EDMONTON, ALBERTA -- (Marketwired) -- 08/03/17 -- EPCOR Utilities Inc. (EPCOR) today filed its quarterly results for the three months and year-to-date period ended June 30, 2017.
"EPCOR's financial performance was in line with expectations for the quarter," said Stuart Lee, EPCOR President & CEO. "It was a productive quarter for EPCOR, as we completed the acquisition of Hughes Gas Resources, Inc., a natural gas distribution utility operating northwest of Houston, Texas, which marks our entrance into the natural gas distribution business and further builds out our footprint in Texas."
"We also made excellent progress in preparing for the transfer of the City of Edmonton's Drainage Services utility to EPCOR," said Mr. Lee. "We look forward to welcoming Drainage employees and customers on September 1." The City of Edmonton approved the transfer of its Drainage Services utility to EPCOR on April 12. With the transfer, EPCOR will oversee the City's entire water utility cycle.
Results were lower than the same periods in 2016 owing to events in 2016 that were not present in 2017. Highlights of EPCOR's financial performance are as follows:
-- Net income was $56 million and $94 million for the three and six months
ended June 30, 2017, respectively, compared with $67 million and $145
million for the corresponding periods in the previous year. Net income
was lower primarily due to lower income from core operations, as
described below, and no dividend income due to the final sale of Capital
Power shares. Partially offsetting these decreases were greater
favorable fair value adjustments related to financial electricity
purchase contracts in 2017 and unfavorable fair value adjustments
related to interest swaps in the corresponding periods in 2016. In
addition, the six months ended June 30, 2017 include the recognition of
the fair value gain resulting from the final sale of Capital Power
shares.
-- Income from core operations was $52 million and $90 million for the
three and six months ended June 30, 2017, respectively, compared with
$68 million and $143 million for the corresponding periods in the
previous year. Income from core operations was lower primarily due to
lower income from industrial services contracts resulting from the
termination of the Suncor financing and operating agreements in 2016,
lower Energy Price Setting Plan margins, lower water and wastewater
volumes due to higher precipitation in the city of Edmonton, higher
water treatment costs and a loss on sale of surplus land, partially
offset by higher electricity transmission and water customer rates. In
addition, the decrease for the six months ended June 30, 2017 was also
due to lower net system access service collections and lower gains as a
result of sales of surplus land in the first quarter of 2016.
-- Net cash flows from operating activities was $132 million for the six
months ended June 30, 2017, compared with $223 million for the
corresponding period in the previous year. The decrease reflects reduced
income from operations and lower funds from changes in non-cash
operating working capital.
-- Investment in capital projects and acquisitions was $154 million and
$252 million for the three and six months ended June 30, 2017,
respectively, compared with $122 million and $210 million for the
corresponding periods in the previous year. The year-to-date increase of
$42 million was primarily due to the acquisition of Hughes Gas
Resources, Inc., partially offset by decreased spending in Distribution
and Transmission on growth and lifecycle projects.
Management's discussion and analysis (MD&A) of the quarterly results are shown below. The MD&A and the unaudited condensed consolidated interim financial statements are available on EPCOR's website (www.epcor.com) and SEDAR (www.sedar.com).
EPCOR, through its subsidiaries, builds, owns and operates electrical and natural gas transmission and distribution networks, water and wastewater treatment, collection and distribution facilities and networks in Canada and the United States. The Company also provides electricity, natural gas and water products and services to residential and commercial customers. EPCOR, headquartered in Edmonton, is an Alberta Top 70 employer. EPCOR's website address is www.epcor.com.
EPCOR Utilities Inc.
Interim Management's Discussion and Analysis
June 30, 2017
This management's discussion and analysis (MD&A) dated August 3, 2017, should be read in conjunction with the condensed consolidated interim financial statements of EPCOR Utilities Inc. for the three months and six months ended June 30, 2017 and 2016 including business transfer and acquisition (note 4), changes in liabilities arising from financing activities (note 5), financial instruments (note 6) and the consolidated financial statements and MD&A for the year ended December 31, 2016, including standards and interpretations not yet applied (note 3(v)), related party transactions (note 27) and financial instruments (note 28), and the cautionary statement regarding forward-looking information at the end of this MD&A. In this MD&A, any reference to "the Company", "EPCOR", "it", "its", "we", "our" or "us", except where otherwise noted or the context otherwise indicates, means EPCOR Utilities Inc., together with its subsidiaries. In this MD&A, Capital Power refers to Capital Power Corporation and its directly and indirectly owned subsidiaries including Capital Power L.P., except where otherwise noted or the context otherwise indicates. Financial information in this MD&A is based on the condensed consolidated interim financial statements, which were prepared in accordance with International Financial Reporting Standards (IFRS), and is presented in Canadian dollars unless otherwise specified. In accordance with its terms of reference, the Audit Committee of the Company's Board of Directors reviews the contents of the MD&A and recommends its approval by the Board of Directors. This MD&A was approved and authorized for issue by the Board of Directors on August 3, 2017.
OVERVIEW
EPCOR is wholly owned by the City of Edmonton (the City). EPCOR, through its subsidiaries, builds, owns and operates electrical and natural gas transmission and distribution networks and provides Regulated Rate Option (RRO) and default supply electricity related services. EPCOR sells electricity and natural gas to Alberta residential consumers under contracts through its Encor brand. In addition, EPCOR builds, owns and operates water treatment facilities and distribution networks, and wastewater treatment facilities and collection networks in Canada and the Southwestern United States (U.S.). The water and wastewater business also includes design, build, finance, operating and maintenance services for municipal and industrial customers in Western Canada.
Net income was $56 million and $94 million for the three and six months ended June 30, 2017, respectively, compared with net income of $67 million and $145 million for the comparative periods in 2016, respectively. The decrease of $11 million and $51 million, respectively, from the comparative periods was in part due to lower income from core operations, as described below, and no dividend income due to the sale of remaining Capital Power shares (also referred to as the "available-for-sale investment in Capital Power"). Partially offsetting these decreases were greater favorable fair value adjustments related to financial electricity purchase contracts in 2017 and unfavorable fair value adjustments related to interest swaps in 2016 with no corresponding transaction in the current year. In addition, the six months ended June 30, 2017 include the recognition of the fair value gain resulting from the final sale of Capital Power shares.
Net income from core operations was $52 million and $90 million for the three and six months ended June 30, 2017, respectively, compared with $68 million and $143 million for the comparative periods in 2016, respectively, as described in the net income table on page 4 of this MD&A. The decrease in income from core operations for the three and six months ended June 30, 2017 was driven in part by lower income from industrial services contracts due primarily to the termination of the Suncor financing and operating agreements in 2016, lower Energy Price Setting Plan margins, lower water and wastewater volumes due to higher precipitation, higher water treatment costs due to poor river quality conditions in the city of Edmonton and loss on sale of surplus land in 2017. The decreases for the three months ended June 30, 2017 were partially offset by higher electricity transmission, water and wastewater rates and higher net system access service collections. In addition, the decrease for the six months ended June 30, 2017 was also due to lower gains as a result of sales of surplus land in the first quarter of 2016 and lower net system access service collections. Partially offsetting these decreases were higher water, wastewater and electricity distribution and transmission rates. Income from core operations is a non-IFRS financial measure as described in Net Income on page 3 of this MD&A.
SIGNIFICANT EVENTS
Acquisition of Hughes Gas Resources, Inc.
On June 1, 2017, the Company acquired 100% of the common shares of Hughes Gas Resources, Inc., (Hughes), a natural gas distribution, transmission and services holding company with four wholly owned subsidiaries operating northwest of Houston, Texas, for total consideration of $54 million (US$40 million) and the assumption of $13 million (US$10 million) in third party debt.
Hughes is primarily involved in the distribution of natural gas to approximately 4,300 customer connections through its rate regulated subsidiary Hughes Natural Gas, Inc. which owns and operates a 354 kilometer (220 mile) natural gas distribution network. Other subsidiaries include Alamo Pipeline, LLC, the owner and operator of a rate regulated natural gas transmission pipeline which transports natural gas from suppliers to Hughes Natural Gas, Inc. through its 51 kilometer (32 mile) pipeline. These operations are regulated by the Texas Railroad Commission. The acquisition also includes two unregulated subsidiaries, Pinehurst Utility Construction, LLC (infrastructure contractor) and Goliad Midstream Energy, LLC (intermediary company for negotiation of supply contracts).
At closing, $46 million of the total consideration was paid with the $8 million balance of the consideration to be paid in the future contingent upon the addition of new customer connections above a minimum of 600 incremental customer connections over a period of six years from the date of closing. The Company has recorded the full amount of this contingent consideration based on expected growth in the region. The Company funded the closing payment using existing cash resources.
The fair value estimates of the assets acquired and liabilities assumed are preliminary and will be finalized upon completion of review by management. Such review could result in adjustments to the purchase price allocation between assets acquired and liabilities assumed. For further information on the fair value estimates, refer to the unaudited condensed consolidated interim financial statements of EPCOR Utilities Inc. for the six months ended June 30, 2017. Refer to the Capital Requirements and Contractual Obligations section for additional information.
Appointments to the Board of Directors
On May 8, 2017, Richard H. Cruickshank and Janice G. Rennie were appointed to the Board of Directors of the Company.
Transfer of Drainage Utility Services from the City of Edmonton
On April 12, 2017, Edmonton's City Council approved the transfer of its Drainage Utility Services (Drainage) to EPCOR. Drainage operations are comprised of the sanitary drainage utility and the stormwater drainage utility which provide services in sanitary wastewater and stormwater collection and bio solids management and disposal. The transfer of the Drainage utility will be structured as a transfer of assets and assumption of liabilities between the City and EPCOR, with EPCOR assuming financial responsibility for all existing Drainage related debt. Finalization of the terms of the Drainage transfer, including execution of a franchise agreement, is nearing completion with the transfer of the assets and assumption of liabilities expected to take place on September 1, 2017. Significant integration activities are currently underway including the set-up of information and accounting systems, the design of the Drainage organization chart and the finalization of the necessary union transfer agreements to facilitate the transfer of all union employees. Refer to the Capital Requirements and Contractual Obligations section for additional information relating to the Drainage transfer.
CONSOLIDATED RESULTS OF OPERATIONS
Revenues
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Three Six
(unaudited, $ millions) months Months
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Revenues for the periods ended June 30, 2016 $ 479 $ 954
Lower Water Services segment revenues (16) (31)
Higher electricity Distribution and Transmission
segment revenues 13 16
Higher (lower) Energy Services segment revenues 3 (4)
Other (5) (6)
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Decrease in revenues from core operations (5) (25)
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Revenues for the periods ended June 30, 2017 $ 474 $ 929
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Consolidated revenues were lower by $5 million and $25 million for the three and six months ended June 30, 2017, respectively, compared with the corresponding periods in 2016 primarily due to the net impact of the following:
-- Water Services segment revenues were lower for the three and six months
ended June 30, 2017, compared with the corresponding periods in 2016
primarily due to lower construction revenues from the Regina wastewater
treatment plant project, lower industrial services contract revenues and
lower water and wastewater volumes due to higher precipitation in the
city of Edmonton, partially offset by growth and higher customer rates.
-- Electricity Distribution and Transmission segment revenues were higher
for the three and six months ended June 30, 2017, compared with the
corresponding periods in 2016 primarily due to higher system access
service revenue and higher electricity transmission customer rates. In
addition, the increase for the six months ended June 30, 2017 was also
due to higher electricity distribution customer rates, partially offset
by lower revenue from commercial services.
-- Energy Services segment revenues were higher for the three months ended
June 30, 2017, compared with the corresponding period in 2016 primarily
due to customer growth, partially offset by lower electricity prices and
volume. Energy Services segment revenues were lower for the six months
ended June 30, 2017, compared with the corresponding period in 2016
primarily due to lower electricity prices and volumes, partially offset
by customer site growth.
Net Income
We use income from core operations to distinguish operating results from the Company's water, electricity and natural gas businesses from results with respect to its investment in Capital Power and changes in the fair value of financial instruments. The change in the fair value of financial instruments is the difference between the opening fair value of the derivative instruments for the period and the closing fair value of the derivative instruments. Income from core operations is a non-IFRS financial measure which does not have any standardized meaning prescribed by IFRS and is unlikely to be comparable to similar measures published by other entities. However, it is presented below as it provides a useful income performance measure of the Company's core business operations and may be referred to by debtholders and other interested parties in evaluating the Company's financial performance and in assessing its creditworthiness.
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Three Six
months Months
(Unaudited, $ millions)
----------------------------------------------------------------------------
Net income for the period ended June 30, 2016 $ 67 $ 145
2016 change in the fair value of contracts-for-
difference 3 (2)
2016 change in the fair value of interest rate
swaps 2 7
2016 dividend income from available-for-sale
investment in Capital Power (4) (7)
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2016 income from core operations 68 143
Lower Water Services segment operating income (13) (30)
Lower Distribution and Transmission segment
operating income (3) (22)
Lower Energy Services segment operating income
excluding change in the fair value of contracts-
for-differences (3) (6)
Lower income tax expense 2 5
Other 1 -
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Decrease in income from core operations (16) (53)
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2017 income from core operations 52 90
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2017 change in the fair value of contracts-for-
difference 4 3
2017 fair value gain on available-for-sale
investment in Capital Power reclassified from
other comprehensive income - 1
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Net income for the period ended June 30, 2017 $ 56 $ 94
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Changes in each business segment's operating results compared with the corresponding periods in 2016 are described in Segment Results below. Explanations of the remaining variances in net income for the three and six months ended June 30, 2017, are as follows:
-- Greater favorable changes in the fair value of contracts-for-
differences.
-- Unfavorable fair value adjustments related to interest rate swaps for
the three months and six months ended June 30, 2016, with no
corresponding adjustments in 2017 due to the settlement of the interest
rate swaps.
-- No dividend income from the Capital Power shares recognized for the
three months and six months ended June 30, 2017, compared with the
corresponding periods in 2016, due to the sale of the remaining shares
in January 2017.
-- Recognition of a fair value gain on sale of its remaining investment in
Capital Power in January 2017 with no corresponding transaction in 2016.
-- Income tax expense was lower for the three and six months ended June 30,
2017, compared with the corresponding periods in 2016, primarily due to
decreased tax expense in the Water Services segment resulting from lower
industrial services contract income in Canada.
SEGMENT RESULTS
Water Services
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(Unaudited, $ millions,
including intersegment Three months ended Six months ended
transactions) June 30, June 30,
-------------------------- --------------------------
2017 2016 2017 2016
------------------------------------------------- --------------------------
Revenues $ 158 $ 174 $ 294 $ 325
Expenses (112) (115) (218) (219)
------------------------------------------------- --------------------------
Operating income $ 46 $ 59 $ 76 $ 106
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Water Services' operating income decreased by $13 million and $30 million for the three and six months ended June 30, 2017, respectively, compared with the corresponding periods in 2016, primarily due to lower income related to industrial services contracts, lower water and wastewater volumes due to higher precipitation in the city of Edmonton, higher water treatment costs due to poor river quality conditions in the city of Edmonton and higher depreciation and staff costs, partially offset by growth and higher customer rates. In addition, the first quarter of 2016 included gains from the sale of surplus land.
Distribution and Transmission
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(Unaudited, $ millions,
including intersegment Three months ended Six months ended
transactions) June 30, June 30,
-------------------------- --------------------------
2017 2016 2017 2016
------------------------------------------------- --------------------------
Revenues $ 177 $ 164 $ 336 $ 320
Expenses (155) (139) (294) (256)
------------------------------------------------- --------------------------
Operating income $ 22 $ 25 $ 42 $ 64
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Distribution and Transmission's operating income decreased by $3 million for the three months ended June 30, 2017, compared with the corresponding period in 2016, primarily due to loss on sale of surplus land and lower income from commercial services, partially offset by higher net system access service collections and electricity transmission customer rates.
Distribution and Transmission's operating income decreased by $22 million for the six months ended June 30, 2017, compared with the corresponding period in 2016, primarily due to lower net system access service collections, loss on sale of surplus land and lower income from commercial services, partially offset by higher electricity distribution and transmission rates.
Energy Services
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(Unaudited, $ millions,
including intersegment Three months ended Six months ended
transactions) June 30, June 30,
------------------------ ------------------------
2017 2016 2017 2016
--------------------------------------------------- ------------------------
Revenues $ 191 $ 188 $ 401 $ 405
Expenses (180) (181) (381) (380)
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Operating income 11 7 20 25
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Exclude change in the fair
value of contracts-for-
differences (4) 3 (3) (2)
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Operating income excluding
change in the fair value
of contracts-for-
differences $ 7 $ 10 $ 17 $ 23
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Energy Services' operating income excluding change in the fair value of contracts-for-differences decreased by $3 million and $6 million for the three and six months ended June 30, 2017, respectively, compared with the corresponding periods in 2016, primarily due to lower Energy Price Setting Plan margins.
Capital Spending and Investment
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(Unaudited, $ millions)
Six months ended June 30, 2017 2016
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Water Services $ 83 $ 79
Distribution and Transmission 118 126
Energy Services 2 2
Corporate 3 3
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206 210
Business acquisition 46 -
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Total capital spending and investment $ 252 $ 210
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Total capital spending and investment was higher for the six months ended June 30, 2017, compared with the corresponding period in 2016, primarily due to the acquisition of Hughes and increased spending in the Water segment on the Gold Bar Hydrovac Sanitary Waste Facility project as well as various projects in the U.S. This was partially offset by decreased spending in the Water Services segment due to the Gold Bar Grit Tanks project being substantially completed and placed into service in 2016. The Distribution and Transmission segment had decreased spending on various growth and lifecycle projects which was only partially offset by increased spending on renovations to its major work center.
CONSOLIDATED STATEMENTS OF FINANCIAL POSITION - ASSETS
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(Unaudited, $ June 30,December 31, Increase Explanation of material
millions) 2017 2016 (decrease) changes
----------------------------------------------------------------------------
Cash and cash $ 14 $ 191 $ (177) Refer to Consolidated
equivalents Statements of Cash Flows
section.
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Trade and 479 325 154 Increase primarily due to
other reclassification of the
Receivables current portion of the
Capital Power receivable
related to the back-to-
back debt ($174 million),
partially offset by a
decrease in electricity
accruals.
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Available-for- - 6 (6) Decrease due to sale of
sale the remaining Capital
investment in Power shares.
Capital Power
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Derivatives 1 - 1
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Inventories 15 14 1
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Other 92 265 (173) Decrease due to
financial reclassification of the
assets current portion of the
Capital Power receivable
related to the back-to-
back debt to trade and
other receivables ($174
million), net of
construction financing.
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Deferred tax 85 84 1
assets
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Property, 5,133 4,983 150 Increase primarily due to
plant and the acquisition of Hughes
equipment and capital expenditures,
partially offset by
unfavorable foreign
currency valuation
adjustments, depreciation
and asset disposals and
retirements.
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Intangible 286 293 (7) Decrease primarily due to
assets and amortization of assets
goodwill with finite lives and
unfavorable foreign
currency valuation
adjustments, partially
offset by the acquisition
of Hughes and capital
expenditures.
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CONSOLIDATED STATEMENTS OF FINANCIAL POSITION - LIABILITIES AND EQUITY
----------------------------------------------------------------------------
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(Unaudited,
$ June 30, December 31, Increase Explanation of material
millions) 2017 2016 (decrease) changes
----------------------------------------------------------------------------
Trade and $238 $299 $(61) Decrease primarily due to
other lower electricity and
payables capital accruals as well
as payments and release
of holdbacks on the
Regina wastewater
treatment plant project,
partially offset by an
increase in electricity
delivery service charges
payable.
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Loans and 1,913 1,920 (7) Decrease primarily due to
borrowings repayment of long-term
(including debt and favorable
current foreign currency
portion) valuation adjustments on
U.S. dollar denominated
debt, partially offset by
Hughes acquisition
assumption of debt.
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Deferred 1,044 1,041 3 Increase primarily due to
revenue(in contributions received
cluding from developers,
current partially offset by
portion) revenue recognized and
favorable foreign
currency valuation
adjustments.
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Provisions 107 111 (4) Decrease primarily due to
(including payment of employee
current benefits in excess of
portion) accruals and favorable
foreign currency
valuation adjustments,
partially offset by net
receipts of refundable
contributions from
customers and developers.
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Other 78 72 6 Increase primarily due to
liabilitie contingent consideration
s(includin recorded on the
g current acquisition of Hughes,
portion) partially offset by
favorable foreign
currency valuation
adjustments.
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Deferred 49 46 3
tax
liabilitie
s
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Equity 2,676 2,672 4 Increase due to
attributab comprehensive income for
le to the the period, partially
Owner of offset by dividends paid.
the
Company
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CONSOLIDATED STATEMENTS OF CASH FLOWS
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(Unaudited, $ millions)
Cash inflows (outflows)
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Three months
ended Increase
June 30, 2017 2016 (decrease) Explanation
----------------------------------------------------------------------------
Operating $ 50 $ 87 $ (37) Decrease primarily due to
lower funds from the
change in non-cash
operating working capital
resulting from an
increase in trade and
other receivables and a
decrease in trade and
other payables, partially
offset by higher funds
from operations due
primarily to a decrease
in the change in employee
benefit provisions.
Investing (140) (109) (31) Decrease is primarily due
to acquisition of Hughes,
lower change in non-cash
investing working capital
and lower distributions
from Capital Power,
partially offset by lower
capital expenditures and
lower advances on
construction financing.
Financing (39) 15 (54) Decrease is primarily due
to proceeds from the net
issuance of short-term
debt in the second
quarter of 2016 and
higher dividend payments
to the City in 2017.
Opening cash 143 36 107
and cash
equivalents
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Closing cash $ 14 $ 29 $ (15)
and cash
equivalents
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(Unaudited, $ millions)
Cash inflows (outflows)
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Six months
ended Increase
June 30, 2017 2016 (decrease) Explanation
----------------------------------------------------------------------------
Operating $ 132 $ 223 $ (91) Decrease primarily due to
lower funds from
operations as a result of
reduced net income and
lower funds from the
change in non-cash
operating working capital
resulting from a lower
decrease in trade and
other receivables and a
higher decrease in trade
and other payables.
Investing (231) (26) (205) Decrease is primarily due
to lower payments related
to long-term loans
receivable from Capital
Power, lower payments
from Regina due to
receipt of the milestone
payment in the first
quarter of 2016,
acquisition of Hughes,
lower change in non-cash
investing working
capital, lower proceeds
from the disposal of
assets and lower
distributions from
Capital Power, partially
offset by lower advances
on construction financing
and proceeds from the
sale of the remaining
shares of Capital Power.
Financing (78) (204) 126 Increase is primarily due
to higher repayment of
long-term debt in 2016,
partially offset by
higher dividend payments
to the City in 2017.
Opening cash 191 36 155
and cash
equivalents
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Closing cash $ 14 $ 29 $ (15)
and cash
equivalents
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Operating Activities and Liquidity
The Company maintains its financial position through rate-regulated utility and contracted operations which generate stable cash flows.
The Company expects to have sufficient liquidity to finance its plans and fund its obligations for the remainder of 2017 with a combination of cash on hand, cash flow from operating activities, the issuance of commercial paper, public or private debt offerings and draws upon existing credit facilities described below under Financing.
Cash flows from operating activities would be impaired by events that cause severe damage to our facilities and would require unplanned cash outlays for system restoration repairs. Under those circumstances, more reliance would be placed on our credit facilities for working capital requirements until a regulatory approved recovery mechanism or insurance proceeds are put in place.
Capital Requirements and Contractual Obligations
As a result of the acquisition of Hughes in June 2017, the Company is committed to pay a fee to the previous owners of Hughes based on the addition of new customer connections above a minimum of 600 incremental customer connections over a period of six years from the date of closing. The fee is capped at US$8 million. The Company also assumed existing third party debt with a fair value of $13 million as part of transaction. A portion of the assumed debt has been settled and the remaining debt has terms-to-maturity of up to four years at interest rates ranging between 4.51% and 7.00% per annum and certain of the Hughes assets are pledged as security.
In April 2017, Edmonton City Council approved the transfer of Drainage to EPCOR as described in the Significant Events section. Under the proposed terms, EPCOR expects to increase the dividend paid to the City by $20 million in 2018 and by a prorated amount in 2017, subject to Board and Shareholder approval. In addition, the Company will pay $75 million to the City over a period of time to be determined by the City to compensate the City for stranded costs related to the transfer. EPCOR will become responsible for future capital costs and assume responsibility for approximately $600 million to $650 million in current drainage-related City debt through a back-to-back agreement with the City. For the first full year of operations, capital spending, net of contributions, is expected to be approximately $120 million to $200 million.
The timing of the total commitment of $91 million for several Distribution and Transmission projects, as directed by Alberta Electricity System Operator, has changed since the fourth quarter of 2016 to $2 million in 2017, $38 million in 2018, $46 million in 2019 and $5 million in 2020.
During the first half of 2017 there were no other material changes to the Company's capital requirements or purchase obligations, including payments for the next five years and thereafter, as previously disclosed in the 2016 annual MD&A.
Financing
Generally, our external capital is raised at the corporate level and invested in the operating business units. Our external financing consists of commercial paper issuance, borrowings under committed syndicated bank credit facilities, debentures payable to the City, publicly issued medium-term notes, U.S. private-debt notes and issuance of preferred shares.
The Company assumed third party debt as a result of the Hughes acquisition; refer to Capital Requirements and Contractual Obligations section for additional information.
The Company has bank credit facilities, which are used principally for the purpose of backing the Company's commercial paper program and providing letters of credit, as outlined below:
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Letters of
(Unaudited, credit and
$ millions) Banking other Net
June 30, Total commercial facility amounts
2017 Expiry facilities paper issued draws available
----------------------------------------------------------------------------
Committed
Syndicated
bank credit November
facility(1) 2019 $ 200 $ - $ 58 $ 142
Syndicated
bank credit November
facility 2020 350 - - 350
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Total
committed 550 - 58 492
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Uncommitted
Bank line of
credit No expiry 25 - - 25
----------------------------------------------------------------------------
Total credit
facilities $ 575 $ - $ 58 $ 517
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Letters of
(Unaudited, credit and
$ millions) Banking other Net
December 31, Total commercial facility amounts
2016 Expiry facilities paper issued draws available
----------------------------------------------------------------------------
Committed
Syndicated
bank credit November
facility(1) 2019 $ 200 $ - $ 73 $ 127
Syndicated
bank credit November
facility 2020 350 - - 350
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Total
committed 550 - 73 477
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Uncommitted
Bank line of
credit No expiry 25 - - 25
----------------------------------------------------------------------------
Total credit
facilities $ 575 $ - $ 73 $ 502
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(1) Restricted to letters of credit.
Letters of credit are issued to meet the credit requirements of energy market participants and conditions of certain service agreements. Letters of credit totaling $58 million (December 31, 2016 - $73 million) were issued and outstanding at June 30, 2017.
The committed syndicated bank credit facilities cannot be withdrawn by the lenders until expiry, provided that the Company operates within the related terms and covenants. The extension feature of EPCOR's committed syndicated bank credit facilities gives the Company the option each year to re-price and extend the terms of the facilities by one or more years subject to agreement with the lending syndicate. The Company regularly monitors market conditions and may elect to enter into negotiations to extend the maturity dates.
The Company has a Canadian base shelf prospectus under which it may raise up to $1 billion of debt with maturities of not less than one year. At June 30, 2017, the available amount remaining under this base shelf prospectus was $1 billion (December 31, 2016 - $1 billion). The base shelf prospectus expires in December 2017.
No commercial paper was issued and outstanding at June 30, 2017 (December 31, 2016 - nil).
If the economy were to deteriorate in the longer term, particularly in Canada and the U.S., the Company's ability to extend the maturity or revise the terms of bank credit facilities, arrange long-term financing for its capital expenditure programs and acquisitions, or refinance outstanding indebtedness when it matures could be adversely impacted. We believe that these circumstances have a low probability of occurring. We continually monitor our capital programs and operating costs to minimize the risk that the Company becomes short of cash or unable to honor its debt servicing obligations. If required, the Company would look to reduce capital expenditures and operating costs.
Credit Rating
In August 2016, DBRS confirmed its A (low) / stable senior unsecured debt and R-1 (low) / stable short-term debt ratings for EPCOR and Standard & Poor's Ratings Services confirmed its A- / stable long-term corporate credit and senior unsecured debt ratings for EPCOR. We do not anticipate any changes to EPCOR's credit ratings due to the transfer of Drainage.
Financial Covenants
EPCOR is currently in compliance with all of its financial covenants in relation to its syndicated bank credit facilities, Canadian public medium-term notes and U.S. private debt notes. Based on current financial covenant calculations, the Company has sufficient borrowing capacity to fund current and long-term requirements. Although the risk is low, breaching these covenants could potentially result in a revocation of EPCOR's credit facilities causing a significant loss of access to liquidity or resulting in the Company's publicly issued medium-term notes and private debt notes becoming immediately due and payable thereby causing the Company to find a means of funding which could include the sale of assets.
For further information on the Company's contractual obligations, refer to the 2016 annual MD&A.
RISK MANAGEMENT
This section should be read in conjunction with the Risk Management section of the 2016 annual MD&A. EPCOR believes that risk management is a key component of the Company's culture and we have put cost-effective risk management practices into place. At the same time, EPCOR views risk management as an ongoing process and we continually review our risks and look for ways to enhance our risk management processes.
As part of ongoing risk management practices, the Company reviews current and proposed transactions to consider their impact on the risk profile of the Company. EPCOR's risk profile and risk management strategies as described in the 2016 annual MD&A have been updated to reflect the transfer of Drainage, the Hughes acquisition and the anticipated acquisition of Natural Resource Gas Limited (NRGL).
Currently, EPCOR's risks include new business integration, strategy execution risk, political and legislative risk, regulatory risk, health and safety risk, information technology related security risks, risk of reputational damage, environment risk, business interruption risks, failure to attract, retain or develop top talent, water scarcity risk, electricity price and volume risk, project risk, weather risk, financial liquidity risk, counterparty and credit risk, billing error risk, foreign exchange risk, conflicts of interest, and general economic conditions, business environment and other risks.
The following risk has been revised since issuance of the 2016 annual MD&A as follows:
New Business Integration Risk
EPCOR plans to diversify its utility infrastructure investments across investment types and North American geographies to reduce investment risk. The Company is planning to accomplish this through expansion into the natural gas distribution and drainage utility businesses as well as new geographies.
These types of utility businesses are new to EPCOR which introduces risk to the Company due to potential unfamiliarity with the associated operational, safety and regulatory risks in addition to the risks associated with integrating these businesses into EPCOR.
In April 2017, the City approved the transfer of its Drainage utility to EPCOR. The transfer will be material to the Company due to the size of the utility, requiring substantial efforts to successfully integrate the operations into EPCOR. The integration will encompass many important elements that must be completed successfully. In addition, the Company may be integrating NRGL concurrently with the Drainage integration along with the ongoing integration of Hughes. Failing to successfully integrate these new businesses and the resultant effects on the Company, including reputational impact, make this EPCOR's most significant risk at the current time.
EPCOR has developed comprehensive integration plans and integration of the Drainage and natural gas distribution businesses will be a top priority for the Company, ensuring that personnel with appropriate skills are in place to operate the businesses safely and properly immediately upon becoming part of EPCOR.
Litigation Update
The Company is not involved in any material litigation at this time.
FUTURE ACCOUNTING STANDARD CHANGES
A number of new standards, amendments to standards and interpretations have been issued by the IASB and the International Financial Reporting Interpretations Committee the application of which is effective for periods beginning on or after January 1, 2018. Those which may be relevant to the Company and may impact the accounting policies of the Company are set out below. The Company does not plan to adopt these standards early.
IFRS 9 - Financial Instruments (IFRS 9), which replaces IAS 39 - Financial Instruments: Recognition and Measurement, eliminates the existing classification of financial assets and requires financial assets to be measured based on the business model in which they are held and the characteristics of their contractual cash flows. The effective date for implementation of IFRS 9 has been set for annual periods beginning on or after January 1, 2018. Based on the Company's existing financial instruments, the Company is currently evaluating the impact of the application of IFRS 9 but does not expect it to have a significant impact on its consolidated financial statements.
IFRS 15 - Revenue from Contracts with Customers (IFRS 15), which replaces IAS 11 - Construction Contracts and IAS 18 - Revenue and related interpretations, is effective for annual periods commencing on or after January 1, 2018. IFRS 15 introduces a new single revenue recognition model for contracts with customers and two approaches to recognizing revenue: at a point in time or over time. The model features a contract-based five-step analysis of transactions to determine whether, how much and when revenue is recognized. The Company has developed an implementation plan and is currently performing detailed analysis on each revenue stream and the underlying contracts with customers to determine the impact of IFRS 15 on the consolidated financial statements. A significant portion of the Company's revenue is generated from the provision of utility goods and services that are simultaneously received and consumed by customers. Therefore, the Company will continue to recognize utility revenue over time as the goods and services are provided because the output method of revenue recognition depicts the entity's performance towards complete satisfaction of its performance obligation. For other contracts with customers, analysis is ongoing and the Company expects to report more detailed information, including estimated quantitative impacts, in future periods.
IFRS 16 - Leases (IFRS 16), which replaces IAS 17 - Leases (IAS 17), is effective for annual periods commencing on or after January 1, 2019. IFRS 16 combines the existing dual model of operating and finance leases in IAS 17 into a single lessee model. The Company is currently reviewing contracts that are identified as leases in order to evaluate the impact of adoption of IFRS 16 on the consolidated financial statements. Based on its preliminary assessment the Company expects that there will be a material impact on its statements of financial position requiring the recognition of lease assets and lease obligations with respect to its leases for office space, which are currently classified as operating leases.
IFRIC 23 - Uncertainty over Income Tax Treatments is effective for annual periods commencing on or after January 1, 2019. The interpretation provides guidance on the recognition and measurement of current and deferred tax assets and liabilities under IAS 12 when there is uncertainty over income tax treatments. The Company does not expect a material impact on initial application of the interpretation however the interpretation may impact the Company's recognition, measurement and disclosure of uncertain tax treatments in the future.
CRITICAL ACCOUNTING ESTIMATES
In preparing the condensed consolidated interim financial statements, management necessarily made judgments and estimates in determining transaction amounts and financial statement balances. The following are the items for which significant estimates were made in the condensed consolidated interim financial statements: electricity revenues and costs, unbilled consumption of electricity and water, fair values and income taxes. Although the current condition of the economy has not impacted our methods of estimating accounting values, it has impacted the inputs in those determinations and the resulting values. Interim results will fluctuate due to the seasonal demands for electricity and water, changes in electricity prices, and the timing and recognition of regulatory decisions. Consequently, interim results are not necessarily indicative of annual results.
For further information on the Company's other critical accounting estimates, refer to the 2016 annual consolidated financial statements and 2016 annual MD&A.
OUTLOOK
For the remainder of 2017, EPCOR will focus on the transfer and integration of the Drainage utility as well as the integration of Hughes and the expected closing of NRGL. In addition, we will continue to target growth in rate-regulated water, wastewater, electricity and natural gas infrastructure. We expect much of this investment to come from new infrastructure to accommodate customer growth and lifecycle replacement of existing infrastructure primarily related to the Edmonton and U.S. based operations. EPCOR intends to expand our water and electricity commercial services activities and to invest in the area of renewable energy generation, including solar and biogas facilities to power our operations and enhance our environmental performance.
EPCOR is proposing to build a new solar farm just south of its existing E.L. Smith Water Treatment Plant (E.L. Smith WTP). The proposed solar farm will generate "green" energy to help power the existing E.L. Smith WTP and its water treatment and distribution processes, while reducing our greenhouse gas emissions. The solar farm is expected to have a peak generation capacity of approximately 12 megawatts. In May 2017, EPCOR submitted a Land Development Application to the City for approval to rezone the area as the zoning will need to be changed to Public Utility in order to build the solar farm on this site. Once EPCOR has received initial input from the public, EPCOR will submit an application to the Alberta Utilities Commission (AUC) for approval to build and operate the new solar farm. If approved by the City and the AUC, construction is anticipated to begin in the first half 2018 with construction expected to be completed in the fourth quarter of 2018.
In November 2016, the Company entered into a definitive asset purchase agreement to acquire substantially all of the assets of NRGL for consideration of $21 million, subject to certain adjustments. NRGL is a natural gas distributor in southwestern Ontario near London, providing services to approximately 8,000 residential, commercial and industrial customers in the counties of Elgin, Middlesex, Oxford and Norfolk. The Ontario Energy Board (OEB) is currently reviewing the application for approval of this arrangement and the Company expects to complete the transaction in the second half of 2017.
EPCOR has been awarded franchises by three municipalities in the Southern Bruce region of Ontario near Kincardine to build and operate a natural gas distribution system. In March 2016 EPCOR applied to the OEB for the approval of these franchise agreements. In January 2017 the OEB requested indications of interest from any parties interested in servicing these areas and the OEB is developing a process for adjudicating competing applications. It is not clear at this time when the OEB will finalize and hold its competitive process.
Over the long-term, demand for water is expected to increase and we anticipate escalating requirements for better water management practices including watershed management and conservation. We will pursue expansion of our portfolio of commercial water contracts.
In December 2016, the Government of Alberta passed Bill 21: the Modernized Municipal Government Act (MGA) which could impose restrictions on the ability of a Municipally Controlled Corporation (MCC) to conduct its business. EPCOR, which is a MCC of the City of Edmonton, was previously exempted by regulation from the MGA and a similar exemption by way of regulation has not as of yet been tabled. EPCOR is working to ensure the previous exemption is re-instated as the related regulations are developed. Not having an exemption from the MGA could materially impact EPCOR's ability to execute on its Long Term Plan.
QUARTERLY RESULTS
---------------------------------------------------------------------------- ---------------------------------------------------------------------------- (Unaudited, $ millions) Quarters ended Revenues Net income ---------------------------------------------------------------------------- June 30, 2017 $ 474 $ 56 March 31, 2017 455 38 December 31, 2016 474 88 September 30, 2016 504 76 June 30, 2016 479 67 March 31, 2016 475 78 December 31, 2015 523 65 September 30, 2015 511 (13) ----------------------------------------------------------------------------
Events for the past eight quarters compared to the same quarter of the prior year that have significantly impacted net income include:
-- June 30, 2017, second quarter results included lower income related to
industrial services contracts, lower Energy Price Setting Plan margins,
a loss on sale of surplus land, lower water and wastewater volumes due
to higher precipitation in the city of Edmonton, higher water treatment
costs due to poor river quality conditions in the city of Edmonton and
no dividend income due to the sale of Capital Power shares. Partially
offsetting these decreases were favorable fair value adjustments related
to financial electricity purchase contracts in 2017 and unfavorable fair
value adjustments related to interest swaps in 2016 with no
corresponding transaction in the current year, higher electricity
transmission, water and wastewater rates and higher net system access
service collections.
-- March 31, 2017, first quarter results included unfavorable fair value
adjustments related to financial electricity purchase contracts and no
dividend income due to the sale of Capital Power shares, lower net
system access collections, lower gains as a result of sales of surplus
land in the first quarter of 2016, lower income related to industrial
services contracts and lower Energy Price Setting Plan margins.
Partially offsetting these decreases was higher water, wastewater and
electricity distribution and transmission rates and an unfavorable fair
value adjustment related to interest swaps in the first quarter of 2016.
-- December 31, 2016, fourth quarter results included the recognition of
the fair value gain resulting from the sale of Capital Power shares,
greater favorable fair value adjustments related to financial
electricity purchase contracts and interest rate swaps and higher
approved electricity distribution, water and wastewater rates, partially
offset by lower electricity transmission customer rates, lower billing
charge rates, higher depreciation and lower income related to industrial
services contracts.
-- September 30, 2016 third quarter results included greater favorable fair
value adjustments related to financial electricity purchase contracts,
the recognition of the fair value gain resulting from the sale of the
Capital Power shares, and higher approved electricity, water and
wastewater rates, partially offset by lower billing charge rates and
higher depreciation. In addition, 2015 included an impairment of the
Capital Power shares.
-- June 30, 2016 second quarter results included lower favorable fair value
adjustments related to financial electricity purchase contracts and
interest rate swaps and excluded any gains related to Capital Power.
These decreases were partially offset by higher approved electricity,
water and wastewater rates and higher income related to industrial
services contracts.
-- March 31, 2016 first quarter results included higher approved
electricity, water and wastewater rates, gains on sales of surplus
lands, higher income related to industrial services contracts, and
higher dividend income from Capital Power. This was partially offset by
no equity share of income of Capital Power, and lower favorable fair
value adjustments on financial electricity purchase contracts.
-- December 31, 2015 fourth quarter results included an impairment of the
available-for-sale investment in Capital Power, no equity share of
income of Capital Power and lower deferred income tax recovery. This was
partially offset by higher approved electricity, water and wastewater
rates, higher billing charge rates, higher customer water consumption,
and greater favorable fair value adjustments on financial electricity
purchase contracts.
-- September 30, 2015 third quarter results included the impairment of the
available-for-sale investment in Capital Power and unfavorable fair
value adjustments related to the financial electricity purchase
contracts, partially offset by higher approved electricity, water and
wastewater rates, higher billing charge rates, and higher Energy Price
Setting Plan margins.
FORWARD-LOOKING INFORMATION
Certain information in this MD&A is forward-looking within the meaning of Canadian securities laws as it relates to anticipated financial performance, events or strategies. When used in this context, words such as "will", "anticipate", "believe", "plan", "intend", "target", and "expect" or similar words suggest future outcomes.
The purpose of forward-looking information is to provide investors with management's assessment of future plans and possible outcomes and may not be appropriate for other purposes. Material forward-looking information within this MD&A, including related material factors or assumptions and risk factors, are noted in the table below:
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Forward-looking Material Factors or Risk Factors
Information Assumptions
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The Company expects to EPCOR is able to generate EPCOR's operations do not
have sufficient the expected cash flow generate the expected
liquidity to finance from operations and level of cash flow and /
its plans and fund its various means of funding or circumstances arise
obligations in 2017. remain available to the limiting or restricting
Company. the Company's ability to
access funds through the
various means otherwise
available.
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Drainage will be Transfer takes place on Estimated transfer date
transferred under the the estimated transfer changes.
proposed terms, date and under the Transfer or terms are
including the estimated proposed terms. varied.
transfer date: Actuals vary from
estimated amounts.
EPCOR expects to
increase the dividend
paid to the City by $20
million in 2018 and by
a prorated amount in
2017, subject to Board
and Shareholder
approval.
In addition, the Company
will pay $75 million to
the City over a period
of time to be
determined by the City
to compensate the City
for stranded costs
related to the
transfer.
EPCOR will become
responsible for future
capital costs and
assume responsibility
for approximately $600
million to $650 million
in current drainage-
related City debt
through a back-to-back
agreement with the
City.
For the first full year
of operations, capital
spending, net of
contributions, is
expected to be
approximately $120
million to $200
million.
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Whether actual results, performance or achievements will conform to the Company's expectations and predictions is subject to a number of known and unknown risks and uncertainties which could cause actual results to differ from expectations and are identified in the Risk Management section above.
Readers are cautioned not to place undue reliance on forward-looking statements as actual results could differ materially from the plans, expectations, estimates or intentions expressed in the forward-looking statements. Except as required by law, EPCOR disclaims any intention and assumes no obligation to update any forward-looking statement even if new information becomes available, as a result of future events or for any other reason.
ADDITIONAL INFORMATION
Additional information relating to EPCOR including the Company's 2016 Annual Information Form is available on SEDAR at www.sedar.com.
Contacts:
Media Relations:
Tim le Riche
(780) 969-8238
tleriche@epcor.com
Corporate Relations:
Claudio Pucci
(780) 969-8245 or toll free (877) 969-8280
cpucci@epcor.com
