                                 increase the power transfer capability from Onslow to Halifax (approximately 80 MW) and will minimize planned system
                                 outages for the work presently being conducted on behalf of Northeast Power Coordination Council (NPCC) and
                                 the Bulk Power System.  Completing this work in conjunction with CI 43291 67N Onslow BPS Upgrades 230kV allows
                                 NS Power to complete the work concurrently and reduce the need for an additional outage in the future.
                                                                                           References:
                                        •  Matter Number M06545 – NERC - North American Electric Reliability Corporation - Q3 2014 - November 26, 2014
                                        •  Matter Number M06525 – NSPI - Onslow 345 kV Node Swap - November 14, 2014
                                        •  Matter Number M06427 – NERC - N.A. Electric Reliability Corporation - 2015 Business Plans etc. - Sep. 17, 2014
                                        •  Matter Number M06363 – NERC - North American Electric Reliability Corporation - Q2 2014 - August 15, 2014
                                        •  Matter Number M06294 – NSPI - Protection Risk Reduction 67N-Onslow 230kV - $2,870,285 - June 25, 2014
                                        •  Matter Number M06258 – NERC - North American Electric Reliability Corporation - Q1 2014 - May 20, 2014
                                        •  Matter Number M06132 – NERC - North American Electric Reliability Corporation - Q4 2013 - February 28, 2014
                                        •  Matter Number M06011 – NERC - North American Electric Reliability Corporation - Q3 2013 - November 26, 2013
                                        •  Matter Number M05944 – NERC - N.A. Electric Reliability Corporation - 2014 Business Plans etc. - Nov. 04, 2013
                                        •  Matter Number M05862 – NERC - North American Electric Reliability Corporation - Q2 2013 - August 30, 2013
                                        •  Matter Number M05713 – NERC - North American Electric Reliability Corporation - Q1 2013 - May 31, 2013
                                        •  Matter Number M04460 – NERC - First NERC Quarterly Application...Approval...Reliability Standards... - Sep. 06, 2011
                                        •  Matter Number M04025 – NSPI - Review...Reliability of Service at NSPI - April 04, 2011
                                        •  Matter Number M03815 – NSPI - Backup Control Centre - $3,222,066 - December 24, 2010
                                        •  Matter Number M03324 – NERC - NERC Reliability Standards; and NPCC Regional Reliability Criteria - June 29, 2010
                                        •  Matter Number M01989 – NSPI - CIP Standards Implementation - $422,923 - July 22, 2009
                                        •  Matter Number M01871 – NSPI - Report to the UARB Regarding NSPI/NB Power Interconnection - June 30, 2009

   •  M06524    ENSC - Update* on Implementation of the Electricity Efficiency and Conservation Restructuring (2014) Act - November 14, 2014
                                 * This update [Exhibit E-1 in Matter Number M06524] is filed as a result of a directive from ENSC's 2015 DSM filing - M06247.
                                                      "It is further ordered that ENSC file updates with the Board regarding the implementation of the
                                                      recommendations of the Econoler and Peach reports and the internal audit reports, no later than
                                                      two weeks from the date that ENSC provides them to the DSM Advisory Group (DSMAG)...
                                 In a letter [Document Number 230686 under Matter Number M06524] to Efficiency Nova Scotia Corporation (ENSC) dated December 1, 2014,
                                 the Utility and Review Board (UARB, Board) makes the following comments:
                                                      In the section regarding development of the 2016-2018 Demand Side Management (DSM) Resource Plan
                                                      Agreement, the report – filed by ENSC on November 14, 2014 – states that ENSC and NSPI have developed
                                                      Guiding Principles [spelled out (made explicit) in Appendix B on page 19 of Exhibit E-1 in Matter Number M06524] for discussions between
                                                      the two organizations.  The Board takes note of the following shared objectives included in the Guiding Principles:
                                                     •  The 2016-2018 DSM Resource Plan application and contract submitted to the regulator are fully
                                                                   and publicly supported by Nova Scotia Power and Efficiency Nova Scotia.
                                                     •  The 2016-2018 DSM Resource Plan process develops trust amongst Nova Scotia Power,
                                                                   Efficiency Nova Scotia, the UARB and the Provincial Government and stakeholders.
                                                     •  Furthermore, the report's conclusion [page 11 of Exhibit E-1 under Matter Number M06524] states that ENSC and NSPI
                                                                   are working to ensure a smooth transition to the new electricity efficiency and conservation model,
                                                                   and that both organizations are committed to filing the 2016-2018 DSM Resource Plan agreement
                                                                   on time, with all required elements included.

   •  M06517    NSPI - Request Approval of the 2015 Annually Adjusted Rates (AARs) - November 7, 2014
                                 In assessing issues for large consumers (industrial and municipal) of electric energy which might unduly affect the
                                 integrity of the NSPI power supply system the following would be considered: reliability, voltage flicker, phase unbalance,
                                 harmonic voltage and current levels, rate of change in load levels, stability, fault levels and other related conditions.
                                                                                           References:
                                        •  Matter Number M06517 – Seven UARB Decisions - December 17, 2014
                                                                    (1) Wholesale Market Backup/Top-up Service Tariff
                                                                    (2) One Part Distribution Voltage Real Time Pricing Tariff
                                                                    (3) One Part Extra High Voltage Real Time Pricing Tariff
                                                                    (4) One Part High Voltage Real Time Pricing Tariff
                                                                    (5) Load Following (LF) of the Generation Replacement and Load Following (GRLF) Tariff
                                                                    (6) Seasonal Customer Charge for the Shore Power Tariff
                                                                    (7) Monthly Customer Charge for the Wholesale Market Non-dispatchable Supplier Spill Tariff

   •  M06514    NSPI - Application for approval... Annual Capital Expenditure Plan (ACE) for 2015  [881 pages] - November 6, 2014
                                 Nova Scotia Power Inc. - 2015 ACE Plan Application for approval of $138.7 million of its
                                              Annual Capital Expenditure (ACE Plan) - total $273.0 million
                                                                                           References:
                                        •  Matter Number M06963 – 2015 ACE Plan Stakeholder Engagement Report  [348 pages] - June 30, 2015
                                        •  Matter Number M06514 – Annual Capital Expenditure Plan (ACE) for 2015  [881 pages] - November 6, 2014
                                        •  Matter Number M06514 – Annual Capital Expenditure Plan (ACE) for 2015  - 2015 NSUARB 92 - CANLII Archive
                                        •  Matter Number M06508 – 2014 ACE Directive 5 Report...Capital Expenditure Justification Criteria - Nov. 4, 2014
                                        •  Matter Number M05998 – Annual Capital Expenditure Plan (ACE) for 2014  [853 pages] - November 21, 2013
                                        •  Matter Number M05998 – Annual Capital Expenditure Plan (ACE) for 2014  - 2014 NSUARB 91 - CANLII Archive
                                                                                     •  NSPI Responses to SBA Information Requests
                                                                                     •  Lingan Reduced Minimum Load and Two Shift Cycling Study - June 2013
                                        •  Matter Number M05844 – 2013 Annual Capital Expenditure Plan (ACE) Directive  [36 pages] - August 13, 2013
                                        •  Matter Number M05355/M04600 – 2013 Capital Expenditure Justification Criteria - NSPI - May 24, 2013
                                        •  Matter Number M05339 – Annual Capital Expenditure Plan (ACE) for 2013  [1184 pages] - November 6, 2012
                                        •  Matter Number M05339 – Annual Capital Expenditure Plan (ACE) for 2013  - 2013 NSUARB 106 - CANLII Archive
                                        •  Matter Number M04600 – Annual Capital Expenditure Plan (ACE) for 2012  [1189 pages] - November 2, 2011
                                        •  Matter Number M04600 – Annual Capital Expenditure Plan (ACE) for 2012  - 2012 NSUARB 53 - CANLII Archive
                                        •  Matter Number M03810 – Annual Capital Expenditure Plan (ACE) for 2011  [657 pages] - December 24, 2010
                                        •  Matter Number M03810 – Annual Capital Expenditure Plan (ACE) for 2011  - 2011 NSUARB 96 - CANLII Archive
                                        •  Matter Number M03339 – 2010 Annual Capital Expenditure Plan - Board Directive  [2 pages] - September 23, 2010
                                        •  Matter Number M02511 – Annual Capital Expenditure Plan (ACE) for 2010  [268 pages] - December 11, 2009
                                        •  Matter Number M02511 – Annual Capital Expenditure Plan (ACE) for 2010  - 2010 NSUARB 99 - CANLII Archive
                                        •  Matter Number M00546 – Annual Capital Expenditure Plan (ACE) for 2009  [191 pages] - December 12, 2008
                                        •  Matter Number M00546 – Annual Capital Expenditure Plan (ACE) for 2009  - 2009 NSUARB 54 - CANLII Archive
                                        •  Matter Number M00221 – Annual Capital Expenditure Plan (ACE) for 2008        UARB ???
                                        •  Matter Number M00221 – Annual Capital Expenditure Plan (ACE) for 2008  - 2008 NSUARB 86 - CANLII Archive

   •  M06508    NSPI - 2014 ACE Directive 5 Report - Capital Planning & Capital Expenditure Justification Criteria - November 4, 2014
                                 Nova Scotia Power Inc. Capital Planning & Capital Expenditure Justification Criteria
                                 Detailed Document - Annual Capital Expenditure Plan (ACE)
                                 System Design Criteria
                                                      •  [page 70] A conductor carrying a current of 325 amperes is considered to be at its load limit...

                                                      •  [page 100] The purpose of this document is to state the Nova Scotia Power Inc. planning and
                                                      development criteria to be applied to new additions to NS Power transmission system planned
                                                      or constructed after the effective date of this document...Where and when applicable, NS Power
                                                      criteria will be superseded by the Northeast Power Coordinating Council (NPCC) criteria...

                                                      •  [page 102] Primary Transmission System (defined as 230kV and above)
                                                      The protection system must be designed with redundancy to cater to any single element failure,
                                                                    in keeping with good utility practice and conform to industry standards.
                                                      Unless otherwise specified, and determined appropriate by transient stability studies, the following
                                                                    fault clearing times will be applied to the Primary Transmission system.  Any deviations
                                                                    from these criteria must be submitted to the system planning group for approval.
                                                      a. For a three phase or phase to ground fault on the local bus or on any element directly connected to
                                                                    the local bus such that it is within the instantaneous protection zone for that element...
                                                                    the fault contribution clearing time will be 4 cycles...

                                                      •  [page 104] The design criteria are:
                                                      1. From normal system conditions, the Interconnected Transmission System dynamic response shall be
                                                                    stable and positively-damped following a permanent three-phase fault on any one system element
                                                                    cleared in prime time.  No cascade tripping shall occur.
                                                      2. From normal system conditions, the Interconnected Transmission System dynamic response shall be
                                                                    stable and positively-damped following a permanent line-to-ground fault on any one system element
                                                                    cleared in prime time.  No cascade tripping shall occur.
                                                      3. From normal system conditions, the Interconnected Transmission System dynamic response shall be
                                                                    stable and positively-damped following a permanent line-to-ground fault on any one system element
                                                                    cleared in breaker back-up time.  No cascade tripping beyond elements cleared by the
                                                                    operative back-up protection shall occur...

                                                      •  [page 106] - For system power transformers, where calculations are not specifically conducted:
                                                      a. Under system normal, loading is limited to 100% of the 65°C manufacturer nameplate MVA
                                                                    for summer and 110% for winter;
                                                      b. Under contingency, the 15 minute short time rating is limited to 110% of the 65°C manufacturer
                                                                    nameplate MVA for summer and 120% for winter, provided that the system operator has
                                                                    the means to reduce the overload to system normal rating within 15 minutes...

   •  M06505    NSPI WO (Q3 2014) - 9C Aberdeen Line Tap - $834,595 - October 31, 2014
                                 This project includes the construction of a short line tap and connection of switches at the 9C substation.  Under the current
                                 transmission system configuration – existing switches on L6510 are inoperable under live line conditions – an outage is
                                 required for all customers associated with the Port Hastings substation (2C) during the operation of the switches on L6537
                                 between Port Hastings (2C) and Glen Tosh (5S), specifically Whycocomagh (67C), which includes South West Margaree (58C),
                                 Cheticamp (103C) and Baddeck (104S).  This project is required to eliminate switching outages to customers in
                                 central and northeast Cape Breton when isolating transmission lines L6537 (connects 67C Whycocomagh to L6510)
                                 and/or L6510 (connects 2C Port Hastings to 5S Glen Tosh).

   •  M06504    NSPI WO (Q3 2014) - HYD (Hydro) - Paradise Bearing Replacement (U&U) - $349,957 - October 31, 2014
                                 The Paradise generating unit, a 3.6MW unit, suffered a bearing failure in May 2014, due to the failure of bearing temperature
                                 sensors intended to shut the unit down before damage occurs.  This project will replace the damaged bearings in the
                                 Paradise generating unit as well as the temperature sensors and temperature control devices to ensure that the unit shuts
                                 down when necessary to prevent similar damage in the future.  Why do this project?  The Paradise generating unit suffered
                                 a bearing failure that caused a forced outage.  This unit is a source of renewable energy contributing to compliance with
                                 Renewable Electricity Standard targets as well as for grid stability and flexibility leading to the western end of the province.
                                 Why do this project now?  This unit is a critical unit to NS Power's electrical system.  In order to return the generating unit
                                 to service, this project must be completed now.  Why do this project this way?  Due to the failure of the bearings and
                                 temperature sensors, the only option is replacement.  Replacement of the bearings, temperature sensors and temperature
                                 control devices will prevent this type of failure in the future.  An updated control system will ensure the sensors are being
                                 read and responded to accordingly.  The bearings, temperature sensors and the control system have been replaced.

   •  M06502    NSPI WO - HYD (Hydro) - Nictaux Rotor Rewind U & U - $413,143 - October 31, 2014
                                 This project includes the rotor rewind in order to restore the insulation integrity and return the Nictaux Generating Unit to
                                 service.  The Nictaux rotor experienced vibration issues caused by magnetic imbalance in the rotor poles.  This imbalance
                                 caused a forced outage in April 2014.  A repair was made to the rotor in order to return the unit to service, but has not
                                 corrected the vibration issue, therefore a rewind is necessary.  Operating the unit with the imbalance can lead to frequent
                                 future forced outages.  Why do this project?  Nictaux Generating unit recently experienced a forced outage due to vibration
                                 issues related to a fault on the rotor.  Temporary repairs have been made to the rotor to allow the unit to be returned to
                                 service, with the risk that another forced outage was possible within the year.  Following the repair, the insulation resistance
                                 value was well below the recommended value as per the IEEE 43-2000 standard.  The rotor needs to be rewound to
                                 restore the insulation resistance value.  Why do this project now?  The repair made to the damaged rotor pole is a
                                 temporary solution.  The plant has a scheduled outage this year for a pipeline replacement.  Therefore, rewinding the
                                 rotor during this planned outage would not result in any additional lost generation.  The longer the rotor is in service with
                                 poor ground insulation the greater the chance of a forced outage.  As of 2015, generation from NS Power's legacy
                                 hydro facilities will qualify under the provisions of the Nova Scotia Renewable Electricity Regulations. Generation
                                 from hydro facilities is an important part of NS Power's compliance plan to serve 25 percent of sales from
                                 qualifying renewable generation sources.  Why do this project this way?  Having the rotor rewound will extend the life
                                 of the generator and improve its reliability.  Completing this work during a scheduled outage will reduce the amount of lost
                                 generation due to forced spill from the headpond.  The other alternatives are to continue operations with the temporary
                                 repair in place, which is shown in the Economic Analysis Model to be a less economic alternative – or to replace* the rotor
                                 entirely.  This alternative is a much more costly option and not considered necessary at this time.
                                 * Note: Here we have an example of a Low Probability High Consequence Event.  This rotor, manufactured in 1954, is an expensive special design,
                                           to meet the unusual overspeed strength required by the omission of a surge tank at this hydroelectric plant.  The lack of a surge tank requires the
                                           governor to be adjusted to shut off the water flow to the turbine markedly slower than usual.  In the case of a full-load trip of the generator circuit breaker
                                           (Low Probability), the slow movement of the governor to close the wicket gates means that the generator rotor reaches a much higher maximum rotational
                                           speed (possible High Consequence if the rotor disintegrates) than would normally occur in a hydroelectric plant equipped with a surge tank.  Why was the
                                           surge tank omitted?  The site geography, with its long gradual downhill slope, makes any effective surge tank design far too expensive.


   •  M06501    NSPI WO (Q3 2014) - IT Windows Server 2003 Upgrade P & A - $2,242,271 - October 31, 2014
                                 This project will involve the procurement of all required hardware, software and migration tasks to upgrade Windows Server 2003
                                 to Windows Server 2012.  In cases where current applications are not supported by 2012, an upgrade to 2008 will occur. 
                                 Microsoft is discontinuing support of its Windows Server 2003 Operating System (OS) on July 14, 2015.  Microsoft will no longer
                                 provide any patches or security updates beyond this date, putting NS Power servers using this OS and the applications on these
                                 servers at a security risk.  Any new security threats will not be addressed by Microsoft.  Why do this project?  Microsoft has
                                 announced that Windows Server 2003 Operating System (WIN2003) has reached the end of its supported life and is being
                                 decommissioned by July 14, 2015.  After this date, NS Power will no longer receive security and functionality patches that allow
                                 the WIN2003 servers to work with other applications and protect it from new viruses and malware.  In order to mitigate these risks,
                                 this server upgrade must be completed prior to July 2015.  Why do this project now?  The migration from WIN2003 is necessary
                                 because Microsoft is no longer supporting WIN2003 after July 2015.  Running WIN2003 after July 2015 will expose NS Power to
                                 security risks from viruses and malware.  At the time of the Annual Capital Expenditure Plan (ACE) 2014 submission, this work
                                 was expected to be completed in early 2015 in order to meet the July 2015 deadline.  Further evaluation showed the scope of the
                                 project to be greater than expected and required the project to begin in 2014.  Why do this project now?  The migration from
                                 WIN2003 is necessary because Microsoft is no longer supporting WIN2003 after July 2015.  Running WIN2003 after July 2015
                                 will expose NS Power to security risks from viruses and malware.  At the time of ACE 2014 submission, this work was expected
                                 to be completed in early 2015 in order to meet the July 2015 deadline.  Further evaluation showed the scope of the project to be
                                 greater than expected and required the project to begin in 2014.

   •  M06500    Efficiency Nova Scotia Q3 DSM Report - October 31, 2014

   •  M06499    Lunenburg Electric Utility - Request approval of Capital Expenditure and Board Opinion - 2014/15 Capital Budget - October 27, 2014

                                        Maritime Link across Cabot Strait       500 MW        670 000 horsepower
   •  M06477    NSPML - Nova Scotia Power Maritime Link Inc. - NSPML 2014 Q3 Quarterly Report - October 15, 2014
                                 — This [Exhibit N-1 in Matter Number M06477] is the Q3 2014 Quarterly Report for the Maritime Link as directed by the UARB.
                                 1.0 Introduction
                                 2.0 Update of Project Schedule...
                                            2.1 Gates and Milestones
                                            2.2 Commercial Activities
                                                   2.2.1 Land Access Agreements
                                                   2.2.2 Funding
                                                   2.2.3 Joint Development Agreements
                                            2.3 Engineering Activities
                                            2.4 Submarine Cables (Marine)
                                            2.5 Horizontal Directional Drilling (HDD) Boreholes (NS and NL)
                                            2.6 Converter Stations
                                            2.7 Right of Way Clearing Contractor(s) – Transmission Lines
                                            2.8 Construction Contractor(s) – Transmission Lines
                                            2.9 Construction Contractor(s) – Site Preparation
                                            2.10 Construction Contractor(s) – Other (including Grounding Sites in NS and NL)
                                 3.0 Updated Cost Summary

This is the Q3 2014 quarterly report for the Maritime Link as directed by the UARB...
In this reporting period, a significant contracting achievement was reached with the
execution  of the  ABB contract on 26 June 2014 for the  design,  construction  and
commissioning  of the  converters  and  substations.   This  is  the  largest  contract
within  this  project...  Work  to  achieve  agreements  with  remaining  land  owners
continues to be a priority with all DC Line and Grounding Line land rights forecasted
to be secured by year-end in both provinces.  Rights associated with Access Trails
are anticipated  to  continue  to be pursued into 2015 as necessary... For the months
of June, July and August 2014,  NSPML  submitted  Maritime Link (MLP) Construction
Reports for the Independent Engineer's (IE) review. The IE reviewed technical aspects
of  the  MLP,  including  engineering,  construction  and  other  required  due  diligence
to confirm that Project execution plans are commercially reasonable, progressing in a
satisfactory manner in  accordance with the terms of the applicable Material Project
Documents of the ML Credit Agreement and consistent with Good Utility Practice...

                                                                                           References:
                                        •  Matter Number M06592 – NSPML - Maritime Link 2014 Q4 Quarterly Report - December 15, 2014
                                        •  Matter Number M06477 – NSPML - Maritime Link 2014 Q3 Quarterly Report - October 15, 2014
                                        •  Matter Number M06280 – NSPML - Maritime Link - 2013 Affiliate Code of Conduct Annual Report - June 13, 2014
                                        •  Matter Number M06279 – NSPML - Maritime Link 2014 Q2 Quarterly Report - June 13, 2014
                                        •  Matter Number M06191 – NSPML - Maritime Link 2014 Q1 Quarterly Report - April 15, 2014
                                        •  Matter Number M06024 – NSPML - Maritime Link 2013 Q4 Quarterly Report - December 13, 2013
                                        •  Matter Number M05419 – NSPML - Application for approval of the Maritime Link Project... - January 28, 2013

   •  M06475    NSPI - Fuel Costs Deferral Hearing - October 23, 2014
                                                                                           Reference:
                                        •  Matter Number M06475 – UARB Decision - Deferral of Fuel Costs - November 25, 2014

   •  M06453    Efficiency Nova Scotia Corporation - 2014 Rate and Bill Impact Analysis - Octber 1, 2014

   •  M06447    NSPI - NERC Bulk Electric System (BES) Definition Project Plan - September 30, 2014
                                 –  On November 18, 2010 FERC issued Order 743 and directed NERC to revise the definition of Bulk Electric System
                                 so that the definition encompasses all Elements and Facilities necessary for the reliable operation and planning of
                                 the interconnected bulk power system.  Phase One of Project 2010-17 Definition of Bulk Electric System concluded
                                 on November 21, 2011 with stakeholder approval of a revised definition of Bulk Electric System and application form
                                 titled ‘Detailed Information to Support an Exception Request’ referenced in the Rules of Procedure Exception Process. 
                                 The revised definition, modifications to the Rules of Procedure to provide a process for determining exceptions to the
                                 definition, and an application form to support that process, will all be presented to the NERC Board of Trustees for
                                 adoption and then filed with regulatory authorities for approval.
                                 –  Per the FERC order granting extension, Registered Entities are to apply the definition of Bulk Electric System
                                 to their asset inventory beginning July 1, 2014 and utilize a 24 month implementation period to effect an orderly
                                 transition where all Elements and Facilities necessary for the reliable operation and planning of the interconnected
                                 bulk power system are included in the Bulk Electric System by July 1, 2016.
                                 –  NS Power proposes to file by June 15, 2015 an Application to the Utility and Review Board for approval of the following:
                                        •  The proposed Nova Scotia Bulk Electric System Exception Procedure;
                                        •  The proposed BES Exception Request form;
                                        •  A list of NS Power BES definition exceptions;
                                        •  BES Exception Request forms for each exception on the list above; and
                                        •  A draft plan to address compliance gaps not being addressed by the Exception Procedure.
                                 NS Power notes that the revised BES definition remains under review in a number of Canadian jurisdictions,
                                 while others have adopted province-specific exception processes.  Given this, the Company submits that the
                                 schedule and approach proposed in this submission remain aligned with other Canadian jurisdictions.
                                                                                           References:
                                        •  NERC Proposed Definition of Bulk Electric System
                                        •  FERC Order No. 743 - Revision to ERO Definition of Bulk Electric System  November 18, 2010
                                        •  FERC Order No. 743-A - Order on Rehearing  March 17, 2011
                                        •  FERC Order Granting Extension of Time on BES  June 13, 2013
                                        •  FERC Order Approving Revised Definition  March 20, 2014
                                        •  (U.S.) National Law Review FERC Adopts Revisions to Bulk Electric System Definition  March 26, 2014

   •  M06427    NERC - North American Electric Reliability Corporation - 2015 Business Plan and Budget and 2015 Business Plans
                                 and Budgets of Regional Entities and of Proposed Assessments to Fund Budgets - Sepember 17, 2014
                                                                                           References:
                                        •  Matter Number M06545 – NERC - North American Electric Reliability Corporation - Q3 2014 - November 26, 2014
                                        •  Matter Number M06525 – NSPI - Onslow 345 kV Node Swap - November 14, 2014
                                        •  Matter Number M06427 – NERC - N.A. Electric Reliability Corporation - 2015 Business Plans etc. - Sep. 17, 2014
                                        •  Matter Number M06363 – NERC - North American Electric Reliability Corporation - Q2 2014 - August 15, 2014
                                        •  Matter Number M06294 – NSPI - Protection Risk Reduction 67N-Onslow 230kV - $2,870,285 - June 25, 2014
                                        •  Matter Number M06258 – NERC - North American Electric Reliability Corporation - Q1 2014 - May 20, 2014
                                        •  Matter Number M06132 – NERC - North American Electric Reliability Corporation - Q4 2013 - February 28, 2014
                                        •  Matter Number M06011 – NERC - North American Electric Reliability Corporation - Q3 2013 - November 26, 2013
                                        •  Matter Number M05944 – NERC - N.A. Electric Reliability Corporation - 2014 Business Plans etc. - Nov. 04, 2013
                                        •  Matter Number M05862 – NERC - North American Electric Reliability Corporation - Q2 2013 - August 30, 2013
                                        •  Matter Number M05713 – NERC - North American Electric Reliability Corporation - Q1 2013 - May 31, 2013
                                        •  Matter Number M04460 – NERC - First NERC Quarterly Application...Approval...Reliability Standards... - Sep. 06, 2011
                                        •  Matter Number M04025 – NSPI - Review...Reliability of Service at NSPI - April 04, 2011
                                        •  Matter Number M03815 – NSPI - Backup Control Centre - $3,222,066 - December 24, 2010
                                        •  Matter Number M03324 – NERC - NERC Reliability Standards; and NPCC Regional Reliability Criteria - June 29, 2010
                                        •  Matter Number M01989 – NSPI - CIP Standards Implementation - $422,923 - July 22, 2009
                                        •  Matter Number M01871 – NSPI - Report to the UARB Regarding NSPI/NB Power Interconnection - June 30, 2009

   •  M06406    NSPI - Emergency Services Restoration Plan (ESRP) - 2014 Drill Report - September 2, 2014
                                 On July 16, 2014 the UARB initiated a formal review of NS Power's response to Post-Tropical Storm Arthur.  As part
                                 of the formal requirements of that review process, NS Power submitted a report on the event on August 19, 2014. 
                                 The report provides, amongst other items, a detailed description of Nova Scotia Power's Emergency Operations Centre
                                 activities during the event as well as the current Emergency Services Restoration Plan (ESRP) (Appendix 3.01)
                                        — Letter from UARB to NSPI, dated September 3, 2014 (evidence in Matter Number M06406)
                                        2014 ESRP Report considered filed as [Exhibit A-2 in Matter Number M06321]
                                        Emergency Service Restoration Plan (ESRP) beginning on page 6 of Appendix 3.01 in M06321
                                                                                           References:
                                        •  Matter Number M07053 – NSPI - Emergency Services Restoration Plan (ESRP) - 2015 Drill Report - Aug. 31, 2015
                                        •  Matter Number M06406 – NSPI - Emergency Services Restoration Plan (ESRP) - 2014 Drill Report - Sep. 2, 2014
                                        •  Post-Tropical Storm Arthur - Review of NS Power's Storm Response  eight items - August 2014 to May 2015
                                        •  Matter Number M06321 – 2014 NSUARB 163 - Decision: NSPI...Response to Storm Arthur - October 6, 2014
                                        •  Matter Number M06321 – UARB Review: Widespread Power Outages - Storm Arthur: July 5, 2014
                                        •  Matter Number M05943 – NSPI - 2013 ESRP - Level 3 & 4 Response - October 30, 2013
                                        •  Matter Number M05861 – NSPI - Emergency Services Restoration Plan (ESRP) - 2013 Drill Report - August 30, 2013
                                        •  Matter Number M05155 – NSPI - Revised ESRP - Level 3 & 4 Response and 2012 Drill Report - August 31, 2012
                                        •  Matter Number M04440 – NSPI - Revised ESRP - Level 3 & 4 Response - Rev. 1.7 & 2011 Drill Report - Aug. 31, 2011
                                        •  Matter Number M02140 – NSPI - Revised ESRP and 2009 Drill Report - August 31, 2009

   •  M06404    Berwick Electric Utility - request for Interim Rate - August 29, 2014
                                                                                          Reference:
                                        •  Matter Number M06404 – Berwick Electric Commission (Re), 2014 NSUARB 146 (CanLII)    September 9, 2014

 
M00000-M00999    M01000-M01999    M02000-M02999    M03000-M03999    M04000-M04999
M05000-M05499    M05500-M05999    M06000-M06199    M06200-M06399
M06400-M06599    M06600-M06799    M06800-M06999    M07000-M07199


In the “Electricity” section of the UARB website
Matter Numbers M06200 to M06399

      Matter
    Number


   •  M06395    Efficiency Nova Scotia 2014 Q2 Demand Side Management (DSM) Report - August 27, 2014
                                 For the period April 1 to June 30, 2014
                                                                                           References:
                                        •  Matter Number M06395 – Efficiency Nova Scotia Corp. - 2014 Q2 DSM Quarterly Report
                                        •  Matter Number M06248 – Efficiency Nova Scotia Corp. - 2014 Q1 DSM Quarterly Report
                                        •  Matter Number M05956 – Efficiency Nova Scotia Corp. - 2013 Q3 DSM Quarterly Report
                                        •  Matter Number M05904 – Efficiency Nova Scotia Corp. - Various 2012 and 2013 Reports

   •  M06363    NERC - North American Electric Reliability Corporation - Q2 2014 - Application...Approval of Reliability Standards - August 15, 2014
                                 Some or all of NERC's Reliability Standards are mandatory in the Canadian provinces of Alberta, British Columbia, Manitoba,
                                 New Brunswick, Nova Scotia [boldface emphasis added], Ontario, Quebec, and Saskatchewan.
                                                                                           References:
                                        •  Matter Number M06525 – NSPI - Onslow 345 kV Node Swap - November 14, 2014
                                        •  Matter Number M06427 – NERC - N.A. Electric Reliability Corporation - 2015 Business Plans etc. - Sep. 17, 2014
                                        •  Matter Number M06363 – NERC - North American Electric Reliability Corporation - Q2 2014 - August 15, 2014
                                        •  Matter Number M06294 – NSPI - Protection Risk Reduction 67N-Onslow 230kV - $2,870,285 - June 25, 2014
                                        •  Matter Number M06258 – NERC - North American Electric Reliability Corporation - Q1 2014 - May 20, 2014
                                        •  Matter Number M06132 – NERC - North American Electric Reliability Corporation - Q4 2013 - February 28, 2014
                                        •  Matter Number M06011 – NERC - North American Electric Reliability Corporation - Q3 2013 - November 26, 2013
                                        •  Matter Number M05944 – NERC - N.A. Electric Reliability Corporation - 2014 Business Plans etc. - Nov. 04, 2013
                                        •  Matter Number M05862 – NERC - North American Electric Reliability Corporation - Q2 2013 - August 30, 2013
                                        •  Matter Number M05713 – NERC - North American Electric Reliability Corporation - Q1 2013 - May 31, 2013
                                        •  Matter Number M04460 – NERC - First NERC Quarterly Application...Approval...Reliability Standards... - Sep. 06, 2011
                                        •  Matter Number M04025 – NSPI - Review...Reliability of Service at NSPI - April 04, 2011
                                        •  Matter Number M03815 – NSPI - Backup Control Centre - $3,222,066 - December 24, 2010
                                        •  Matter Number M03324 – NERC - NERC Reliability Standards; and NPCC Regional Reliability Criteria - June 29, 2010
                                        •  Matter Number M01989 – NSPI - CIP Standards Implementation - $422,923 - July 22, 2009
                                        •  Matter Number M01871 – NSPI - Report to the UARB Regarding NSPI/NB Power Interconnection - June 30, 2009

   •  M06352    NSPI WO - 2012 Off Road to Roadside - $1,381,102 - July 31, 2014
                                 This project is planned to relocate approximately 25 km of distribution line from off road to the roadside in various
                                 locations throughout the province.  The following locations are included in the scope for this project:
                                              – 607N-301 G Advocate Hospital - 750m
                                              – 73W-41 1 Upper Branch Rd/Wagner Rd - 3.15 km
                                              – 57C-426 Country Harbour Phase 3 - 1.5 km
                                              – 58C-405 Margaree Forks - 4.5 km
                                              – 100C-21 Cape Porcupine Phase 2 - 3 km 590C-300 Route 4 - 5 km
                                              – 57C-426 Goldboro Phase 4 - 5 km 4C-432 St. Andrews - 2 km
                                 This project will provide improved access to distribution circuits which are currently located in off road rights of way.
                                 Providing easier access to the distribution lines will reduce the time to identify the location of the fault during outage
                                 events improving the reliability of these feeder sections.  Having the distribution line road side also makes the regular
                                 maintenance activities more cost effective.  Why do this project?  Relocating off road sections to the roadside
                                 improves access to the distribution plant and reduces the restoration time during outage events.  The Build-to-Roadside
                                 program is a multi-year program to move off road distribution lines to roadside.  The program is part of the overall
                                 customer reliability investment.  A list of lines with off-road sections that should be moved to roadside was developed
                                 to form the individual projects within this program.  As detailed scoping is completed on a line, including obtaining
                                 NS Power easements, Aliant easements, necessary permits and other documentation, these projects are brought
                                 forward for execution.

   •  M06351    NSPI WO - HYD (Hydro) - Tusket #2 Overhaul - $1,116,199 - July 31, 2014
                                 The Tusket powerhouse was put into service in 1929 and much of the equipment is original.  Annual preventative
                                 maintenance activities on Unit #2 in October 2010 indicated excessive wicket gate and runner tolerances, and
                                 indications of cracking.  The unit was returned to service until interference between the operating ring and wicket
                                 gates prompted it to be taken out of service in May 2011.  A detailed condition assessment of the mechanical
                                 components was undertaken to accurately determine what work is required to return Unit #2 to service.  Work to
                                 be undertaken in this project will correct the following deficiencies: warped operating ring, bushing and linkage
                                 tolerances, runner replacement and blade hub refurbishment.  The damage to the blades is such that they are not
                                 repairable.  To return the unit to service, the turbine blades must be replaced.  Tusket Unit #2 has been inoperable
                                 since May 2011.  Since the unit was taken out of service, water has been spilling around this unit.  For every cubic
                                 metre of water "spilled" a specific amount of electrical energy (kWh) is lost, and must be replaced by burning fuel
                                 in a thermal generating plant.  Detailed condition assessment, scoping and resourcing efforts have been completed,
                                 and replacement blades have been procured.  The blades are a long-lead item, and NS Power is now prepared to
                                 complete this work and return the unit to service in 2014.

   •  M06350    NSPI WO - TRE (Trenton) #5 5-1 Pulveriser Refurbishment (Q2 2014) - $576,305 - July 31, 2014
                                 This project consists of a full rebuild of the pulverizer at Trenton 5.  Unit #5 at the Trenton Generating Station utilizes four
                                 Babcock & Wilcox EL-70 Coal Pulverizers to prepare the coal for combustion in the boiler.  These mills were originally
                                 installed and commissioned in 1969 and since this time have been subjected to continuous use, with the exception of
                                 shutdowns.  This project was included in the 2012 ACE Plan at $171k (under $250k).  This project was deferred until
                                 2014 when the 5-1 pulverizer was scheduled for a routine overhaul of the grinding element zone, including replacement
                                 of the actual grinding elements.  As this mill is of a similar vintage to the 5-2 and 5-4 pulverizers which both required a
                                 major rebuild including shaft replacements in 2013, it was decided to perform some additional testing and inspection of
                                 the shaft while offline.  Furthermore, after ACE 2014 submission, oil analysis indicated elevated levels of lead, which
                                 suggests bearing damage.  This required additional investigation.  During the inspection of the main shaft, damage to the
                                 top bearing and shaft was found.  The damage was sufficient to require the removal of the top bearing and shaft, which
                                 equires a full disassembly of the pulverizer.  Given the previous history with 5-2 and 5-4 pulverizers in 2013, along with
                                 the fact that the shaft in 5-1 pulverizer is of original vintage, it was decided that a full rebuild of the pulverizer was required
                                 to ensure the reliable operation of the pulverizer.  This project is required so that the 5-1 pulverizer mill, one of four such
                                 mills in operation on Trenton Unit 5, can be returned to service.  Without the mill in operation, Trenton Unit 5 runs de-rated
                                 by 40 MW.  This project was included in the 2012 ACE Plan at $171k.  The increase from $145k to $576,305 is primarily
                                 due to labour and material increases as a result of further investigation per the description above.

   •  M06349    NSPI WO - HYD Unforeseen and Unbudgeted (U&U) WRC (Wreck Cove) Unit 1 Stator Repair - $366,027 - July 31, 2014
                                 During a unit condition assessment in the fall of 2013, a high voltage test revealed a stator bar insulation failure.  This
                                 required an immediate repair to the stator in order to bring the unit back into service.  This repair was completed in the
                                 fall of 2013 under a preliminary engineering project, which at the time was thought could lead to more extensive capital
                                 investment in Unit #1.  The stator repair was originally thought to be a part of this larger investment, which through further
                                 assessment and investigation will be completed as part of the major Wreck Cove Unit Overhauls currently estimated to
                                 be completed in 2018/2019.  With the stator repairs being the sole capital investment at this time, it is being brought
                                 forward as a U&U.  The project included purchase and installation of a stator bar set.  NS Power reached out to multiple
                                 vendors for these materials.  However, the Original Equipment Manufacturer (OEM) was the only provider who could
                                 deliver the materials in the required timeframe.  Why do it this way?  Repairing the stator winding is a much lower-cost
                                 (and much faster) solution than replacing the stator of a large hydroelectric generator.  The repair was done while the
                                 unit was disassembled and the most expedient and simple repair was undertaken.  Generator repairs are specialized
                                 and needed to be conducted by outside experts.

   •  M06348    NSPI WO - LIN (Lingan) U&U Heavy Fuel Oil Recirculation Line Refurbishment - $1,304,395 - July 31, 2014
                                 The heavy oil tank stores Bunker C oil for secondary supplemental fuel for the four units at Lingan.  When this fuel oil
                                 is being used during the colder months, it travels to the plant through the main oil line where some of it is burned in the
                                 boilers and the remainder is pumped back through the recirculation line.  Before the oil travels back to the storage tank,
                                 it is heated through an in-plant heat exchanger.  The heated heavy oil then travels back to the storage tank to mix with
                                 the rest of the oil in the tank.  This process keeps the oil warm, making it more fluid and easier to pump through the fuel
                                 supply system.  During routine operator inspections a heavy oil recirculation line leak was detected.  The pipe wall
                                 thinning was caused by external corrosion. Further inspection found thinning walls around the support saddles.  The
                                 areas around the leaks were refurbished and or replaced with new piping.  Pipe support saddles were added to regain
                                 wall thickness in the area refurbished.  All oil that leaked was cleaned up immediately.  The completion of this work
                                 enables heavy oil to be available to the plant as an economical secondary fuel.

   •  M06341    NSPI - Approval of an Open Access Transmission Tariff (OATT) - May 31, 2005
                                 By application dated and filed with the Board on May 12, 2004, NSPI requested Board approval of an Open Access
                                 Transmission Tariff (OATT).  In its application, NSPI stated that the OATT would allow third parties to use the NSPI
                                 transmission system in an open and non-discriminatory manner
, as contemplated by the Province's Energy Strategy
                                 entitled Seizing the Opportunity.  NSPI further stated that, given the policy objectives of Nova Scotia's Energy Strategy,
                                 approval of this proposed OATT will provide opportunities for NSPI, Independent Power Producers (IPP), and electric
                                 customers.  The OATT includes terms, conditions and rates for Transmission Service and Ancillary Services, service
                                 and operating agreements, and the Standards of Conduct under which service will be provided.  This also includes
                                 NSPI's submission for Standard Generator Interconnection Procedures, applicable to generating facilities connecting
                                 to NSPI's transmission system at 69 kV and above.  In addition to the Energy Strategy, on October 18, 2004, the
                                 Province's Electricity Act received Royal Assent.  This Act identified the six municipal electric utilities as "wholesale
                                 customers" which are permitted to "... purchase electricity from any competitive supplier"...

   •  M06331    Antigonish Electric Utility - request for interim approval of Schedule of Rates for Light-Emitting Diode (LED) street lighting - July 22, 2014
                                                Approved: August 6, 2014
                                 The rates for the LED street lighting service are new rates which have not been previously approved by the Board, and
                                 the Board is satisfied that the calculation of the LED street lighting rates is appropriate...
                                                                                           Reference:
                                        •  Matter Number M06331 – Antigonish Electric Utility (Re), 2014 NSUARB 132 (CanLII)     August 6, 2014

   •  M06329    Friends of Harmony/Camden, Greenfield and Surrounding Areas - July 21, 2014
                                 Re: Affinity Wind LP's Wind Turbine Development, Johnson Road, Harmony, Colchester County
                                 Re: Approval of a COMFIT wind project undertaken by Affinity Wind LP
                                 Re: Colchester County Wind Turbine Development By-law
                                                                                           References:
                                        •  Wind farm foes get green light to carry on appeal   Chronicle-Herald, Halifax - March 30, 2015
                                        •  Matter Number M06674 – 2015 NSUARB 65 - UARB Decision - March 27, 2015
                                        •  Matter Number M06673 – Appeal by Friends of Harmony/Camden/Greenfield... - January 23, 2015
                                        •  Matter Number M06329 – Friends of Harmony/Camden, Greenfield and Surrounding Areas - July 21, 2014
                                        •  Residents weigh in against turbine plan   Chronicle-Herald, Halifax - July 22, 2014
                                        •  MLA files citizens' petition in Province House over Greenfield wind turbine project concerns
                                                                The Labradorian, Happy Valley-Goose Bay - April 25, 2014
                                        •  Colchester County approves new wind turbine bylaw   The Daily News, Truro - October 30, 2013
                                        •  Open house planned for wind farm site   The Daily News, Truro - May 28, 2013
                                        •  Greenfield Wind Farm Environmental Assessment Registration  November 2013

UARB Review: Widespread Power Outages
Storm – July 5, 2014

•  M06321    Review of Nova Scotia Power Inc.'s state of preparedness and response to post-tropical storm Arthur

•  Post-Tropical Storm Arthur – Review of NS Power's Storm Response  [173 pages]  August 19, 2014
•  Section   3 - Appendices 3.01-3.31  Emergency Services Restoration Plan [290 pages]
•  Section   4 - Appendices 4.01-4.04  Level 3 Restoration [62 pages]
•  Section   5 - Appendix 5.01  Damage Assessment Timeline [20 pages]
•  Section   6 - Appendix 6.01  Detailed Transmission Events Log [7 pages]
•  Section   9 - Appendices 9.01-9.02  NS Power Annual SAIFI* and SAIDI* [8 pages]
•  Section 10 - Appendix 10.01  NSPI News Release - July 9, 2014 [3 pages]
•  Section 13 - Appendix 13.01  Davies Consulting LLC - Relevant Experience [4 pages]
                 * SAIFI - System Average Interruption Frequency Index
                 * SAIDI - System Average Interruption Duration Index

                                                                                        Also See:
•  2014 NSUARB 163 - Decision: NSPI's state of preparedness and response to post-tropical storm Arthur - Oct. 6, 2014

                                                                References:
•  2014 Jul    1 –* Mahone Bay dumps electric utility truck  Lunenburg County Progress Bulletin

•  2014 Jul    9 — Electrical fire damages home on Northwest Road  Lunenburg County Progress Bulletin
•  2014 Jul  10 — Editorial: Power outage response a failure to commun...  Chronicle-Herald, Halifax
•  2014 Jul  15 –* Lunenburg utility spared from worst of Arthur  Lunenburg County Progress Bulletin
•  2014 Jul  15 –* Town could have helped in Arthur's aftermath  Lunenburg County Progress Bulletin
•  2014 Jul  21 — Nova Scotia Power, Arthur and the review: the unasked questions  Halifax Metro
•  2014 Aug 20 — Province raps NSP on post-Arthur outages  Chronicle-Herald, Halifax
•  2014 Aug 25 — Don't trust Nova Scotia Power to fix what ails it  Halifax Metro
•  2014 Sep   4 — Arthur an eye-opener for emergency officials  Lunenburg County Progress Bulletin
•  2014 Sep   9 — Province says Nova Scotia Power must do better job communicating  Chronicle-Herald
•  2014 Sep   9 — Consultant targets NSP website, forecasting in Arthur report  Chronicle-Herald, Halifax
•  2014 Sep 16 — Emergency management learns lessons from Arthur  Lunenburg County Progress Bulletin

NOTE: The three items marked with an asterisk (above) should be read together.
They could easily be  rewritten  as  one  coherent  article  which would be relevant
in the context of an official  regulatory  review of the electric utility response to the
challenge presented by  Storm  Arthur  to Nova Scotia.  These three small electric
utility organizations – Mahone Bay, Lunenburg and Riverport – each of them with
ownership and  management  structures  completely  independent  of the others,
each many  decades  older than the large provincial multi-corporate electric utility
organization, provide an exemplary model of how local utility people can provide
an effective response much faster than the large provincial utility.  To those who
might be tempted to protest that a large utility can provide electricity at a lower
cost than a small one, one could respond that all three of these small utilities
get their electricity wholesale at the same price from the same supplier, and
are able to  finance  and  maintain  their  local  electric  distribution systems
and to sell electricity to individual residential customers at rates lower than
those paid (see below) by residential customers in the surrounding areas.

•  2004 Apr 14 — Lunenburg faces major electrical expenditure  Lunenburg County Progress Bulletin
    One of six municipally owned distributors in the province, the town is able to purchase electricity wholesale at a
    discount from Nova Scotia Power Inc. (NSPI), then resell it to its residents.  The arrangement not only sees the
    town turn a profit by selling the power at an increased price, but also allows them to offer it at a substantial saving
    compared to what regular NSPI customers are charged.  That discount ranges from 7.9% for general customers
    to 55.4% for those in the small general classification, while regular domestic customers enjoy a saving of 19.5%...


•  2004 Oct 20 — Lunenburg applies for power rate hike  Lunenburg County Progress Bulletin
    After these rate increases, both residential and commercial customers will still be paying rates
    considerably lower than those who are buying electricity directly from Nova Scotia Power...




UARB Review: Widespread Power Outages
Storm – November 13-14, 2004

Reference:
•  2005 NSUARB 86    released August 5, 2005
Public Review of the Power Outages resulting from the Storm of November 13-14, 2004
Widespread outages caused by storm...communication system failed...further action directed by UARB...

— On November 13-14, 2004, Nova Scotia was affected by an early winter storm which resulted
in power outages affecting over 160,000 of NSPI's customers.
— The November 2004 storm, in particular caused much confusion and concern among NSPI's customers.  The storm's
impacts were not felt consistently across the Province, and in many areas the impacts were typical of an ordinary winter
storm.  In light of this, these customers were confused by the extent of the damage done to NSPI's transmission and
distribution systems; which resulted in serious and lengthy outages for thousands of NSPI's customers.
— The government of the day (Premier Hamm) subsequently asked the UARB if it would undertake a review of NSPI's
preparation for and response to the early winter storm.  The UARB agreed to do so, and convened public hearings in
various locations in the Province in April and May 2005...
— The UARB found that NSPI's preparation for and implementation of communications with customers, emergency officials,
media and others during and after the storm was "a very serious and totally unacceptable failure". The UARB directed that
further action be taken...
Liberty Consulting Group (Liberty) of Quentin, Pennsylvania, independent consultants with expertise in communications and transmission
and distribution system design, observed that NSPI has numerous right-of-way issues to address, especially on its 69 kV lines.  During its aerial
assessment of the NSPI transmission system, Liberty observed that about 10 km of 69 kV line L-5532 from Digby to Big Falls routes along the road.
Side clearances on this section appeared to be less than the 10m required for its 69 kV lines located on rights-of-way.  A tree caused an outage on
this line during the November storm, and was the fifth and last interrupted transmission path to Annapolis Valley.  This falling tree caused the
interruption of all remaining load and hydro generation in the valley
.  In addition, Liberty observed other locations, particularly in the western
part of the province, where NSPI had not yet trimmed the 69 kV and 138 kV rights-of-way to full width...

References:

•  2004 Nov 24 — Editorial Comment  Lunenburg County Progress Bulletin
    "Utility CEO Chris Huskilson...apologized for the breakdown in communications..."

•  2005 May 11 — Residents criticize Nova Scotia Power at Chester hearing  Lunenburg County Progress Bulletin
    "This idea of telling your customers and the general public that the reduction in staff, particularly in linemen,
      hasn't affected your ability to respond to outages is, to be very blunt, a crock..."


•  2005 Aug 24 — Nova Scotia Power needs to communicate better...  Lunenburg County Progress Bulletin
    "The Utility and Review Board ordered NSP to improve the way it communicates with affected customers."




EMO Review: Widespread Power Outages
Storm – September 29-30, 2003

Reference:
•  A Report on the Emergency Response to Hurricane Juan, September 29-30, 2003    dated November 2003

— This storm knocked out power to 300,000 customers of Nova Scotia Power Inc (NSPI).  Devastating winds brought down
27 main transmission lines, several 120-foot transmission towers, 117 distribution feeders, and 31 major NSPI substations...
NSPI had to deal with the crippling blow dealt to its transmission and distribution systems.  As one company official put it, the
hurricane tracked along the "backbone" of NSPI's transmission system from Halifax to Truro.  In all, Juan interrupted service
to 70% of the utility's customers.  With 300,000 customers out of power throughout Halifax Regional Municipality (HRM) and
the northeastern part of the province, NSPI put together a massive effort to restore power.  Three hundred field crews were
assembled from Nova Scotia, New Brunswick, and Maine, and their work was supported by NSPI staff, EMO, municipal staff,
and 2,000 members of the armed forces.  During the recovery effort itself, NSPI's priorities included addressing safety hazards
and restoring power to crucial customers – including health institutions – identified by EMO and NSPI.  The utility reported that
it had restored power to 50% of customers by noon on Tuesday, September 30th.  By Thursday, October 2nd, 85% of the
customers who lost power were back on the grid, and by Friday, 95% were restored.  The last customers were restored after
14 days without power – on Sunday, October 12th.  Despite this recovery effort, an official from Canada's Department of
National Defence (DND) said neither HRM nor NSPI was initially well-prepared to take advantage of the soldiers and sailors
that DND provided at the request of those two agencies.  DND teams were tasked with two mandates: helping NSPI restore
power to its grid and helping facilitate the reopening of traffic lanes in HRM.  However, during the first two days after the
hurricane – September 29th and September 30th – "we found many of our teams standing by in various parts of the city
without direction and without guidance."  With 1,133 ready to hit the streets Tuesday, DND "faced a problem where we
had the manpower and it was not used very efficiently at all"... Dozens of recommendations were made, but they can be
summarized under three headings: (1) improved use of resources and people, (2) improved operational protocols,
and (3) improved communications... NSPI and other agencies directly involved in emergency response operations should
design automated telephone answering systems to provide callers with estimated hold times.  That way, callers would be
able "to get on with their lives" – as one participant said – when wait times are excessive...
— The purpose of this report is to...focus on two key topics: the breadth, scope, strengths and weaknesses of the
emergency response effort; and the lessons learned as a result of that effort...

References:

•  2003 Oct 1 — Juan to remember  Lunenburg County Progress Bulletin
          Hurricane wreaks havoc along coastal communities

•  2003 Oct 8 — Residents still cleaning up after Hurricane Juan  Lunenburg County Progress Bulletin
    At the height of the storm, 4,000 in Lunenburg County were without power but most electricity
    was restored by the evening of Tuesday, September 30th.


•  2003 Oct 8 — Food banks assisting hurricane victims  Lunenburg County Progress Bulletin




Widespread Power Outages
Storm – November 5-6, 2002

Reference:
•  2002 Nov 13 — County paralyzed by nor'easter    Lunenburg County Progress Bulletin

A powerful nor'easter blew across Lunenburg County overnight Wednesday, November 6, 2002, leaving a path of
early wintry weather and a number of South Shore communities without electricity.  The outages were the worst
Nova Scotia Power has had to cope with in ten five years.  At one point Thursday, November 7th, 100,000 people
throughout the province were without power.  By Sunday, all power had been restored.

Also see:
•  2002 Nov 13 — Privatization of NSP has brought new opportunities - Huskilson    ...Progress Bulletin




UARB Review: Widespread Power Outages
Storm – November 27-28, 1997

Reference:
•  Public Review of the Power Outages, Storm of November 27-28, 1997    released February 9, 1998
Widespread outages caused by storm...further action directed by UARB...

— In all regions, a Nova Scotia customer in 1996 who lost power could expect to be without power for a longer period
than in 1990, as indicated by the CAIDI index.
— The existing setup at the Call Centre at Scotia Square in Halifax did not seem able to handle the magnitude
of incoming calls experienced – 75,829 calls on Thursday evening, November 27, 1997 and early Friday morning.
From 8:00am Friday, November 28, to 8:00am Wednesday, December 3, 1997, the Call Centre operated on a 24 hour
basis utilizing all available personnel.  On average, 51 agents were working throughout the period at the Call Centre.
— The Nova Scotia Utility and Review Board (UARB, Board) is of the view that the reduction of lineworkers was a factor
in the duration of the outages that occurred in Nova Scotia on November 27 and 28, 1997...
— NSPI is directed to research the methods for routine inspection and maintenance being used by North American
electric utilities as related to overhead distribution system components and report back to the Board with the results of
this research and any recommendations not later than July 31, 1998. [boldface emphasis added]

Reference:
•  Matter Number M06406 – NSPI - Emergency Services Restoration Plan - 2014 Drill Report - September 2, 2014




Widespread Power Outages
Storm – September 14-15, 1996

Reference:
•  Hortense Slams Nova Scotia    September 16, 1996, Chicago Tribune

Hurricane Hortense, the first hurricane to hit the region since Blanche in 1975, roared into Nova Scotia
Saturday, September 14th, with 100mph [160 km/h] winds that peeled roofs from buildings, flooded streets
and left tens of thousands without power all night.  Power was restored to much of the province Sunday.

   •  M06319    NSPI - Rate Application 2007

   •  M06300    NSPI - NSPSO  2014-2023  10 Year System Outlook Report - June 27, 2014
                                 Section 3.4.6.1 of the Wholesale Market Rules Regulations provides: Subject to any contrary order of the Board, the
                                 Nova Scotia Power System Operator (NSPSO) shall submit the draft NSPSO system plan to the Utility and Review
                                 Board (UARB) for the Board's public comment process and for any Board review, and shall publish the draft plan each
                                 year by the end of June.  The Market Rules were issued by the Nova Scotia Department of Energy on February 1, 2007,
                                 to coincide with the proclamation of the Electricity Act which opened, on a limited basis, the Nova Scotia electricity market
                                 to wholesale competition.
                                             – On behalf of the NSPSO, the 2014 10 Year System Outlook is attached for the Board's review.  Concurrent
                                             with this filing, NSPI will post this report on the Forecasts and Assessments section of the NSPSO OASIS site.
                                                                                           References:
                                        •  Matter Number M06966 – Nova Scotia Power Inc. - NSPSO  2015-2024  10 Year System Outlook Report
                                        •  Matter Number M06300 – Nova Scotia Power Inc. - NSPSO  2014-2023  10 Year System Outlook Report
                                        •  Matter Number M05775 – Nova Scotia Power Inc. - NSPSO  2013-2022  10 Year System Outlook Report
                                        •  Matter Number M05061 – Nova Scotia Power Inc. - NSPSO  2012-2021  10 Year System Outlook Report
                                        •  Matter Number M04250 – Nova Scotia Power Inc. - NSPSO  2011-2020  10 Year System Outlook Report
                                        •  Matter Number M03347 – Nova Scotia Power Inc. - NSPSO  2010-2019  10 Year System Outlook Report
                                        •  Matter Number M01870 – Nova Scotia Power Inc. - NSPSO  2009-2018  10 Year System Outlook Report
                                                                                  •  Nova Scotia Power Inc. - NSPSO  2008-2017  10 Year System Outlook Report

   •  M06294    NSPI WO - Protection Risk Reduction 67N-Onslow 230KV - $2,870,285 - June 25, 2014
                                 This project provides the costs to upgrade the protection system at 67N-Onslow (230kV) to comply with Northeast
                                 Power Coordination Council (NPCC) bulk power system protection risk reduction plan.  On August 30, 2010 NPCC
                                 requested a Mitigation Plan for Bulk Power System (BPS) facilities that lack a second set of protective relays on a
                                 BPS element and/or a second battery at a BPS substation.  The substation at Onslow lacks these requirements.
                                 Implementation of all redundant protection and second battery is required to be completed by end of 2016.
                                 NS Power had four stations requiring this upgrade.  Because this work is significant, NSPI has chosen to complete
                                 the four stations requiring this upgrade over the next three year period.  NS Power is planning to complete
                                 120H-Brushy Hill 230kV by end of 2014, 67N-Onslow to be completed in early 2015, 3C-Port Hastings to be
                                 completed by end of 2015 and 88S-Lingan by the end of 2016.
                                                                                           References:
                                        •  Matter Number M06427 – NERC - N.A. Electric Reliability Corporation - 2015 Business Plans etc. - Sep. 17, 2014
                                        •  Matter Number M06363 – NERC - North American Electric Reliability Corporation - Q2 2014 - August 15, 2014
                                        •  Matter Number M06294 – NSPI - Protection Risk Reduction 67N-Onslow 230kV - $2,870,285 - June 25, 2014
                                        •  Matter Number M06258 – NERC - North American Electric Reliability Corporation - Q1 2014 - May 20, 2014
                                        •  Matter Number M06133 – NSPSO - NS Power System Operator 2013 Wholesale Market Report - March 3, 2014
                                        •  Matter Number M06132 – NERC - North American Electric Reliability Corporation - Q4 2013 - February 28, 2014
                                        •  Matter Number M06011 – NERC - North American Electric Reliability Corporation - Q3 2013 - November 26, 2013
                                        •  Matter Number M05944 – NERC - N.A. Electric Reliability Corporation - 2014 Business Plans etc. - Nov. 04, 2013
                                        •  Matter Number M05862 – NERC - North American Electric Reliability Corporation - Q2 2013 - August 30, 2013
                                        •  Matter Number M05713 – NERC - North American Electric Reliability Corporation - Q1 2013 - May 31, 2013
                                        •  Matter Number M04460 – NERC - First NERC Quarterly Application...Approval...Reliability Standards... - Sep. 06, 2011
                                        •  Matter Number M04025 – NSPI - Review...Reliability of Service at NSPI - April 04, 2011
                                        •  Matter Number M03815 – NSPI - Backup Control Centre - $3,222,066 - December 24, 2010
                                        •  Matter Number M03324 – NERC - NERC Reliability Standards; and NPCC Regional Reliability Criteria - June 29, 2010
                                        •  Matter Number M01989 – NSPI - CIP Standards Implementation - $422,923 - July 22, 2009
                                        •  Matter Number M01871 – NSPI - Report to the UARB Regarding NSPI/NB Power Interconnection - June 30, 2009

   •  M06293    Antigonish Electric Utility - Purchase of New Utility Bucket Truck - June 24.2014

   •  M06290    Nova Scotia Power Inc. - Fuel Adjustment Mechanism (FAM) 2012/2013 Audit - July 2, 2014
                                        — 2015 NSUARB 9 - UARB Decision [64 pages] - January 20, 2015
                                        The overall objective of the FAM audit will be to examine operational and managerial aspects of
                                        the fuel and energy procurement, management, and production functions and activities of NSPI...
                                        The standard for determining prudency of a utility's fuel procurement practices is well established. As stated
                                        by the Illinois Commerce Commission, "prudence is that standard of care which a reasonable person would
                                        be expected to exercise under the same circumstances encountered by utility management at the time decisions
                                        had to be made... Hindsight is not applied in assessing prudence... A utility's decision is prudent if it was within
                                        the range of decisions reasonable persons might have made... The purpose of the FAM Audit is to ensure that
                                        all fuel related costs passed on to ratepayers were prudently incurred... The Board orders that all costs related
                                        to the Sydney Harbour dredging be removed from the FAM expenses... The Board concludes that NSPI bears
                                        responsibility for imprudence related to the Trenton 5 incident.  NSPI is directed to ensure that such future events
                                        be subjected to a more robust analysis of management's influence and responsibility related to the event...
                                        The determination of a precise cost of replacement energy during the prolonged outage was not possible,
                                        primarily attributed to a lack of data being collected by NSPI during periods of uneconomic generation.  In order
                                        to avoid experiencing similar difficulties in the future, NSPI is directed to collaborate with Liberty to develop and
                                        implement a suitable data collection process.  NSPI is to file a report by March 31, 2015...
                                        — This Decision includes the Board's findings relative to the FAM Audit.
                                        — The FAM Audit results in a disallowance of $5,142,500, plus carrying charges.
                                             NSPI is to calculate and provide the assignment of carrying charges in its Compliance Filing.
                                                                                           References:
                                                          The following transcripts are provided for convenience of the parties and the public:
                                        •  Matter Number M06290 – NSPI - A Hearing into NSPI's FAM Audit for 2012 and 2013  [307 pages] - October 27, 2014
                                        •  Matter Number M06290 – NSPI - A Hearing into NSPI's FAM Audit for 2012 and 2013  [163 pages] - Part A - Oct. 28, 2014
                                        •  Matter Number M06290 – NSPI - A Hearing into NSPI's FAM Audit for 2012 and 2013    [13 pages] - Part B - Oct. 28, 2014
                                                                                           Also See:
                                        •  Trenton Unit No. 5 - Root Cause Analysis Report - REDACTED [Exhibit N-22 in Matter Number M06290]  [43 pages] - No Date

   •  M06280    Nova Scotia Power Maritime Link Inc. - 2013 Affiliate Code of Conduct Annual Report - June 13, 2014

                                        Maritime Link across Cabot Strait       500 MW        670 000 horsepower
   •  M06279    NSPML - Nova Scotia Power Maritime Link Inc. - NSPML 2014 Q2 Quarterly Report - June 13, 2014
                                 — This [Exhibit N-1 in Matter Number M06279] is the Q2 2014 Quarterly Report for the Maritime Link as directed by the UARB.
                                 1.0 Introduction
                                 2.0 Update of Project Schedule...
                                            2.1 Gates and Milestones
                                            2.2 Commercial Activities
                                                   2.2.1 Land Access Agreements
                                                   2.2.2 Funding – Schedule Reserve and Allowances
                                                   2.2.3 Joint Development Agreements
                                            2.3 Engineering Activities
                                            2.4 Submarine Cables (Marine)
                                            2.5 Converter Stations
                                            2.6 Tree Clearing Contractor – Transmission Lines
                                            2.7 Construction Contractor – Transmission Lines
                                            2.8 Construction Contractor(s) – Other
                                 3.0 Updated Cost Summary
                                                                                           References:
                                        •  Matter Number M06477 – NSPML - Maritime Link 2014 Q3 Quarterly Report - October 15, 2014
                                        •  Matter Number M06279 – NSPML - Maritime Link 2014 Q2 Quarterly Report - June 13, 2014
                                        •  Matter Number M06191 – NSPML - Maritime Link 2014 Q1 Quarterly Report - April 15, 2014
                                        •  Matter Number M06024 – NSPML - Maritime Link 2013 Q4 Quarterly Report - December 13, 2013
                                        •  Matter Number M05419 – NSPML - Application for approval of the Maritime Link Project... - January 28, 2013

   •  M06277    Nova Scotia Power Inc. - Small General and General Tariff Revisions Application 2014 - June 12, 2014
                                 During the 2012 General Rate Application, Leanne Hachey, then Vice-President, Atlantic, of the Canadian Federation
                                 of Independent Business (CFIB), requested that the Board re-examine whether the demand threshold of 32,000 kWh
                                 per year between the Small General and General rate classes was still appropriate.  Currently, there are approximately
                                 24,000 customers in the Small General Class and 11,500 customers in the General Class.  The CFIB had suggested
                                 that the demand threshold should be set at 50 kW.  NS Power performed a bill simulation analysis for this threshold.
                                 Using billing data from 2012, NS Power determined that the majority of General customers at this demand level
                                 consumed energy in the range from 100 MWh to 200 MWh per year.  The analysis showed that, absent a change in
                                 rates, if a 50 kW threshold were to be used, about 80 percent of General customers would drop to the Small General
                                 rate class; more than half of them would pay more for electricity, and NS Power revenues would increase by $2.9 million.
                                 NS Power also modeled changing the demand threshold to 40,000, 50,000 and 60,000 kWh...
                                                                                           References:
                                        •  Matter Number M06277 – Nova Scotia Power Incorporated (Re), 2014 NSUARB 123 (CanLII)    July 29, 2014
                                        •  Matter Number M06277 – Small General and General Tariff Revisions    June 12, 2014

   •  M06274    NSPI - Sale of LED Streetlights to Municipalities - Pre-approval Request - June 5, 2014
                                 Pursuant to the regulations made under the Energy-Efficient Appliances Act, municipalities are entitled to take
                                 ownership of their own non-high mast roadway lights from NS Power.  Municipalities were required to inform
                                 NS Power of their intention to do so by June 30, 2013, and identify the lights by location.  The Energy-Efficient
                                 Appliances Act also requires conversion of all roadway lights in the Province to Light Emitting Diode (LED)
                                 streetlights.  NS Power is in the final stages of completing a capital work order for the Board's consideration
                                 for the acquisition of LED streetlights to replace its existing Mercury Vapour, Low Pressure Sodium and
                                 High Pressure Sodium streetlights.  Seventeen municipalities, of the 58 to which NS Power currently provides
                                 full streetlight service, have informed NS Power that they will take ownership of their streetlights.  This repre-
                                 sents about 48% of the streetlights currently owned by NS Power.  Some of these municipalities have indicated
                                 they are prepared to move forward to begin removal of the NS Power streetlights and replacement of these with
                                 the municipality-owned LED units.  NS Power seeks the Board's confirmation that it may sell existing streetlights
                                 for their net book (depreciated) value to those municipalities who have notified NS Power of their intentions to
                                 take ownership of their agreed share.

   •  M06268    NSPI Affiliate Code of Conduct Report for 2013 - May 30, 2014
                                                                                           Reference:
                                        •  Matter Number M06268 – NSPI - Affiliate Code of Conduct Paper Proceeding - P-167 [16 pages] - August 19, 2015
                                                   The Affiliate Code of Conduct governs the conduct of NS Power as it relates to its business dealings
                                                   with its affiliates...NS Power executives and senior management expect all employees to comply fully
                                                   with all provisions of the NS Power Affiliate Code of Conduct...

   •  M06263    NSPI Dispute Resolution Officer (DRO) Appeal - Derek Andrew McIsaac - May 27, 2014
                                 A consumption and billing issue (a residential electricity consumer) has been having with NSP for many months now...
                                 Subject to Rule 12(2), information about Dispute Resolution Officer (DRO) appeals filed with the Utility and Review Board
                                 is a matter of public record and can be accessed by others through the Internet or offices of the Board...

   •  M06259    Nova Scotia Power Inc. - Natural Gas Report - November 1, 2013 - March 31, 2014

   •  M06258    NERC - North American Electric Reliability Corporation - Q1 2014 - Application...Approval of Reliability Standards - May 20, 2014
                                 Some or all of NERC's Reliability Standards are mandatory in the Canadian provinces of Alberta, British Columbia, Manitoba,
                                 New Brunswick, Nova Scotia [boldface emphasis added], Ontario, Quebec, and Saskatchewan.
                                 —The North American Electric Reliability Corporation (NERC) hereby submits to the Nova Scotia Utility and Review Board
                                 (NSUARB) an application for approval of the NERC Reliability Standards and an updated NERC Glossary of Terms
                                 approved by the United States Federal Energy Regulatory Commission (FERC or the Commission), submitted
                                 for informational purposes. This filing covers the time period from January 1, 2014 through March 31, 2014.
                                 NERC requests that, as specified herein, these Reliability Standards and Definitions be made mandatory and
                                 enforceable for users, owners, and operators of the Bulk-Power System within the Province of Nova Scotia.
                                                                                           References:
                                        •  Matter Number M06363 – NERC - North American Electric Reliability Corporation - Q2 2014 - August 15, 2014
                                        •  Matter Number M06294 – NSPI - Protection Risk Reduction 67N-Onslow 230kV - $2,870,285 - June 25, 2014
                                        •  Matter Number M06258 – NERC - North American Electric Reliability Corporation - Q1 2014 - May 20, 2014
                                        •  Matter Number M06133 – NSPSO - NS Power System Operator 2013 Wholesale Market Report - March 3, 2014
                                        •  Matter Number M06132 – NERC - North American Electric Reliability Corporation - Q4 2013 - February 28, 2014
                                        •  Matter Number M06011 – NERC - North American Electric Reliability Corporation - Q3 2013 - November 26, 2013
                                        •  Matter Number M05944 – NERC - N.A. Electric Reliability Corporation - 2014 Business Plans etc. - Nov. 04, 2013
                                        •  Matter Number M05862 – NERC - North American Electric Reliability Corporation - Q2 2013 - August 30, 2013
                                        •  Matter Number M05713 – NERC - North American Electric Reliability Corporation - Q1 2013 - May 31, 2013
                                        •  Matter Number M04460 – NERC - First NERC Quarterly Application...Approval...Reliability Standards... - Sep. 06, 2011
                                        •  Matter Number M04025 – NSPI - Review...Reliability of Service at NSPI - April 04, 2011
                                        •  Matter Number M03815 – NSPI - Backup Control Centre - $3,222,066 - December 24, 2010
                                        •  Matter Number M03324 – NERC - NERC Reliability Standards; and NPCC Regional Reliability Criteria - June 29, 2010
                                        •  Matter Number M01989 – NSPI - CIP Standards Implementation - $422,923 - July 22, 2009
                                        •  Matter Number M01871 – NSPI - Report to the UARB Regarding NSPI/NB Power Interconnection - June 30, 2009
                                                                                           Also See:
                                                      •  North American Electric Reliability Corporation  NERC website
                                                      •  North American Electric Reliability Corporation  Wikipedia
                                                      •  NERC's Staff Expertise Recognized by IEEE Engineering Group  July 31, 2014
                                                      •  Keeping the Electricity Moving: NERC Guards the Bulk Power Grid  ASME
                                                      •  Reliability Standards  NERC
                                                      •  Reliability Standards for the Bulk Electric Systems of North America  complete set, 1838 pages
                                                      •  Integrated Bulk Power System Risk Assessment Concepts  NERC  (Chrome browser recommended)
                                                      •  Reliability – Canadian Electricity Association
                                                      •  ISO RTO   Independent System Operator (ISO)   Regional Transmission Organization (RTO)

   •  M06248    Efficiency Nova Scotia Corporation - 2014 Q1 Demand Side Management (DSM) Report - May 14, 2014
                                 In the first quarter of 2014, Efficiency Nova Scotia (ENSC) achieved success with Demand Side Management (DSM)
                                 program results.  Energy savings of 26.1 GWh were achieved, which is approximately 19% of the 2014 target of
                                 137.8 GWh.  Based on this result, as well as planned activities for the remainder of 2014, Efficiency Nova Scotia
                                 is confident it will achieve its 2014 energy savings goal within its approved investment amount of $47.5 million.
                                                                                           References:
                                        •  Matter Number M06395 – Efficiency Nova Scotia Corp. - 2014 Q2 DSM Quarterly Report
                                        •  Matter Number M06248 – Efficiency Nova Scotia Corp. - 2014 Q1 DSM Quarterly Report
                                        •  Matter Number M05956 – Efficiency Nova Scotia Corp. - 2013 Q3 DSM Quarterly Report
                                        •  Matter Number M05904 – Efficiency Nova Scotia Corp. - Various 2012 and 2013 Reports

   •  M06247    Efficiency Nova Scotia Corporation - 2015 Demand Side Management (DSM) Plan - May 14, 2014
                                                                                          Reference:
                                        •  Matter Number M06247 – Efficiency Nova Scotia Corporation (Re), 2014 NSUARB 144 (CanLII)    September 8, 2014

   •  M06221    NSPI WO - Q1 2014 - TUC (Tufts Cove) Cooling Water System Biofouling Control - $4,416,543 - April 30, 2014
                                 Power plant condensers and cooling water (CW) systems using seawater are prone to accumulation of microorganisms
                                 and algae on wetted parts such as condenser tubes.  This phenomenon is known as biofouling.  In recent years, biofouling
                                 in the CW piping and condensers at the Tufts Cove Generating Station has become progressively worse, and resulted in
                                 reduced reliability and availability, and increased heat rate (reduced energy efficiency) of the plant's three generating units.
                                 The biofouling has also resulted in unbudgeted maintenance costs for condenser tube cleaning.  Untreated seawater used
                                 for cooling permits the growth of algae, mussels and other organisms which cause flow restrictions and fouling in pipes,
                                 vessels, exchangers and other equipment.  The presence of this marine growth causes and/or increases corrosion in
                                 affected areas, and losses in system efficiencies, which can include lower heat transfer rates within heat exchangers,
                                 lower flow rates through small pipes, and fouled equipment.  The scope of this project is to purchase and install a sodium
                                 hypochlorite (NaClO) anti-fouling system to reduce and control biofouling in the CW piping and condensers
                                 for Units 1, 2, 3 and 6 at the Tufts Cove Generating Station.

   •  M06220   

   •  M06219    NSPI WO - Q1 2014 - Milton Hydro Office Construction - $733,611 - April 30, 2014

   •  M06218    NSPI WO - TUC (Tufts Cove) #3 U&U Generator Refurbishment - $1,500,239 - April 30, 2014
                                 This project is to cover the costs of repairing the TUC3 Generator Rotor due to a ground fault
                                 which occurred on February 18, 2014.  Running this machine with a ground fault could cause
                                 damage to the rotor, resulting in substantial repair costs.

   •  M06217    NSPI WO - TUC (Tufts Cove) #3 - U&U Turbine IP Row 21 Blading Phase 2 - $1,150,115 - April 30, 2014
                                 This project is to replace the remaining 108 Unit 3 Turbine Intermediate Pressure (IP) Row 21 Blades with used refurbished
                                 blades until new replacement blades are available.  Phase 1 replaced four blades due to inspection findings in late 2013.
                                 NS Power is currently completing the root cause failure analysis on the blades.
                                 Estimated Useful Life 2 to 3 years – (this is to last until the full replacement in 2016).

   •  M06216    NSPI WO - HYD (Hydro) - Unforeseen and Unbudgeted (U&U) Mill Lake Unit#2 Refurbishment - $516,830 - April 30, 2014
                                 This project is to refurbish Mill Lake Unit 2 in order to return it to service.  The Mill Lake units have been out of service
                                 since 2008 due to penstock and scroll case integrity.  Unit 2 requires replacement of the penstock (last 30m), butterfly
                                 valve and refurbishment of the scroll case.  These water turbines and generators were manufactured and installed in the
                                 late 1920s.  Due to investments made in the Coon Pond pipeline and intake structures, a potential 2 GWh (annually) of
                                 energy production for the Mill Lake Generating Station has been created.  At today's prices for wholesale electricity,
                                 each of the two Mill Lake generating units can produce energy worth about $400,000 a year.  Studies show that there
                                 is sufficient water to run both Mill Lake units for 16 hours per day.

   •  M06215    NSPI - 2013 Annual Report for the Electromechanical Relay Test Program - April 30, 2014
                                 Relays are special devices installed by all electric utilities in substations to protect power lines and equipment from
                                 faults on the transmission and distribution system, and provide isolation capabilities to improve reliability of electric
                                 service to customers.  Relays are routinely tested from time to time to ensure they are properly calibrated and in
                                 good working condition.  On October 28, 2010, the Board issued an order directing NSPI to extend the previous
                                 three-year testing cycle to six years for relays for the 69kV and 138kV systems, and directing NSPI to continue to
                                 file annual reports in the current format.  In 2013, 316 relays were tested in 15 substations across the Province.

   •  M06214    Nova Scotia Power Inc. - Renewable to Retail Engagement Pursuant to the Electricity Act - April 30, 2014
                                 By Application dated April 30, 2014, [Exhibit N-1 in Matter Number M06214] Nova Scotia Power Incorporated requested
                                 the Utility and Review Board initiate a process for consultation by NSPI with stakeholders in connection with
                                 sales of renewable low impact electricity generated within Nova Scotia...
                                                                                           Reference:
                                        •  Matter Number M06214 – Participants List [Exhibit DOC.pdf in Matter Number M06214] Updated Dec. 16, 2014  [7 pages]

   •  M06213    Nova Scotia Power Inc. 2014 Load Forecast Report (10 Year Energy and Demand Forecast)
                                 In accordance with section 3.3.1.2 of the Nova Scotia Wholesale Electricity Market Rules, the Nova Scotia Power
                                 System Operator (NSPSO) shall file with the Board its ten-year energy and demand forecast by the end of April each
                                 year for the ten-year period beginning in the following January.
                                              – Attached is NSPI's 2014 Load Forecast.
                                              – For the winter of 2013/2014, the NSPI system peak load was 2,118 MW (2 839 000 horsepower) established
                                                          5:00pm-6:00pm  on  January 2nd, 2014,  when  temperature  was  -19.3°C.
                                              For the winter of 2012/2013, the January peak reached 2,033 MW (2 725 000 horsepower) at a temperature of -12.8°C.
                                              – Transmission losses are forecast at approximately 3% of the transmission system energy requirement.
                                              NS Power distribution losses are forecast at approximately 5.5% of distribution level sales.  Residential
                                              and commercial classes tend to have higher losses due to the lower voltages at which they are served.
                                                                                           References:
                                        •  Matter Number M06213 – Nova Scotia Power System Operator (NSPSO) 2014 Load Forecast Report (10 Years)
                                        •  Matter Number M05653 – Nova Scotia Power System Operator (NSPSO) 2013 Load Forecast Report (10 Years)
                                        •  Matter Number M04953 – Nova Scotia Power System Operator (NSPSO) 2012 Load Forecast Report (10 Years)
                                        •  Matter Number M04064 – Nova Scotia Power System Operator (NSPSO) 2011 Load Forecast Report (10 Years)
                                        •  Matter Number M03071 – Nova Scotia Power System Operator (NSPSO) 2010 Load Forecast Report (10 Years)
                                        •  Matter Number M01559 – Nova Scotia Power System Operator (NSPSO) 2009 Load Forecast Report (10 Years)

   •  M06206   
   •  M06205   

   •  M06204    NSPI - 2013 Short Run Marginal Cost (SRMC) to Rates Report - April 30, 2014
                                 The Utilities and Review Board notes that during 2013 coal-fired generation was used on the margin 53% of the time,
                                 compared to 80% in 2012.  Also, Imports were on the margin 26% of the time in 2013, compared to 13% in 2012.  NSPI
                                 has stated that meeting environmental requirements was not a driver of the generation used on the margin during 2013.
                                                NOTE: Electric generation "on the margin" refers to the last generation called up
                                                by dispatchers - typically the most expensive per MWh at a given level of demand.

 
M00000-M00999    M01000-M01999    M02000-M02999    M03000-M03999    M04000-M04999
M05000-M05499    M05500-M05999    M06000-M06199    M06200-M06399
M06400-M06599    M06600-M06799    M06800-M06999    M07000-M07199


In the “Electricity” section of the UARB website
Matter Numbers M06000 to M06199

      Matter
    Number


   •  M06194    Nova Scotia Power Inc. - Annual and Regulated Financial Statements - 2013 & 2014 - April 15, 2014
                                              Re: Calculation of Nova Scotia Power Inc's Return on Equity - P-888(2)
                                              Re: NSPI Renewable Energy Projects - Tax and Depreciation Effect - P-201
                                              Re: Application of the $27.5 million non-fuel deferral P - 893
                                 — Thermal Generating Stations
                                 NSPI facilities continue to rank among the best in Canada on performance indicators.  The high availability
                                 and capabilityof low cost thermal generating stations provide lower cost energy to customers.  In 2013, thermal
                                 plant availability was 87.5 per cent compared to 81.0 per cent in 2012 and 85.5 per cent over a four-year average.
                                 This ranks in the top quartile of the Canadian Electricity Association statistics.
                                 — Cost of Fuel
                                 Historically, coal and petroleum coke (petcoke) has had the lowest per unit fuel cost, after hydro and NSPI-owned
                                 wind, which have no fuel cost component.  Purchased power, natural gas, oil and biomass have the next lowest
                                 fuel cost, depending on the relative pricing of each.  Over the last few years economic dispatch has favoured natural
                                 gas over coal.  However, this trend has reversed since the latter part of 2012, due to volatility in natural gas markets
                                 in Nova Scotia as a result of supply challenges.
                                 — Point Tupper Wind Farm
                                 NSPI is a participant in 23.3 MW wind energy project with Renewable Energy Services Ltd. in Point Tupper, Nova Scotia.
                                 Percentage ownership of the wind project assets is based on the relative value of each party's project assets by the total
                                 project assets with NSPI owning less than 49 per cent.  NSPI has a power purchase arrangement to purchase the entire
                                 net output of the project and therefore NSPI's portion of the revenues are recorded net, within fuel for generation and
                                 purchased power.  NSPI's portion of operating expenses, are recorded in Operating, Maintenance and General (OM&G)
                                 expenses.  In 2013, NSPI recognized $2.6 million (2012 – $2.6 million) in fuel for generation and purchased power
                                 and $0.5 million (2012 – $0.5 million) in OM&G.
                                 — South Canoe Wind Farm
                                 NSPI is a participant in the development of a 102 MW wind farm in South Canoe, Nova Scotia.  Percentage ownership
                                 of the wind farm will be based on the relative value of each party's project assets by the total project assets, however
                                 NSPI will not own more than 49 per cent.  The projects are planned to be in service in 2015.
                                 — Brooklyn Power
                                 On July 22, 2013, Emera, through its wholly owned subsidiary, Emera Energy, purchased a 100 per cent interest
                                 in Brooklyn Power Corporation (Brooklyn Energy) for total consideration of $26.8 million.  Brooklyn Energy is
                                 a 30 MW biomass co-generation facility located in Brooklyn, Queens County, Nova Scotia.  This investment was
                                 made to increase Emera's renewable generation portfolio.
                                 — Poly Chlorinated Bi-Phenol (PCB) Transformers
                                 In response to the Canadian Environmental Protection Act 1999, 2008 Poly Chlorinated Bi-Phenol (PCB) Regulations
                                 to phase out electrical equipment and liquids containing PCBs, NSPI has implemented a program to eliminate
                                 transformers and other oil-filled electrical equipment on its system that do not meet the 2008 PCB Regulations
                                 Standard by 2014.  The federal government published proposed amendments to the PCB Regulations extending
                                 the required deadline for the removal of some types of equipment from 2014 to 2025.  The amendments are expected
                                 to be finalized in Q1 2014.  In addition, there is a capital program to destroy all confirmed PCB contaminated pole
                                 mount transformers taken out of service through attrition.  The combined total cost of these projects is estimated to
                                 be $26.2 million and, as at December 31, 2013, approximately $12.1 million has been spent to date.  NSPI has
                                 recognized an Asset Retirement Obligation (ARO) of $11.1 million as at December 31, 2013 associated with
                                 the PCB phase-out program.

                                        Maritime Link across Cabot Strait       500 MW        670 000 horsepower
   •  M06191    NSPML - Nova Scotia Power Maritime Link Inc. - NSPML 2014 Q1 Quarterly Report - April 15, 2014
                                 — This [Exhibit N-1 in Matter Number M06191] is the Q1 2014 Quarterly Report for the Maritime Link as directed by the UARB.
                                 1.0 Introduction
                                 2.0 Update of Project Schedule...
                                            2.1 Gates and Milestones
                                            2.2 Commercial Activities
                                                   2.2.1 Land Access Agreement
                                                   2.2.2 Funding – Schedule Reserve and Allowances
                                                   2.2.3 Joint Development Agreements
                                            2.3 Engineering Activities
                                            2.4 Submarine Cables (Marine)
                                            2.5 Converter Stations
                                            2.6 Tree Clearing Contractor – Transmission Lines
                                            2.7 Construction Contractor – Transmission Lines
                                            2.8 Construction Contractor – Compounds/Other
                                 3.0 Updated Cost Summary
                                                                                           References:
                                        •  Matter Number M06279 – NSPML - Maritime Link 2014 Q2 Quarterly Report - June 13, 2014
                                        •  Matter Number M06191 – NSPML - Maritime Link 2014 Q1 Quarterly Report - April 15, 2014
                                        •  Matter Number M06024 – NSPML - Maritime Link 2013 Q4 Quarterly Report - December 13, 2013
                                        •  Matter Number M05419 – NSPML - Application for approval of the Maritime Link Project... - January 28, 2013

   •  M06180    Nova Scotia Power Inc. - Power Line Technician Staffing Levels and Reliability of Service at NSPI, 2014 Report - April 4, 2014
                                 The 2013 Annual Emergency Services Restoration Plan (ESRP) Drill was held on August 26, 2013, with approximately
                                 20 drill participants working at the Ragged Lake Control Centre.  An invitation was sent to Utility and Review Board staff
                                 inviting them to observe the drill.  The format of the drill was based on the assumption of a large, weather event (such as
                                 a hurricane) occurring in Nova Scotia.  Participants were tasked with a thorough review of the ESRP document, with the
                                 focus on EOC (Emergency Operations Centre) team responsibilities, role descriptions, EOC operating procedures,
                                 processes and sub-plans.  The drill included the majority of the EOC Team...
                                 References:  • Joint Emergency Operations Centre
                                 • A Report on the Emergency Response to Hurricane Juan September 29-30, 2003

   •  M06176    Nova Scotia Power Inc. - Regulation 5.3 - Alternative Billing Plans, Section A - Budget Plan - Report - April 4, 2014
                                 The Board has identified a concern related to customer credit balances that have continued to increase due to
                                 the billing system not recognizing negative budget amounts.  NSPI's failure to refund or otherwise resolve the
                                 issue associated with the budget billing system not recognizing negative budget billing amounts is concerning.
                                 The Board directs NSPI to provide a report, prior to July 31, 2014, that outlines NSPI's proposed solution to
                                 remedy this issue and a timeline for implementation.  This report should include the total amount NSPI owed
                                 to customers in a credit position at December 31, 2013...

   •  M06172    Elliott Daniels and Paul Taylor (Development Agreement) - April 2, 2014 - Appeal to the approval of a Development Agreement
                                 by SWEB Development Inc. to allow three large wind turbines in Three Mile Plains,
                                 Mill Lakes Watershed Protected Area, Municipality of the District of West Hants

   •  M06144    Nova Scotia Power Corporation (NSPC) - Rate Hearing 1993 - October 8, 1992
                                                                                          References:
                                        •  Matter Number M05039 – NS Power Rates 1979
                                        •  Matter Number M05051 – NS Power Rates 1982
                                        •  Matter Number M05424 – NS Power Rates 1989
                                        •  Matter Number M06119 – NS Power Rates 1990
                                        •  Matter Number M05411 – NS Power Rates 1992
                                        •  Matter Number M06144 – NS Power Rates 1993
                                        •  Matter Number M05361 – NS Power Rate Design 1993
                                        •  Matter Number M06131 – NS Power Rates 1995
                                        •  Matter Number M05380 – NS Power Rate Design 1996
                                        •  Matter Number M05188 – NS Power Rates 2002
                                        •  Matter Number M05002 – NS Power Generic Rate Design 2003
                                        •  Matter Number M05656 – NS Power Rates (Extra Large Interruptible) 2003
                                        •  Matter Number M05675 – NS Power Rates 2004
                                        •  Matter Number M06319 – NS Power Rates 2007
                                        •  Matter Number M05474 – NS Power Rates (Human Rights) 2007
                                        •  Matter Number M05644 – NS Power Rates (Short Run Marginal Costs) 2012
                                        •  Matter Number M06277 – NS Power Rates (Tariff Revisions) 2014

Name Change:
On 12 August 1992, Nova Scotia Power Incorporated (New NSPI),
a  new   privately-owned   electric   utility   company,   officially
bought the assets of Nova Scotia Power Corporation (Old NSPC).
—Sources:    • Halifax Chronicle-Herald, August 13, 1992
• Utilities and Review Board - M06144 - (Exhibit NSP-863 dated 03/24/1993) - March 24, 1993


•  M06142    NSPI - 2013 Annual FAM (Fuel Adjustment Mechanism) Report - March 5, 2014

Nova Scotia Power Incorporated – 2013


Electric Energy Actual
2012
Actual
2013
Budget
2014
Total System Requirements (GWh) 10,509.4 11,204.1 9,847.2
Domestic Electric Sales (GWh) 9,754.4 10,455.7 9,135.1
Export Sales (GWh) 34.9 10.5 15.5
Net System Losses (GWh) 720.1 737.9 696.6
Net System Losses (Per Cent) 6.9% 6.6% 7.1%

NSPI Commentary 2013
Emissions Regulations

Nova Scotia Power (NSPI) is required to manage air emissions to annual fleet wide limits, as per the
NS Air Quality Regulations and the NS Greenhouse Gas (GHG) Emission Regulations.  NSPI has been
fully compliant with legislated emission targets each year.


For 2013, the fleet wide cap on air emissions for sulphur dioxide (SO2) was 72,500 tonnes per year.
The emissions of SO2 were within these limits for 2013 at 67,806 tonnes.  In 2014 the cap for SO2 will
remain at 72,500 tonnes, but the cap is expected to be lowered to 60,900 tonnes in 2015.


The 2013 cap on emissions of mercury (Hg) was originally 85 kg.  NSPI continued the operation of seven
sorbent injection systems that were installed in 2009.  The mercury emissions were within this limit in
2013 at 72.5 kg.  The 2014 emission limit for mercury will be 65 kg.  Under current regulations, any
NSPI emissions of Hg above 65 kg per year for 2010-2013 must be made up by 2020.


NSPI manages its actual air emissions (SO2 and to some extent mercury) by purchasing and
combusting specific quality fuels and procuring power from other sources (i.e., Imports and
Independent Power Producers), and by increasing the amount of renewable generation.


The 2013 cap for emissions of nitrogen oxides (NOx) was 21,365 tonnes.  NSPI continued the
operation of the low NOx Combustion Firing Systems (LNCFS) on all Lingan units, Point Tupper
and Trenton 6.  These LNCFS additions represent the primary approach to reduce NOx emissions.
Emissions for 2013 were 16,998 tonnes.  The NOx emission cap will remain at 21,365 tonnes in 2014,
but is expected to reduce to 19,228 tonnes in 2015.


The GHG emission limit for the two-year period of 2012-2013 has been set at 18.5 million tonnes CO2eq.
This equated to an approximate target of 9.34 million tonnes in 2012 and 9.16 million tonnes in 2013.
The 2012 emissions of GHG totalled 7,572,982 tonnes of CO2eq, and the 2013 emissions were
7,799,519 tonnes of CO2eq for a total of 15,372,501 tonnes for the compliance period.  In addition, NSPI
xobtained a 145,728 tonne GHG credit in 2013, which can be applied to reduce the GHG total even further.


In addition to these fleet-wide caps, each generating facility operates within an Industrial Operating
Approval which requires ground level ambient air quality to be maintained, plume visibility to be within
limits and, in some cases, specific emission standards to be met.  This is accomplished by maintaining
the plant equipment in good working order and operating the plant within the specified limits.


References:
•  Matter Number M06738 – Nova Scotia Power Inc. - 2014 Annual FAM (Fuel Adjustment Mechanism) Report
•  Matter Number M06142 – Nova Scotia Power Inc. - 2013 Annual FAM (Fuel Adjustment Mechanism) Report
•  Matter Number M05555 – Nova Scotia Power Inc. - 2012 Annual FAM (Fuel Adjustment Mechanism) Report
•  Matter Number M04865 – Nova Scotia Power Inc. - 2011 Annual FAM (Fuel Adjustment Mechanism) Report
•  Matter Number M03958 – Nova Scotia Power Inc. - 2010 Annual FAM (Fuel Adjustment Mechanism) Report
•  Matter Number M02791 – Nova Scotia Power Inc. - 2009 Annual FAM (Fuel Adjustment Mechanism) Report
•  Matter Number M01866 – Nova Scotia Power Inc. - Mercury Sorbent Cost Recovery – June 9, 2009             

•  Total System Emissions - NSPI All Generating Plants


Also see:

•  CO2eq Equivalent carbon dioxide  Wikipedia

• The Canadian Electricity Association (CEA) Mercury Program

• The Canadian Electricity Association (CEA) - Understanding Mercury

•  Multi-Technology, Mercury Abatement Program, Implementation
and Performance at Nova Scotia Power
  September 2010

• Technical Review of Mercury Technology Options for Canadian Utilities -
A Report to the Canadian Council of Ministers of the Environment
(CCME)  March 2005


• Canada-wide Standard for Mercury Emissions from Coal-fired Electric Power Generation Plants
– 2012 Progress Report
   May 2014
         — (page 22)   Nova Scotia has amended its provincial  Air  Quality  Regulations  to extend
achievement of the  65 kg  cap  to 2014 from 2010, with annual declining  emission  caps from 2010
to 2013.  In addition  the  province  has  established  a cap of  35 kg  in 2020.   The  annual  emission
allocations under provincial regulation for the years 2010 to 2020 are identified in the following tables...
             — (page 3)   Canada-wide:  In the  baseline  year of 2003,  2695 kg  of mercury were emitted
and there was a total of 3725 kg  of mercury in the amount of coal burned.  This represented a capture
rate of less than 28%.  In 2012, 826 kg of mercury were emitted and the total mercury contained in the
coal  burned  was  1868 kg  representing  a  capture  rate  of  56%.  Although  this  is  not  equal  to  the
Canada-wide Standards for Mercury Emissions from Coal-fired Electric Power Generation Plants (CWS)
goal of 60% capture, it does represent a nearly  70%  reduction in total emissions from 2003.  The 2010
emission caps were expected  to produce a  52-58%  reduction  in  total  emissions.  While the goal for
capture rate has not yet been achieved, absolute emissions have been reduced more than expected
through  a  combination  of  reduced  coal  consumption  and  emissions  abatement...

   •  M06136    NSPI WO - HYD - Cheticamp Dam D-1 (Wreck Cove) Refurbishment - Outside Quarter - March 4, 2014 - $5,778,847

   •  M06133    Nova Scotia Power Inc. - Nova Scotia Power System Operator (NSPSO) 2013 Wholesale Market Report - March 3, 2014
                                 2013 Annual Report providing information on thirteen areas of Wholesale Market operation
                                 The Nova Scotia Wholesale Electricity Market was opened to competition effective February 1, 2007.  At that time the
                                 Nova Scotia Wholesale Electricity Market Rules, which define the rights and obligations of the Nova Scotia Power
                                 System Operator (NSPSO) and all Market Participants, also came into effect.  This report on the operation of the
                                 wholesale electricity market in 2013 provides information on thirteen areas as specified by the Nova Scotia Utility and
                                 Review Board (Board, UARB) in its letter of March 10, 2008.  This is the seventh Wholesale Market Report prepared by
                                 the NSPSO.  The previous report was filed with the UARB on February 28, 2013. 
                                                                                         UARB Comments
                                 The Board notes that during 2013 additional steps were taken with respect to the Wholesale Market Advisory Committee
                                 and as of the date of this filing, this Committee has full membership and regularly scheduled meetings are occurring.
                                 The Board also notes that while the NSPSO has made progress on completing some of the market procedures listed
                                 as outstanding in the 2012 Report, two procedures still remain outstanding as of this 2013 Report filing.
                                                                                         NERC and NPCC
                                 Since the NS Power electrical system is interconnected with the North American bulk power system,
                                 NS Power is required to comply with standards and codes as governed by the North American Electric
                                 Reliability Corporation (NERC) and the Northeast Power Coordinating Council (NPCC).  This obligation to comply
                                 extends to Market Participants and generators interconnected with the Nova Scotia Power grid.  Links to the applicable
                                 standards and codes are published on the Open Access Same-time Information System (OASIS) website.
                                                                                         Nova Scotia Power Inc.
                                 All facilities involved in the generation, transmission, and use of electricity must be properly connected to the
                                 interconnected power systems to avoid degrading the reliability of the electric systems to which they are connected.
                                 To avoid adverse impacts on reliability, generation and transmission owners and electricity end-users must meet facility
                                 connection and performance requirements specified by those responsible for the reliability of the interconnected
                                 transmission systems.  Nova Scotia Power Inc. provides this guide to identify the process and general technical
                                 requirements for connecting to the NSPI transmission system.  The primary purpose of this document is to ensure
                                 that facilities that could have an adverse impact on the bulk power system, regardless of ownership, are planned,
                                 designed, and operated to criteria set forth by NERC and NPCC.
                                                                                           References:
                                        •  Matter Number M06743 – Nova Scotia Power System Operator (NSPSO) 2014 Wholesale Market Report
                                        •  Matter Number M06133 – Nova Scotia Power System Operator (NSPSO) 2013 Wholesale Market Report
                                        •  Matter Number M05565 – Nova Scotia Power System Operator (NSPSO) 2012 Wholesale Market Report
                                        •  Matter Number M04842 – Nova Scotia Power System Operator (NSPSO) 2011 Wholesale Market Report
                                        •  Matter Number M03959 – Nova Scotia Power System Operator (NSPSO) 2010 Wholesale Market Report
                                        •  Matter Number M02762 – Nova Scotia Power System Operator (NSPSO) 2009 Wholesale Market Report

   •  M06132    NERC - North American Electric Reliability Corporation - Q4 2013 - Application...Approval of Reliability Standards - Feb. 28, 2014
                                 Some or all of NERC's Reliability Standards are mandatory in the Canadian provinces of Alberta, British Columbia, Manitoba,
                                 New Brunswick, Nova Scotia [boldface emphasis added], Ontario, Quebec, and Saskatchewan.
                                 —The North American Electric Reliability Corporation (NERC) hereby submits to the Nova Scotia Utility and Review Board
                                 (NSUARB) an application for approval of the NERC Reliability Standards and an updated NERC Glossary of Terms
                                 approved by the United States Federal Energy Regulatory Commission (FERC or the Commission), submitted
                                 for informational purposes.  This filing covers the time period from October 1, 2013 through December 31, 2013.
                                 NERC requests that, as specified herein, these Reliability Standards and Definitions be made mandatory and
                                 enforceable for users, owners, and operators of the bulk-power system within the Province of Nova Scotia.
                                                                                           References:
                                        •  Matter Number M06258 – NERC - North American Electric Reliability Corporation - Q1 2014 - May 20, 2014
                                        •  Matter Number M06133 – NSPSO - NS Power System Operator 2013 Wholesale Market Report - March 3, 2014
                                        •  Matter Number M06132 – NERC - North American Electric Reliability Corporation - Q4 2013 - February 28, 2014
                                        •  Matter Number M06011 – NERC - North American Electric Reliability Corporation - Q3 2013 - November 26, 2013
                                        •  Matter Number M05944 – NERC - N.A. Electric Reliability Corporation - 2014 Business Plans etc. - Nov. 04, 2013
                                        •  Matter Number M05862 – NERC - North American Electric Reliability Corporation - Q2 2013 - August 30, 2013
                                        •  Matter Number M05713 – NERC - North American Electric Reliability Corporation - Q1 2013 - May 31, 2013
                                        •  Matter Number M04460 – NERC - First NERC Quarterly Application...Approval...Reliability Standards... - Sep. 06, 2011
                                        •  Matter Number M04025 – NSPI - Review...Reliability of Service at NSPI - April 04, 2011
                                        •  Matter Number M03815 – NSPI - Backup Control Centre - $3,222,066 - December 24, 2010
                                        •  Matter Number M03324 – NERC - NERC Reliability Standards; and NPCC Regional Reliability Criteria - June 29, 2010
                                        •  Matter Number M01989 – NSPI - CIP Standards Implementation - $422,923 - July 22, 2009
                                        •  Matter Number M01871 – NSPI - Report to the UARB Regarding NSPI/NB Power Interconnection - June 30, 2009
                                                                                           Also See:
                                                      •  North American Electric Reliability Corporation  NERC website
                                                      •  North American Electric Reliability Corporation  Wikipedia
                                                      •  NERC's Staff Expertise Recognized by IEEE Engineering Group  July 31, 2014
                                                      •  Keeping the Electricity Moving: NERC Guards the Bulk Power Grid  ASME
                                                      •  Reliability Standards  NERC
                                                      •  Reliability Standards for the Bulk Electric Systems of North America  complete set, 1838 pages
                                                      •  Integrated Bulk Power System Risk Assessment Concepts  NERC  (Chrome browser recommended)
                                                      •  Reliability – Canadian Electricity Association
                                                      •  ISO RTO   Independent System Operator (ISO)   Regional Transmission Organization (RTO)

   •  M06131   

   •  M06120    Berwick Electric Commission - 2014 Demand Side Management (DSM) Flow Through Application - February 24, 2014
                                                                                          References:
                                        •  Demand Side Management Cost Recovery Rider    NSPI - August 2014
                                        •  Matter Number M06120 – Town of Berwick (Electric Commission) (Re), 2014 NSUARB 49 (CanLII)    March 4, 2014

   •  M06119    Nova Scotia Power Corporation (NSPC) - Rate Hearing 1990 - October 3, 1989
                                 — Effective with respect to power and energy supplied by NSPC on and after April 1st, 1990.
                                 — Nova Scotia Power Corporation Domestic (Residential Household) Rate
                                 Base Charge - $7.27 per month
                                 Energy Charge - 7.86 cents per kilowatt hour for the first 200 kilowatt hours per month
                                                          - 7.07 cents per kilowatt hour for all additional kilowatt hours
                                 The minimum monthly charge shall be $7.27.
               &