Companies: 10,652     total market cap: $139.320 T
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Eversource Energy
ES
#930
Rank
$25.93 B
Marketcap
๐Ÿ‡บ๐Ÿ‡ธ United States
Country
$69.13
Share price
0.30%
Change (1 day)
21.09%
Change (1 year)
๐Ÿ”‹ Electricity๐Ÿšฐ Utility companies โšก Energy
Categories
  1. Eversource Energy
  2. Quarterly Reports (10-Q)
  3. Financial Year FY2019 Q2

Eversource Energy - 10-Q quarterly report FY2019 Q2


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eversourcelogo.jpg
 

UNITED STATES SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
 
FORM
10-Q
☒
QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE
SECURITIES EXCHANGE ACT OF 1934
 
For the Quarterly Period Ended
June 30, 2019
 
or
☐
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE     
SECURITIES EXCHANGE ACT OF 1934
 

For the transition period from ____________ to ____________

Registrant; State of Incorporation; Address; Telephone Number;
Commission File Number; and I.R.S. Employer Identification No.


EVERSOURCE ENERGY
(a Massachusetts voluntary association)
300 Cadwell Drive, Springfield, Massachusetts 01104
Telephone: (800) 286-5000
Commission File Number: 1-5324
I.R.S. Employer Identification No. 04-2147929


THE CONNECTICUT LIGHT AND POWER COMPANY
(a Connecticut corporation)
107 Selden Street, Berlin, Connecticut 06037-1616
Telephone: (800) 286-5000
Commission File Number: 0-00404
I.R.S. Employer Identification No. 06-0303850


NSTAR ELECTRIC COMPANY
(a Massachusetts corporation)
800 Boylston Street, Boston, Massachusetts 02199
Telephone: (800) 286-5000
Commission File Number: 1-02301
I.R.S. Employer Identification No. 04-1278810


PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE
(a New Hampshire corporation)
Energy Park
780 North Commercial Street, Manchester, New Hampshire 03101-1134
Telephone: (800) 286-5000
Commission File Number: 1-6392
I.R.S. Employer Identification No. 02-0181050

 
Securities registered pursuant to Section 12(b) of the Act:
 
 
 
 
 
Title of each class
 
Trading Symbol(s)
 
Name of each exchange on which registered
Common Shares, $5.00 par value per share
 
ES
 
New York Stock Exchange

Indicate by check mark whether the registrants (1) have filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrants were required to file such reports), and (2) have been subject to such filing requirements for the past 90 days.
 
Yes
No
 
☒
☐

Indicate by check mark whether the registrants have submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrants were required to submit such files).
 
Yes
No
 
☒
☐

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.
Eversource Energy
Large accelerated filer
☒
Accelerated
filer
☐
Non-accelerated
filer
☐
Smaller reporting company
☐
Emerging growth company
☐
The Connecticut Light and Power Company
Large accelerated filer
☐
Accelerated
filer
☐
Non-accelerated filer
☒
Smaller reporting company
☐
Emerging growth company
☐
NSTAR Electric Company
Large accelerated filer
☐
Accelerated
filer
☐
Non-accelerated filer
☒
Smaller reporting company
☐
Emerging growth company
☐
Public Service Company of New Hampshire
Large accelerated filer
☐
Accelerated
filer
☐
Non-accelerated filer
☒
Smaller reporting company
☐
Emerging growth company
☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ¨

Indicate by check mark whether the registrants are shell companies (as defined in Rule 12b-2 of the Exchange Act):
 
Yes
No
 
 
 
Eversource Energy
☐
☒
The Connecticut Light and Power Company
☐
☒
NSTAR Electric Company
☐
☒
Public Service Company of New Hampshire
☐
☒

Indicate the number of shares outstanding of each of the registrant's classes of common stock, as of the latest practicable date:
Company - Class of Stock
Outstanding as of July 31, 2019
 
 
 
Eversource Energy Common Shares, $5.00 par value
323,602,045

shares
The Connecticut Light and Power Company Common Stock, $10.00 par value
6,035,205

shares
NSTAR Electric Company Common Stock, $1.00 par value
200

shares
Public Service Company of New Hampshire Common Stock, $1.00 par value
301

shares

Eversource Energy holds all of the 6,035,205 shares, 200 shares, and 301 shares of the outstanding common stock of The Connecticut Light and Power Company, NSTAR Electric Company, and Public Service Company of New Hampshire, respectively.

NSTAR Electric Company and Public Service Company of New Hampshire each meet the conditions set forth in General Instructions H(1)(a) and (b) of Form 10-Q, and each is therefore filing this Form 10-Q with the reduced disclosure format specified in General Instruction H(2) of Form 10‑Q.

Eversource Energy, The Connecticut Light and Power Company, NSTAR Electric Company, and Public Service Company of New Hampshire each separately file this combined Form 10-Q.  Information contained herein relating to any individual registrant is filed by such registrant on its own behalf.  Each registrant makes no representation as to information relating to the other registrants.



GLOSSARY OF TERMS

The following is a glossary of abbreviations and acronyms that are found in this report:
Current or former Eversource Energy companies, segments or investments:
Eversource, ES or the Company
Eversource Energy and subsidiaries
Eversource parent or ES parent
Eversource Energy, a public utility holding company
ES parent and other companies
ES parent and other companies are comprised of Eversource parent, Eversource Service, Eversource Water Ventures, Inc. (parent company of Aquarion), and other subsidiaries, which primarily includes our unregulated businesses, HWP Company, The Rocky River Realty Company (a real estate subsidiary), the consolidated operations of CYAPC and YAEC, and Eversource parent's equity ownership interests that are not consolidated
CL&P
The Connecticut Light and Power Company
NSTAR Electric
NSTAR Electric Company
PSNH
Public Service Company of New Hampshire
PSNH Funding
PSNH Funding LLC 3, a bankruptcy remote, special purpose, wholly-owned subsidiary of PSNH
NSTAR Gas
NSTAR Gas Company
Yankee Gas
Yankee Gas Services Company
Aquarion
Eversource Aquarion Holdings, Inc. and its subsidiaries
NPT
Northern Pass Transmission LLC
Northern Pass
The HVDC and associated alternating-current transmission line project from Canada into New Hampshire
Eversource Service
Eversource Energy Service Company
Bay State Wind
Bay State Wind LLC, an offshore wind business being developed jointly by Eversource and Denmark-based Ørsted, which holds the Sunrise Wind project
North East Offshore
North East Offshore, LLC, an offshore wind business being developed jointly by Eversource and Denmark-based Ørsted, which holds the Revolution Wind and South Fork Wind projects
CYAPC
Connecticut Yankee Atomic Power Company
MYAPC
Maine Yankee Atomic Power Company
YAEC
Yankee Atomic Electric Company
Yankee Companies
CYAPC, YAEC and MYAPC
Regulated companies
The Eversource regulated companies are comprised of the electric distribution and transmission businesses of CL&P, NSTAR Electric and PSNH, the natural gas distribution businesses of Yankee Gas and NSTAR Gas, NPT, Aquarion, and the solar power facilities of NSTAR Electric
Regulators:
 
DEEP
Connecticut Department of Energy and Environmental Protection
DOE
U.S. Department of Energy
DOER
Massachusetts Department of Energy Resources
DPU
Massachusetts Department of Public Utilities
EPA
U.S. Environmental Protection Agency
FERC
Federal Energy Regulatory Commission
ISO-NE
ISO New England, Inc., the New England Independent System Operator
MA DEP
Massachusetts Department of Environmental Protection
NHPUC
New Hampshire Public Utilities Commission
PURA
Connecticut Public Utilities Regulatory Authority
SEC
U.S. Securities and Exchange Commission
SJC
Supreme Judicial Court of Massachusetts
Other Terms and Abbreviations:
ADIT
Accumulated Deferred Income Taxes
AFUDC
Allowance For Funds Used During Construction
AOCI
Accumulated Other Comprehensive Income
ARO
Asset Retirement Obligation
Bcf
Billion cubic feet
C&LM
Conservation and Load Management
CfD
Contract for Differences
CTA
Competitive Transition Assessment
CWIP
Construction Work in Progress
EDC
Electric distribution company
EDIT
Excess Deferred Income Taxes
EPS
Earnings Per Share
ERISA
Employee Retirement Income Security Act of 1974

i


ESOP
Employee Stock Ownership Plan
Eversource 2018 Form 10-K
The Eversource Energy and Subsidiaries 2018 combined Annual Report on Form 10-K as filed with the SEC
Fitch
Fitch Ratings
FMCC
Federally Mandated Congestion Charge
FTR
Financial Transmission Rights
GAAP
Accounting principles generally accepted in the United States of America
GSC
Generation Service Charge
GSRP
Greater Springfield Reliability Project
GWh
Gigawatt-Hours
HQ
Hydro-Québec, a corporation wholly-owned by the Québec government, including its divisions that produce, transmit and distribute electricity in Québec, Canada
HVDC
High-voltage direct current
Hydro Renewable Energy
Hydro Renewable Energy, Inc., a wholly-owned subsidiary of Hydro-Québec
IPP
Independent Power Producers
ISO-NE Tariff
ISO-NE FERC Transmission, Markets and Services Tariff
kV
Kilovolt
kVa
Kilovolt-ampere
kW
Kilowatt (equal to one thousand watts)
kWh
Kilowatt-Hours (the basic unit of electricity energy equal to one kilowatt of power supplied for one hour)
LBR
Lost Base Revenue
LNG
Liquefied natural gas
LRS
Supplier of last resort service
MG
Million gallons
MGP
Manufactured Gas Plant
MMBtu
One million British thermal units
MMcf
Million cubic feet
Moody's
Moody's Investors Services, Inc.
MW
Megawatt
MWh
Megawatt-Hours
NEEWS
New England East-West Solution
NETOs
New England Transmission Owners (including Eversource, National Grid and Avangrid)
OCI
Other Comprehensive Income/(Loss)
PAM
Pension and PBOP Rate Adjustment Mechanism
PBOP
Postretirement Benefits Other Than Pension
PBOP Plan
Postretirement Benefits Other Than Pension Plan
PCRBs
Pollution Control Revenue Bonds
Pension Plan
Single uniform noncontributory defined benefit retirement plan
PPA
Pension Protection Act
RECs
Renewable Energy Certificates
Regulatory ROE
The average cost of capital method for calculating the return on equity related to the distribution business segment excluding the wholesale transmission segment
RNS
Regional Network Service
ROE
Return on Equity
RRBs
Rate Reduction Bonds or Rate Reduction Certificates
RSUs
Restricted share units
S&P
Standard & Poor's Financial Services LLC
SBC
Systems Benefits Charge
SCRC
Stranded Cost Recovery Charge
SERP
Supplemental Executive Retirement Plans and non-qualified defined benefit retirement plans
SS
Standard service
TCAM
Transmission Cost Adjustment Mechanism
TSA
Transmission Service Agreement
UI
The United Illuminating Company
VIE
Variable Interest Entity


ii


EVERSOURCE ENERGY AND SUBSIDIARIES   
THE CONNECTICUT LIGHT AND POWER COMPANY
NSTAR ELECTRIC COMPANY AND SUBSIDIARY
PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES

TABLE OF CONTENTS
 
Page
PART I – FINANCIAL INFORMATION
 
 
 
ITEM 1.
Financial Statements (Unaudited)
 
 
 
 
 
Eversource Energy and Subsidiaries (Unaudited)
 
 
Condensed Consolidated Balance Sheets
1
 
Condensed Consolidated Statements of Income
2
 
Condensed Consolidated Statements of Comprehensive Income
2
 
Condensed Consolidated Statements of Common Shareholders' Equity
3
 
Condensed Consolidated Statements of Cash Flows
4
 
 
 
 
The Connecticut Light and Power Company (Unaudited)
 
 
Condensed Balance Sheets
5
 
Condensed Statements of Income
6
 
Condensed Statements of Comprehensive Income
6
 
Condensed Statements of Common Stockholder's Equity
7
 
Condensed Statements of Cash Flows
8
 
 
 
 
NSTAR Electric Company and Subsidiary (Unaudited)
 
 
Condensed Consolidated Balance Sheets
9
 
Condensed Consolidated Statements of Income
10
 
Condensed Consolidated Statements of Comprehensive Income
10
 
Condensed Consolidated Statements of Common Stockholder's Equity
11
 
Condensed Consolidated Statements of Cash Flows
12
 
 
 
 
Public Service Company of New Hampshire and Subsidiaries (Unaudited)
 
 
Condensed Consolidated Balance Sheets
13
 
Condensed Consolidated Statements of Income
14
 
Condensed Consolidated Statements of Comprehensive Income
14
 
Condensed Consolidated Statements of Common Stockholder's Equity
15
 
Condensed Consolidated Statements of Cash Flows
16
 
 
 
 
Combined Notes to Condensed Financial Statements (Unaudited)
17
 
 
 
ITEM 2.
Management's Discussion and Analysis of Financial Condition and Results of Operations
 
 
Eversource Energy and Subsidiaries
42
 
The Connecticut Light and Power Company, NSTAR Electric Company and Subsidiary, and
Public Service Company of New Hampshire and Subsidiaries
58
 
 
 
ITEM 3.
Quantitative and Qualitative Disclosures About Market Risk
65
 
 
 
ITEM 4.
Controls and Procedures
65
 
 
 
PART II – OTHER INFORMATION
 
 
 
ITEM 1.
Legal Proceedings
66
 
 
 
ITEM 1A.
Risk Factors
66
 
 
 
ITEM 2.
Unregistered Sales of Equity Securities and Use of Proceeds
66
 
 
 
ITEM 6.
Exhibits
67
 
 
 
SIGNATURES
69

iii



EVERSOURCE ENERGY AND SUBSIDIARIES
CONDENSED CONSOLIDATED BALANCE SHEETS
(Unaudited)
(Thousands of Dollars)
As of June 30, 2019

As of December 31, 2018





ASSETS
 


 
Current Assets:
 


 
Cash
$
20,578


$
108,068

Receivables, Net
964,314


994,055

Unbilled Revenues
154,920


176,285

Fuel, Materials, Supplies and Inventory
174,124

 
238,042

Regulatory Assets
515,265


514,779

Prepayments and Other Current Assets
302,496


260,995

Total Current Assets
2,131,697


2,292,224







Property, Plant and Equipment, Net
26,304,446


25,610,428







Deferred Debits and Other Assets:
 


 

Regulatory Assets
4,404,176


4,631,137

Goodwill
4,427,266


4,427,266

Investments in Unconsolidated Affiliates
748,705

 
464,286

Marketable Securities
401,231


417,508

Other Long-Term Assets
578,385


398,407

Total Deferred Debits and Other Assets
10,559,763


10,338,604







Total Assets
$
38,995,906


$
38,241,256





LIABILITIES AND CAPITALIZATION
 

 
Current Liabilities:
 

 
Notes Payable
$
729,000


$
910,000

Long-Term Debt – Current Portion
779,289


837,319

Rate Reduction Bonds – Current Portion
43,210

 
52,332

Accounts Payable
903,431


1,119,995

Regulatory Liabilities
379,850


370,230

Other Current Liabilities
677,341


823,006

Total Current Liabilities
3,512,121


4,112,882





Deferred Credits and Other Liabilities:
 

 
Accumulated Deferred Income Taxes
3,549,922


3,506,030

Regulatory Liabilities
3,639,792


3,609,475

Derivative Liabilities
363,848


379,562

Accrued Pension, SERP and PBOP
955,092


962,510

Other Long-Term Liabilities
1,264,061


1,196,336

Total Deferred Credits and Other Liabilities
9,772,715


9,653,913







Long-Term Debt
13,039,180


12,248,743

 
 
 
 
Rate Reduction Bonds
561,727

 
583,331

 
 
 
 
Noncontrolling Interest – Preferred Stock of Subsidiaries
155,570


155,570







Common Shareholders' Equity:


 
Common Shares
1,699,292


1,669,392

Capital Surplus, Paid In
6,659,009


6,241,222

Retained Earnings
3,954,492


3,953,974

Accumulated Other Comprehensive Loss
(53,641
)

(60,000
)
Treasury Stock
(304,559
)

(317,771
)
Common Shareholders' Equity
11,954,593


11,486,817

 
 
 
 
Commitments and Contingencies (Note 9)


 








Total Liabilities and Capitalization
$
38,995,906


$
38,241,256


The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.

1


EVERSOURCE ENERGY AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF INCOME
(Unaudited)
 
For the Three Months Ended June 30,
 
For the Six Months Ended June 30,
(Thousands of Dollars, Except Share Information)
2019
 
2018
 
2019
 
2018
 
 
 
 
 
 
 
 
Operating Revenues
$
1,884,495

 
$
1,853,856

 
$
4,300,287

 
$
4,141,818

 
 
 
 
 
 
 
 
Operating Expenses:
 
 
 
 
 
 
 
Purchased Power, Fuel and Transmission
620,904

 
653,915

 
1,595,786

 
1,600,662

Operations and Maintenance
328,010

 
293,858

 
663,606

 
626,406

Depreciation
219,084

 
199,140

 
434,032

 
403,406

Amortization
38,945

 
36,203

 
109,906

 
81,397

Energy Efficiency Programs
105,837

 
101,955

 
245,953

 
236,196

Taxes Other Than Income Taxes
181,083

 
177,431

 
365,672

 
359,865

Impairment of Northern Pass Transmission
239,644

 
—

 
239,644

 
—

Total Operating Expenses
1,733,507

 
1,462,502

 
3,654,599

 
3,307,932

Operating Income
150,988

 
391,354

 
645,688

 
833,886

Interest Expense
132,705

 
126,404

 
264,438

 
247,533

Other Income, Net
45,866

 
50,149

 
76,850

 
83,938

Income Before Income Tax Expense
64,149

 
315,099

 
458,100

 
670,291

Income Tax Expense
30,815

 
70,452

 
114,209

 
154,219

Net Income
33,334

 
244,647

 
343,891

 
516,072

Net Income Attributable to Noncontrolling Interests
1,880

 
1,880

 
3,759

 
3,759

Net Income Attributable to Common Shareholders
$
31,454

 
$
242,767

 
$
340,132

 
$
512,313

 
 
 
 
 
 
 
 
Basic and Diluted Earnings Per Common Share
$
0.10

 
$
0.76

 
$
1.07

 
$
1.61

 
 
 
 
 
 
 
 
Weighted Average Common Shares Outstanding:
 
 
 
 
 
 
 
Basic
319,664,998

 
317,344,596

 
318,644,796

 
317,370,825

Diluted
320,388,490

 
317,885,187

 
319,352,287

 
317,939,094


The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.


CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
(Unaudited)
 
For the Three Months Ended June 30,
 
For the Six Months Ended June 30,
(Thousands of Dollars)
2019
 
2018
 
2019
 
2018
 
 
 
 
 
 
 
 
Net Income
$
33,334

 
$
244,647

 
$
343,891

 
$
516,072

Other Comprehensive Income, Net of Tax:
 
 
 
 
 
 
 
Qualified Cash Flow Hedging Instruments
262

 
471

 
578

 
1,195

Changes in Unrealized Gains/(Losses)
   on Marketable Securities
444

 
(144
)
 
1,099

 
(588
)
Changes in Funded Status of Pension, SERP and
  PBOP Benefit Plans
3,457

 
1,815

 
4,682

 
4,808

Other Comprehensive Income, Net of Tax
4,163

 
2,142

 
6,359

 
5,415

Comprehensive Income Attributable to
  Noncontrolling Interests
(1,880
)
 
(1,880
)
 
(3,759
)
 
(3,759
)
Comprehensive Income Attributable to Common
  Shareholders
$
35,617

 
$
244,909

 
$
346,491

 
$
517,728


The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.

2


EVERSOURCE ENERGY AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF COMMON SHAREHOLDERS' EQUITY
(Unaudited)
 
For the Six Months Ended June 30, 2019
 
Common Shares
 
Capital
Surplus,
Paid In
 
Retained Earnings
 
Accumulated Other Comprehensive Loss
 
Treasury Stock
 
Total Common Shareholders' Equity
(Thousands of Dollars, Except Share Information)
Shares
 
Amount
Balance as of January 1, 2019
316,885,808

 
$
1,669,392

 
$
6,241,222

 
$
3,953,974

 
$
(60,000
)
 
$
(317,771
)
 
$
11,486,817

Net Income
 

 
 

 
 
 
310,558

 
 
 
 
 
310,558

Dividends on Common Shares - $0.535 Per Share
 

 
 

 
 
 
(169,757
)
 
 
 
 
 
(169,757
)
Dividends on Preferred Stock
 

 
 

 
 
 
(1,880
)
 
 
 
 
 
(1,880
)
Long-Term Incentive Plan Activity
 

 
 

 
(16,609
)
 
 

 
 
 
 
 
(16,609
)
Issuance of Treasury Shares
461,662

 
 

 
17,476

 
 

 
 
 
8,633

 
26,109

Other Comprehensive Income
 

 
 

 
 
 
 

 
2,196

 
 
 
2,196

Balance as of March 31, 2019
317,347,470


1,669,392


6,242,089


4,092,895


(57,804
)

(309,138
)

11,637,434

Net Income
 

 
 

 
 
 
33,334

 
 
 
 
 
33,334

Dividends on Common Shares - $0.535 Per Share
 

 
 

 
 
 
(169,857
)
 
 
 
 
 
(169,857
)
Dividends on Preferred Stock
 

 
 

 
 
 
(1,880
)
 
 
 
 
 
(1,880
)
Issuance of Common Shares - $5 par value
5,980,000

 
29,900

 
403,650

 
 
 
 
 
 
 
433,550

Long-Term Incentive Plan Activity
 

 
 

 
6,470

 
 
 
 
 
 
 
6,470

Issuance of Treasury Shares
246,969

 
 

 
13,448

 
 
 
 
 
4,579

 
18,027

Capital Stock Expense
 
 
 
 
(6,648
)
 
 
 
 
 
 
 
(6,648
)
Other Comprehensive Income
 

 
 

 
 
 
 
 
4,163

 
 
 
4,163

Balance as of June 30, 2019
323,574,439

 
$
1,699,292


$
6,659,009


$
3,954,492


$
(53,641
)

$
(304,559
)

$
11,954,593

 
For the Six Months Ended June 30, 2018
 
Common Shares
 
Capital
Surplus,
Paid In
 
Retained Earnings
 
Accumulated Other Comprehensive Loss
 
Treasury Stock
 
Total Common Shareholders' Equity
(Thousands of Dollars, Except Share Information)
Shares
 
Amount
Balance as of January 1, 2018
316,885,808

 
$
1,669,392

 
$
6,239,940

 
$
3,561,084

 
$
(66,403
)
 
$
(317,771
)
 
$
11,086,242

Net Income
 
 
 

 
 
 
271,426

 
 
 
 
 
271,426

Dividends on Common Shares - $0.505 Per Share
 
 
 

 
 
 
(160,027
)
 
 
 
 
 
(160,027
)
Dividends on Preferred Stock
 
 
 

 
 
 
(1,880
)
 
 
 
 
 
(1,880
)
Long-Term Incentive Plan Activity
 
 
 

 
(15,320
)
 
 

 
 
 
 
 
(15,320
)
Other Comprehensive Income
 
 
 

 
 
 
 

 
3,273

 
 
 
3,273

Balance as of March 31, 2018
316,885,808

 
1,669,392

 
6,224,620

 
3,670,603

 
(63,130
)
 
(317,771
)
 
11,183,714

Net Income
 

 
 

 
 
 
244,647

 
 
 
 
 
244,647

Dividends on Common Shares - $0.505 Per Share
 

 
 

 
 
 
(160,027
)
 
 
 
 
 
(160,027
)
Dividends on Preferred Stock
 

 
 

 
 
 
(1,880
)
 
 
 
 
 
(1,880
)
Long-Term Incentive Plan Activity
 

 
 

 
4,627

 
 
 
 
 
 
 
4,627

Other Comprehensive Income
 

 
 

 
 
 
 
 
2,142

 
 
 
2,142

Balance as of June 30, 2018
316,885,808

 
$
1,669,392

 
$
6,229,247

 
$
3,753,343

 
$
(60,988
)
 
$
(317,771
)
 
$
11,273,223


The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.



3


EVERSOURCE ENERGY AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)
 
For the Six Months Ended June 30,
(Thousands of Dollars)
2019
 
2018




Operating Activities:
 

 
Net Income
$
343,891


$
516,072

Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
 

 
Depreciation
434,032


403,406

Deferred Income Taxes
36,535


161,883

Uncollectible Expense
31,546

 
29,250

Pension, SERP and PBOP Expense, Net
13,227


3,317

Pension and PBOP Contributions
(6,648
)

(179,002
)
Regulatory Overrecoveries, Net
23,830


36,669

Amortization
109,906


81,397

Proceeds from DOE Spent Nuclear Fuel Litigation
68,840

 
—

Impairment of Northern Pass Transmission
239,644

 
—

Other
(137,428
)

(103,256
)
Changes in Current Assets and Liabilities:
 

 
Receivables and Unbilled Revenues, Net
6,357


(52,923
)
Fuel, Materials, Supplies and Inventory
63,918


65,609

Taxes Receivable/Accrued, Net
(6,883
)

(132,999
)
Accounts Payable
(156,077
)

(80,059
)
Other Current Assets and Liabilities, Net
(140,103
)

(51,229
)
Net Cash Flows Provided by Operating Activities
924,587


698,135





Investing Activities:
 

 
Investments in Property, Plant and Equipment
(1,377,753
)

(1,251,678
)
Proceeds from Sales of Marketable Securities
348,904


316,252

Purchases of Marketable Securities
(302,950
)

(314,406
)
Proceeds from the Sale of PSNH Generation Assets
—

 
116,809

Investments in Unconsolidated Affiliates
(265,955
)
 
(13,220
)
Other Investing Activities
4,055


(902
)
Net Cash Flows Used in Investing Activities
(1,593,699
)

(1,147,145
)




Financing Activities:
 

 
Issuance of Common Shares, Net of Issuance Costs
426,902

 
—

Cash Dividends on Common Shares
(323,346
)

(320,055
)
Cash Dividends on Preferred Stock
(3,759
)

(3,759
)
Decrease in Notes Payable
(181,000
)

(98,500
)
Issuance of Rate Reduction Bonds
—

 
635,663

Repayment of Rate Reduction Bonds
(30,727
)
 
—

Issuance of Long-Term Debt
1,000,000


1,150,000

Retirement of Long-Term Debt
(250,437
)

(860,421
)
Other Financing Activities
(10,682
)

(17,958
)
Net Cash Flows Provided by Financing Activities
626,951


484,970

Net (Decrease)/Increase in Cash and Restricted Cash
(42,161
)

35,960

Cash and Restricted Cash - Beginning of Period
209,324


85,890

Cash and Restricted Cash - End of Period
$
167,163


$
121,850


The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.



4



THE CONNECTICUT LIGHT AND POWER COMPANY
CONDENSED BALANCE SHEETS
(Unaudited)
(Thousands of Dollars)
As of June 30, 2019
 
As of December 31, 2018
 
 
 
 
ASSETS
 
 
 
Current Assets:
 
 
 
Cash
$
2,191

 
$
87,721

Receivables, Net
415,542

 
397,026

Accounts Receivable from Affiliated Companies
33,519

 
23,082

Unbilled Revenues
53,670

 
56,971

Materials and Supplies
55,243

 
44,529

Regulatory Assets
175,706

 
125,155

Prepayments and Other Current Assets
23,390

 
60,279

Total Current Assets
759,261

 
794,763

 
 
 
 
Property, Plant and Equipment, Net
9,285,633

 
8,909,701

 
 
 
 
Deferred Debits and Other Assets:
 
 
 
Regulatory Assets
1,432,827

 
1,505,488

Other Long-Term Assets
221,860

 
199,767

Total Deferred Debits and Other Assets
1,654,687

 
1,705,255

 
 
 
 
Total Assets
$
11,699,581

 
$
11,409,719

 
 
 
 
LIABILITIES AND CAPITALIZATION
 
 
 
Current Liabilities:
 
 
 
Notes Payable to Eversource Parent
$
259,400

 
$
—

Long-Term Debt – Current Portion
—

 
250,000

Accounts Payable
287,984

 
324,983

Accounts Payable to Affiliated Companies
76,792

 
26,452

Obligations to Third Party Suppliers
52,100

 
56,248

Regulatory Liabilities
112,414

 
109,614

Derivative Liabilities
62,075

 
55,058

Other Current Liabilities
147,764

 
161,088

Total Current Liabilities
998,529

 
983,443

 
 
 
 
Deferred Credits and Other Liabilities:
 
 
 
Accumulated Deferred Income Taxes
1,192,646

 
1,166,784

Regulatory Liabilities
1,153,360

 
1,122,157

Derivative Liabilities
363,717

 
379,536

Accrued Pension, SERP and PBOP
275,358

 
282,771

Other Long-Term Liabilities
153,878

 
155,495

Total Deferred Credits and Other Liabilities
3,138,959

 
3,106,743

 
 
 
 
Long-Term Debt
3,309,455

 
3,004,016

 
 
 
 
Preferred Stock Not Subject to Mandatory Redemption
116,200

 
116,200

 
 
 
 
Common Stockholder's Equity:
 
 
 
Common Stock
60,352

 
60,352

Capital Surplus, Paid In
2,410,765

 
2,410,765

Retained Earnings
1,664,995

 
1,727,899

Accumulated Other Comprehensive Income
326

 
301

Common Stockholder's Equity
4,136,438

 
4,199,317

 
 
 
 
Commitments and Contingencies (Note 9)


 


 
 
 
 
Total Liabilities and Capitalization
$
11,699,581

 
$
11,409,719


The accompanying notes are an integral part of these unaudited condensed financial statements.

5


THE CONNECTICUT LIGHT AND POWER COMPANY
CONDENSED STATEMENTS OF INCOME
(Unaudited)
 
For the Three Months Ended June 30,
 
For the Six Months Ended June 30,
(Thousands of Dollars)
2019
 
2018
 
2019
 
2018
 
 
 
 
 
 
 
 
Operating Revenues
$
740,846

 
$
694,892

 
$
1,590,092

 
$
1,479,875

 
 
 
 
 
 
 
 
Operating Expenses:
 
 
 
 
 
 
 
Purchased Power and Transmission
246,540

 
234,335

 
566,373

 
536,223

Operations and Maintenance
133,351

 
109,685

 
263,989

 
226,977

Depreciation
74,555

 
69,383

 
147,844

 
136,881

Amortization of Regulatory Assets, Net
12,376

 
15,400

 
48,047

 
43,405

Energy Efficiency Programs
20,780

 
18,606

 
46,768

 
41,366

Taxes Other Than Income Taxes
86,465

 
84,375

 
178,463

 
174,676

Total Operating Expenses
574,067

 
531,784

 
1,251,484

 
1,159,528

Operating Income
166,779

 
163,108

 
338,608

 
320,347

Interest Expense
36,972

 
38,674

 
72,754

 
75,498

Other Income, Net
2,853

 
7,063

 
6,733

 
13,623

Income Before Income Tax Expense
132,660

 
131,497

 
272,587

 
258,472

Income Tax Expense
27,856

 
31,785

 
57,312

 
60,192

Net Income
$
104,804

 
$
99,712

 
$
215,275

 
$
198,280


The accompanying notes are an integral part of these unaudited condensed financial statements.


CONDENSED STATEMENTS OF COMPREHENSIVE INCOME
(Unaudited)
 
For the Three Months Ended June 30,
 
For the Six Months Ended June 30,
(Thousands of Dollars)
2019
 
2018
 
2019
 
2018
 
 
 
 
 
 
 
 
Net Income
$
104,804

 
$
99,712

 
$
215,275

 
$
198,280

Other Comprehensive Income, Net of Tax:
 
 
 
 
 
 
 
Qualified Cash Flow Hedging Instruments
(7
)
 
13

 
(13
)
 
65

Changes in Unrealized Gains/(Losses) on
  Marketable Securities
15

 
(4
)
 
38

 
(16
)
Other Comprehensive Income, Net of Tax
8

 
9

 
25

 
49

Comprehensive Income
$
104,812

 
$
99,721

 
$
215,300

 
$
198,329


The accompanying notes are an integral part of these unaudited condensed financial statements.


6


THE CONNECTICUT LIGHT AND POWER COMPANY
CONDENSED STATEMENTS OF COMMON STOCKHOLDER'S EQUITY
(Unaudited)
 
For the Six Months Ended June 30, 2019
 
Common Stock
 
Capital
Surplus,
Paid In
 
Retained
Earnings
 
Accumulated
Other
Comprehensive
Income
 
Total
Common
Stockholder's
Equity
(Thousands of Dollars, Except Stock Information)
Stock
 
Amount
 
 
 
 
Balance as of January 1, 2019
6,035,205

 
$
60,352

 
$
2,410,765

 
$
1,727,899

 
$
301

 
$
4,199,317

Net Income
 

 
 

 
 
 
110,471

 
 
 
110,471

Dividends on Preferred Stock
 

 
 

 
 
 
(1,390
)
 
 
 
(1,390
)
Dividends on Common Stock
 

 
 

 
 
 
(99,000
)
 
 
 
(99,000
)
Other Comprehensive Income
 

 
 

 
 
 
 

 
17

 
17

Balance as of March 31, 2019
6,035,205

 
60,352

 
2,410,765

 
1,737,980

 
318

 
4,209,415

Net Income
 

 
 

 
 
 
104,804

 
 
 
104,804

Dividends on Preferred Stock
 

 
 

 
 
 
(1,390
)
 
 
 
(1,390
)
Dividends on Common Stock
 

 
 

 
 
 
(176,400
)
 
 
 
(176,400
)
Other
 
 
 
 
 
 
1

 
 
 
1

Other Comprehensive Income
 

 
 

 
 
 
 
 
8

 
8

Balance as of June 30, 2019
6,035,205

 
$
60,352

 
$
2,410,765

 
$
1,664,995

 
$
326

 
$
4,136,438

 
For the Six Months Ended June 30, 2018
 
Common Stock
 
Capital
Surplus,
Paid In
 
Retained
Earnings
 
Accumulated
Other
Comprehensive
Income
 
Total
Common
Stockholder's
Equity
(Thousands of Dollars, Except Stock Information)
Stock
 
Amount
 
 
 
 
Balance as of January 1, 2018
6,035,205

 
$
60,352

 
$
2,110,765

 
$
1,415,741

 
$
269

 
$
3,587,127

Net Income
 

 
 

 
 
 
98,568

 
 
 
98,568

Dividends on Preferred Stock
 

 
 

 
 
 
(1,390
)
 
 
 
(1,390
)
Dividends on Common Stock
 

 
 

 
 
 
(60,000
)
 
 
 
(60,000
)
Capital Contributions from Eversource Parent
 

 
 

 
9,000

 
 

 
 
 
9,000

Other Comprehensive Income
 

 
 

 
 
 
 

 
40

 
40

Balance as of March 31, 2018
6,035,205

 
60,352

 
2,119,765

 
1,452,919

 
309

 
3,633,345

Net Income
 

 
 

 
 
 
99,712

 
 
 
99,712

Dividends on Preferred Stock
 

 
 

 
 
 
(1,390
)
 
 
 
(1,390
)
Capital Contributions from Eversource Parent
 

 
 

 
91,000

 
 
 
 
 
91,000

Other Comprehensive Income
 

 
 

 
 
 
 
 
9

 
9

Balance as of June 30, 2018
6,035,205

 
$
60,352


$
2,210,765


$
1,551,241


$
318


$
3,822,676


The accompanying notes are an integral part of these unaudited condensed financial statements.


7


THE CONNECTICUT LIGHT AND POWER COMPANY
CONDENSED STATEMENTS OF CASH FLOWS
(Unaudited)
 
For the Six Months Ended June 30,
(Thousands of Dollars)
2019
 
2018
 
 
 
 
Operating Activities:
 
 
 
Net Income
$
215,275

 
$
198,280

Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
 
 
 
Depreciation
147,844

 
136,881

Deferred Income Taxes
16,513

 
50,915

Uncollectible Expense
7,627

 
7,747

Pension, SERP, and PBOP Expense, Net
6,926

 
3,861

Pension Contributions
—

 
(41,150
)
Regulatory Underrecoveries, Net
(40,460
)
 
(39,908
)
Amortization of Regulatory Assets, Net
48,047

 
43,405

Other
(40,290
)
 
(40,825
)
Changes in Current Assets and Liabilities:
 
 
 
Receivables and Unbilled Revenues, Net
(37,101
)
 
(34,772
)
Taxes Receivable/Accrued, Net
19,701

 
105

Accounts Payable
5,443

 
(30,805
)
Other Current Assets and Liabilities, Net
(3,941
)
 
14,377

Net Cash Flows Provided by Operating Activities
345,584

 
268,111

 
 
 
 
Investing Activities:
 
 
 
Investments in Property, Plant and Equipment
(466,112
)
 
(457,677
)
Other Investing Activities
551

 
110

Net Cash Flows Used in Investing Activities
(465,561
)
 
(457,567
)
 
 
 
 
Financing Activities:
 
 
 
Cash Dividends on Common Stock
(275,400
)
 
(60,000
)
Cash Dividends on Preferred Stock
(2,779
)
 
(2,779
)
Capital Contributions from Eversource Parent
—

 
100,000

Issuance of Long-Term Debt
300,000

 
500,000

Retirement of Long-Term Debt
(250,000
)
 
(300,000
)
Increase/(Decrease) in Notes Payable to Eversource Parent
259,400

 
(45,500
)
Other Financing Activities
4,237

 
(6,189
)
Net Cash Flows Provided by Financing Activities
35,458

 
185,532

Net Decrease in Cash and Restricted Cash
(84,519
)
 
(3,924
)
Cash and Restricted Cash - Beginning of Period
91,613

 
9,619

Cash and Restricted Cash - End of Period
$
7,094

 
$
5,695


The accompanying notes are an integral part of these unaudited condensed financial statements.




8



NSTAR ELECTRIC COMPANY AND SUBSIDIARY
CONDENSED CONSOLIDATED BALANCE SHEETS
(Unaudited)
(Thousands of Dollars)
As of June 30, 2019
 
As of December 31, 2018
 
 
 
 
ASSETS
 

 
 

Current Assets:
 
 
 
Cash
$
177

 
$
1,606

Receivables, Net
346,428

 
361,296

Accounts Receivable from Affiliated Companies
25,071

 
31,344

Unbilled Revenues
42,144

 
34,518

Materials, Supplies and Inventory
64,513

 
114,202

Regulatory Assets
210,032

 
241,747

Prepayments and Other Current Assets
21,289

 
51,960

Total Current Assets
709,654

 
836,673

 
 
 
 
Property, Plant and Equipment, Net
9,075,789

 
8,794,700

 
 
 
 
Deferred Debits and Other Assets:
 
 
 
Regulatory Assets
1,178,974

 
1,196,512

Prepaid PBOP
146,717

 
132,810

Other Long-Term Assets
142,573

 
109,764

Total Deferred Debits and Other Assets
1,468,264

 
1,439,086

 
 
 
 
Total Assets
$
11,253,707

 
$
11,070,459

 
 
 
 
LIABILITIES AND CAPITALIZATION
 
 
 
Current Liabilities:
 
 
 
Notes Payable
$
163,000

 
$
278,500

Notes Payable to Eversource Parent
40,300

 
—

Long-Term Debt – Current Portion
95,000

 
—

Accounts Payable
288,153

 
384,398

Accounts Payable to Affiliated Companies
72,174

 
89,636

Obligations to Third Party Suppliers
95,360

 
109,547

Renewable Portfolio Standards Compliance Obligations
66,370

 
139,898

Regulatory Liabilities
170,970

 
190,620

Other Current Liabilities
61,710

 
74,872

Total Current Liabilities
1,053,037

 
1,267,471

 
 
 
 
Deferred Credits and Other Liabilities:
 
 
 
Accumulated Deferred Income Taxes
1,318,267

 
1,294,467

Regulatory Liabilities
1,514,845

 
1,513,279

Accrued Pension and SERP
29,323

 
14,145

Other Long-Term Liabilities
297,346

 
263,096

Total Deferred Credits and Other Liabilities
3,159,781

 
3,084,987

 
 
 
 
Long-Term Debt
3,246,535

 
2,944,846

 
 
 
 
Preferred Stock Not Subject to Mandatory Redemption
43,000

 
43,000

 
 
 
 
Common Stockholder's Equity:
 
 
 
Common Stock
—

 
—

Capital Surplus, Paid In
1,653,442

 
1,633,442

Retained Earnings
2,099,059

 
2,098,091

Accumulated Other Comprehensive Loss
(1,147
)
 
(1,378
)
Common Stockholder's Equity
3,751,354

 
3,730,155

 
 
 
 
Commitments and Contingencies (Note 9)


 


 
 
 
 
Total Liabilities and Capitalization
$
11,253,707


$
11,070,459


The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.

9


NSTAR ELECTRIC COMPANY AND SUBSIDIARY
CONDENSED CONSOLIDATED STATEMENTS OF INCOME
(Unaudited)
 
For the Three Months Ended June 30,
 
For the Six Months Ended June 30,
(Thousands of Dollars)
2019
 
2018
 
2019
 
2018
 
 
 
 
 
 
 
 
Operating Revenues
$
681,893

 
$
690,737

 
$
1,479,505

 
$
1,460,865

 
 
 
 
 
 
 
 
Operating Expenses:
 

 
 

 
 

 
 

Purchased Power and Transmission
228,397

 
266,108

 
558,501

 
598,687

Operations and Maintenance
108,924

 
102,163

 
221,887

 
220,844

Depreciation
73,055

 
64,051

 
145,639

 
134,593

Amortization of Regulatory Assets, Net
23,184

 
11,954

 
45,768

 
18,318

Energy Efficiency Programs
65,904

 
65,184

 
142,633

 
139,978

Taxes Other Than Income Taxes
48,226

 
47,627

 
93,047

 
95,815

Total Operating Expenses
547,690

 
557,087

 
1,207,475

 
1,208,235

Operating Income
134,203

 
133,650

 
272,030

 
252,630

Interest Expense
28,238

 
27,359

 
56,120

 
53,822

Other Income, Net
10,657

 
14,269

 
21,743

 
26,870

Income Before Income Tax Expense
116,622

 
120,560

 
237,653

 
225,678

Income Tax Expense
26,888

 
32,639

 
53,906

 
60,607

Net Income
$
89,734

 
$
87,921

 
$
183,747

 
$
165,071


The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.


CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
(Unaudited)
 
For the Three Months Ended June 30,
 
For the Six Months Ended June 30,
(Thousands of Dollars)
2019
 
2018
 
2019
 
2018
 
 
 
 
 
 
 
 
Net Income
$
89,734

 
$
87,921

 
$
183,747

 
$
165,071

Other Comprehensive Income, Net of Tax:
 
 
 
 
 
 
 
  Changes in Funded Status of SERP Benefit Plan
1

 
1

 
2

 
2

  Qualified Cash Flow Hedging Instruments
109

 
109

 
219

 
218

  Changes in Unrealized Gains/(Losses) on
    Marketable Securities
4

 
(1
)
 
10

 
(5
)
Other Comprehensive Income, Net of Tax
114

 
109

 
231

 
215

Comprehensive Income
$
89,848

 
$
88,030

 
$
183,978

 
$
165,286


The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.


10


NSTAR ELECTRIC COMPANY AND SUBSIDIARY
CONDENSED CONSOLIDATED STATEMENTS OF COMMON STOCKHOLDER'S EQUITY
(Unaudited)
 
For the Six Months Ended June 30, 2019
 
Common Stock
 
Capital
Surplus,
Paid In
 
Retained
Earnings
 
Accumulated
Other
Comprehensive
Loss
 
Total
Common
Stockholder's
Equity
(Thousands of Dollars, Except Stock Information)
Stock
 
Amount
 
 
 
 
Balance as of January 1, 2019
200

 
$
—

 
$
1,633,442

 
$
2,098,091

 
$
(1,378
)
 
$
3,730,155

Net Income
 

 
 

 
 
 
94,014

 
 
 
94,014

Dividends on Preferred Stock
 

 
 

 
 
 
(490
)
 
 
 
(490
)
Dividends on Common Stock
 

 
 

 
 
 
(60,600
)
 
 
 
(60,600
)
Capital Contributions from Eversource Parent
 

 
 

 
20,000

 
 
 
 
 
20,000

Other Comprehensive Income
 

 
 

 
 
 
 
 
117

 
117

Balance as of March 31, 2019
200


—


1,653,442


2,131,015


(1,261
)

3,783,196

Net Income
 

 
 

 
 

 
89,734

 
 

 
89,734

Dividends on Preferred Stock
 

 
 

 
 

 
(490
)
 
 

 
(490
)
Dividends on Common Stock
 

 
 

 
 

 
(121,200
)
 
 

 
(121,200
)
Other Comprehensive Income
 

 
 

 
 

 
 

 
114

 
114

Balance as of June 30, 2019
200

 
$
—

 
$
1,653,442

 
$
2,099,059

 
$
(1,147
)
 
$
3,751,354

 
For the Six Months Ended June 30, 2018
 
Common Stock
 
Capital
Surplus,
Paid In
 
Retained
Earnings
 
Accumulated
Other
Comprehensive
Loss
 
Total
Common
Stockholder's
Equity
(Thousands of Dollars, Except Stock Information)
Stock
 
Amount
 
 
 
 
Balance as of January 1, 2018
200

 
$
—

 
$
1,502,942

 
$
1,944,961

 
$
(1,823
)
 
$
3,446,080

Net Income
 

 
 

 
 
 
77,149

 
 
 
77,149

Dividends on Preferred Stock
 

 
 

 
 
 
(490
)
 
 
 
(490
)
Dividends on Common Stock
 

 
 

 
 
 
(161,000
)
 
 
 
(161,000
)
Capital Contributions from Eversource Parent
 

 
 

 
92,500

 

 
 
 
92,500

Other
 

 
 

 


 
1

 
 
 
1

Other Comprehensive Income
 

 
 

 
 
 
 
 
106

 
106

Balance as of March 31, 2018
200

 
—

 
1,595,442

 
1,860,621

 
(1,717
)
 
3,454,346

Net Income
 

 
 

 
 
 
87,921

 
 

 
87,921

Dividends on Preferred Stock
 

 
 

 
 
 
(490
)
 
 

 
(490
)
Capital Contributions from Eversource Parent
 

 
 

 
8,000

 
 
 
 

 
8,000

Other Comprehensive Income
 

 
 

 
 
 
 
 
109

 
109

Balance as of June 30, 2018
200

 
$
—


$
1,603,442


$
1,948,052


$
(1,608
)

$
3,549,886


The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.


11


NSTAR ELECTRIC COMPANY AND SUBSIDIARY
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)
 
For the Six Months Ended June 30,
(Thousands of Dollars)
2019
 
2018
 
 
 
 
Operating Activities:
 

 
 

Net Income
$
183,747

 
$
165,071

Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
 

 
 

Depreciation
145,639

 
134,593

Deferred Income Taxes
11,603

 
29,238

Uncollectible Expense
11,605

 
11,301

Pension, SERP and PBOP Income, Net
(7,052
)
 
(19,785
)
Pension and PBOP Contributions
(3,007
)
 
(59,156
)
Regulatory Overrecoveries, Net
17,063

 
34,090

Amortization of Regulatory Assets, Net
45,768

 
18,318

Other
(36,973
)
 
(14,646
)
Changes in Current Assets and Liabilities:
 

 
 

Receivables and Unbilled Revenues, Net
(6,769
)
 
(40,073
)
Materials, Supplies and Inventory
49,688

 
45,058

Taxes Receivable/Accrued, Net
25,572

 
(37,268
)
Accounts Payable
(82,326
)
 
(17,194
)
Other Current Assets and Liabilities, Net
(103,054
)
 
(46,861
)
Net Cash Flows Provided by Operating Activities
251,504

 
202,686

 
 
 
 
Investing Activities:
 

 
 

Investments in Property, Plant and Equipment
(418,571
)
 
(356,497
)
Other Investing Activities
41

 
31

Net Cash Flows Used in Investing Activities
(418,530
)
 
(356,466
)
 
 
 
 
Financing Activities:
 

 
 

Cash Dividends on Common Stock
(181,800
)
 
(161,000
)
Cash Dividends on Preferred Stock
(980
)
 
(980
)
Issuance of Long-Term Debt
400,000

 
—

Capital Contributions from Eversource Parent
20,000

 
100,500

Increase in Notes Payable to Eversource Parent
40,300

 
—

(Decrease)/Increase in Notes Payable
(115,500
)
 
213,810

Other Financing Activities
(3,287
)
 
(158
)
Net Cash Flows Provided by Financing Activities
158,733

 
152,172

Net Decrease in Cash and Restricted Cash
(8,293
)
 
(1,608
)
Cash and Restricted Cash - Beginning of Period
14,659

 
14,708

Cash and Restricted Cash - End of Period
$
6,366

 
$
13,100


The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.


12



PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES
CONDENSED CONSOLIDATED BALANCE SHEETS
(Unaudited)
(Thousands of Dollars)
As of June 30, 2019
 
As of December 31, 2018
 
 
 
 
ASSETS
 
 
 
Current Assets:
 
 
 
Cash
$
343

 
$
1,439

Receivables, Net
99,416

 
104,854

Accounts Receivable from Affiliated Companies
11,476

 
8,444

Unbilled Revenues
39,665

 
47,145

Taxes Receivable
6,985

 
25,913

Materials, Supplies and Inventory
23,280

 
37,504

Regulatory Assets
77,854

 
67,228

Special Deposits
35,017

 
47,498

Prepayments and Other Current Assets
17,293

 
17,564

Total Current Assets
311,329

 
357,589

 
 
 
 
Property, Plant and Equipment, Net
2,969,347

 
2,880,073

 
 
 
 
Deferred Debits and Other Assets:
 
 
 
Regulatory Assets
827,898

 
862,288

Other Long-Term Assets
32,428

 
27,406

Total Deferred Debits and Other Assets
860,326

 
889,694

 
 
 
 
Total Assets
$
4,141,002

 
$
4,127,356

 
 
 
 
LIABILITIES AND CAPITALIZATION
 
 
 
Current Liabilities:
 
 
 
Notes Payable to Eversource Parent
$
20,100

 
$
57,000

Long-Term Debt – Current Portion
150,000

 
150,000

Rate Reduction Bonds – Current Portion
43,210

 
52,332

Accounts Payable
103,749

 
111,292

Accounts Payable to Affiliated Companies
27,195

 
26,029

Regulatory Liabilities
54,183

 
55,526

Other Current Liabilities
45,414

 
64,046

Total Current Liabilities
443,851

 
516,225

 
 
 
 
Deferred Credits and Other Liabilities:
 
 
 
Accumulated Deferred Income Taxes
496,223

 
481,221

Regulatory Liabilities
416,999

 
428,069

Accrued Pension, SERP and PBOP
107,007

 
124,457

Other Long-Term Liabilities
33,584

 
36,339

Total Deferred Credits and Other Liabilities
1,053,813

 
1,070,086

 
 
 
 
Long-Term Debt
951,834

 
655,173

 
 
 
 
Rate Reduction Bonds
561,727

 
583,331

 
 
 
 
Common Stockholder's Equity:
 
 
 
Common Stock
—

 
—

Capital Surplus, Paid In
678,134

 
678,134

Retained Earnings
453,891

 
627,258

Accumulated Other Comprehensive Loss
(2,248
)
 
(2,851
)
Common Stockholder's Equity
1,129,777

 
1,302,541

 
 
 
 
Commitments and Contingencies (Note 9)


 


 
 
 
 
Total Liabilities and Capitalization
$
4,141,002

 
$
4,127,356


The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.


13


PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF INCOME
(Unaudited)
 
For the Three Months Ended June 30,
 
For the Six Months Ended June 30,
(Thousands of Dollars)
2019
 
2018
 
2019
 
2018
 
 
 
 
 
 
 
 
Operating Revenues
$
240,900

 
$
235,146

 
$
517,335

 
$
502,497

 
 
 
 
 
 
 
 
Operating Expenses:
 
 
 
 
 
 
 
Purchased Power, Fuel and Transmission
85,768

 
83,494

 
199,299

 
193,212

Operations and Maintenance
52,729

 
46,487

 
105,359

 
97,867

Depreciation
23,261

 
22,808

 
46,180

 
46,301

Amortization of Regulatory Assets, Net
5,857

 
8,926

 
19,523

 
13,961

Energy Efficiency Programs
6,215

 
4,674

 
12,929

 
9,831

Taxes Other Than Income Taxes
20,725

 
21,879

 
38,037

 
38,680

Total Operating Expenses
194,555

 
188,268

 
421,327

 
399,852

Operating Income
46,345

 
46,878

 
96,008

 
102,645

Interest Expense
13,909

 
14,612

 
28,276

 
27,386

Other Income, Net
2,984

 
3,409

 
10,006

 
8,159

Income Before Income Tax Expense
35,420

 
35,675

 
77,738

 
83,418

Income Tax Expense
8,568

 
9,896

 
18,104

 
22,547

Net Income
$
26,852

 
$
25,779

 
$
59,634

 
$
60,871


The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.


CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
(Unaudited)
 
For the Three Months Ended June 30,
 
For the Six Months Ended June 30,
(Thousands of Dollars)
2019
 
2018
 
2019
 
2018
 
 
 
 
 
 
 
 
Net Income
$
26,852

 
$
25,779

 
$
59,634

 
$
60,871

Other Comprehensive Income, Net of Tax:
 
 
 
 
 
 
 
Qualified Cash Flow Hedging Instruments
269

 
277

 
538

 
567

Changes in Unrealized Gains/(Losses) on
  Marketable Securities
27

 
(8
)
 
65

 
(29
)
Other Comprehensive Income, Net of Tax
296

 
269

 
603

 
538

Comprehensive Income
$
27,148

 
$
26,048

 
$
60,237

 
$
61,409


The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.


14


PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF COMMON STOCKHOLDER'S EQUITY
(Unaudited)
 
For the Six Months Ended June 30, 2019
 
Common Stock
 
Capital
Surplus,
Paid In
 
Retained
Earnings
 
Accumulated
Other
Comprehensive
Loss
 
Total
Common
Stockholder's
Equity
(Thousands of Dollars, Except Stock Information)
Stock
 
Amount
 
 
 
 
Balance as of January 1, 2019
301

 
$
—

 
$
678,134

 
$
627,258

 
$
(2,851
)
 
$
1,302,541

Net Income
 

 
 

 
 
 
32,781

 
 
 
32,781

Dividends on Common Stock
 

 
 

 
 
 
(19,000
)
 
 
 
(19,000
)
Other Comprehensive Income
 

 
 

 
 
 
 

 
307

 
307

Balance as of March 31, 2019
301


—


678,134


641,039


(2,544
)

1,316,629

Net Income
 

 
 

 
 
 
26,852

 
 
 
26,852

Dividends on Common Stock
 

 
 

 
 
 
(214,000
)
 
 
 
(214,000
)
Other Comprehensive Income
 

 
 

 
 
 
 
 
296

 
296

Balance as of June 30, 2019
301

 
$
—


$
678,134


$
453,891


$
(2,248
)

$
1,129,777

 
For the Six Months Ended June 30, 2018
 
Common Stock
 
Capital
Surplus,
Paid In
 
Retained
Earnings
 
Accumulated
Other
Comprehensive
Loss
 
Total
Common
Stockholder's
Equity
(Thousands of Dollars, Except Stock Information)
Stock
 
Amount
 
 
 
 
Balance as of January 1, 2018
301

 
$
—

 
$
843,134

 
$
511,382

 
$
(3,922
)
 
$
1,350,594

Net Income
 

 
 

 
 
 
35,093

 
 
 
35,093

Other Comprehensive Income
 

 
 

 
 
 
 

 
269

 
269

Balance as of March 31, 2018
301


—


843,134


546,475


(3,653
)

1,385,956

Net Income
 

 
 

 
 
 
25,779

 
 
 
25,779

Capital Contributions from Eversource Parent
 
 
 
 
225,000

 
 
 
 
 
225,000

Return of Capital
 
 
 
 
(530,000
)
 
 
 
 
 
(530,000
)
Other
 
 
 
 
 
 
(1
)
 
 
 
(1
)
Other Comprehensive Income
 

 
 

 
 
 
 
 
269

 
269

Balance as of June 30, 2018
301

 
$
—


$
538,134


$
572,253


$
(3,384
)

$
1,107,003


The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.


15


PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)
 
For the Six Months Ended June 30,
(Thousands of Dollars)
2019
 
2018
 
 
 
 
Operating Activities:
 
 
 
Net Income
$
59,634

 
$
60,871

Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
 
 
 
Depreciation
46,180

 
46,301

Deferred Income Taxes
12,030

 
41,981

Regulatory Underrecoveries, Net
(29,377
)
 
(29,816
)
Amortization of Regulatory Assets, Net
19,523

 
13,961

Other
(7,381
)
 
(3,428
)
Changes in Current Assets and Liabilities:
 
 
 
Receivables and Unbilled Revenues, Net
7,658

 
(10,510
)
Materials, Supplies and Inventory
14,225

 
21,803

Taxes Receivable/Accrued, Net
18,029

 
(15,475
)
Accounts Payable
(1,159
)
 
(4,843
)
Other Current Assets and Liabilities, Net
(17,620
)
 
(8,050
)
Net Cash Flows Provided by Operating Activities
121,742

 
112,795

 
 
 
 
Investing Activities:
 
 
 
Investments in Property, Plant and Equipment
(132,791
)
 
(149,925
)
Proceeds from the Sale of Generation Assets
—

 
116,809

Other Investing Activities
743

 
243

Net Cash Flows Used in Investing Activities
(132,048
)
 
(32,873
)
 
 
 
 
Financing Activities:
 
 
 
Cash Dividends on Common Stock
(233,000
)
 
(150,000
)
Capital Contributions from Eversource Parent
—

 
225,000

Return of Capital
—

 
(530,000
)
Issuance of Long-Term Debt
300,000

 
—

Retirement of Long-Term Debt
—

 
(110,000
)
Issuance of Rate Reduction Bonds
—

 
635,663

Repayment of Rate Reduction Bonds
(30,727
)
 
—

Decrease in Notes Payable to Eversource Parent
(36,900
)
 
(144,200
)
Other Financing Activities
(2,703
)
 
(75
)
Net Cash Flows Used in Financing Activities
(3,330
)
 
(73,612
)
Net (Decrease)/Increase in Cash and Restricted Cash
(13,636
)
 
6,310

Cash and Restricted Cash - Beginning of Period
52,723

 
2,191

Cash and Restricted Cash - End of Period
$
39,087

 
$
8,501


The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.


16



EVERSOURCE ENERGY AND SUBSIDIARIES
THE CONNECTICUT LIGHT AND POWER COMPANY
NSTAR ELECTRIC COMPANY AND SUBSIDIARY
PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES

COMBINED NOTES TO CONDENSED FINANCIAL STATEMENTS (Unaudited)

Refer to the Glossary of Terms included in this combined Quarterly Report on Form 10-Q for abbreviations and acronyms used throughout the combined notes to the unaudited condensed financial statements.

1.    SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

A.    Basis of Presentation
Eversource Energy is a public utility holding company primarily engaged, through its wholly-owned regulated utility subsidiaries, in the energy delivery business.  Eversource Energy's wholly-owned regulated utility subsidiaries consist of CL&P, NSTAR Electric and PSNH (electric utilities), Yankee Gas and NSTAR Gas (natural gas utilities) and Aquarion (water utilities).  Eversource provides energy delivery and/or water service to approximately four million electric, natural gas and water customers through eight regulated utilities in Connecticut, Massachusetts and New Hampshire.

The unaudited condensed consolidated financial statements of Eversource, NSTAR Electric and PSNH include the accounts of each of their respective subsidiaries.  Intercompany transactions have been eliminated in consolidation.  The accompanying unaudited condensed consolidated financial statements of Eversource, NSTAR Electric and PSNH and the unaudited condensed financial statements of CL&P are herein collectively referred to as the "financial statements."

The combined notes to the financial statements have been prepared pursuant to the rules and regulations of the SEC.  Certain information and footnote disclosures included in annual financial statements prepared in accordance with GAAP have been omitted pursuant to such rules and regulations.  The accompanying financial statements should be read in conjunction with the Combined Notes to Financial Statements included in Item 8, "Financial Statements and Supplementary Data," of the Eversource 2018 Form 10-K, which was filed with the SEC on February 26, 2019. The preparation of the financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and the disclosure of contingent liabilities as of the date of the financial statements and the reported amounts of revenues and expenses during the reporting period.  Actual results could differ from those estimates.

The financial statements contain, in the opinion of management, all adjustments (including normal, recurring adjustments) necessary to present fairly Eversource's, CL&P's, NSTAR Electric's and PSNH's financial position as of June 30, 2019 and December 31, 2018, and the results of operations, comprehensive income and common shareholders' equity for the three and six months ended June 30, 2019 and 2018, and the cash flows for the six months ended June 30, 2019 and 2018. The results of operations and comprehensive income for the three and six months ended June 30, 2019 and 2018 and the cash flows for the six months ended June 30, 2019 and 2018 are not necessarily indicative of the results expected for a full year.  

Eversource consolidates CYAPC and YAEC because CL&P's, NSTAR Electric's and PSNH's combined ownership and voting interests in each of these entities is greater than 50 percent.  Intercompany transactions between CL&P, NSTAR Electric, PSNH and the CYAPC and YAEC companies have been eliminated in consolidation of the Eversource financial statements.

Eversource's utility subsidiaries' electric, natural gas and water distribution and transmission businesses are subject to rate-regulation that is based on cost recovery and meets the criteria for application of accounting guidance for entities with rate-regulated operations, which considers the effect of regulation on the differences in the timing of the recognition of certain revenues and expenses from those of other businesses and industries. See Note 2, "Regulatory Accounting," for further information.

Certain reclassifications of prior period data were made in the accompanying financial statements to conform to the current period presentation.

B.    Accounting Standards
Accounting Standards Issued but Not Yet Effective: In June 2016, the FASB issued Accounting Standards Update (“ASU”) 2016-13, Financial Instruments - Credit Losses (Topic 326), which provides a new model for recognizing credit losses on financial instruments based on an estimate of current expected credit losses. Under the new guidance, immediate recognition of all credit losses expected over the life of a financial instrument is required. The new standard also revises the other-than-temporary impairment model for available-for-sale debt securities. The standard is effective January 1, 2020, and requires a modified retrospective transition approach through a cumulative-effect adjustment to retained earnings. The Company is assessing the impacts of this standard on the accounting for credit losses on its financial instruments, including accounts receivable.

Accounting Standards Recently Adopted: On January 1, 2019, the Company adopted ASU 2016-02, Leases (Topic 842), which amended existing lease accounting guidance. The Company applied the Topic 842 lease criteria to new leases and lease renewals entered into effective on or after January 1, 2019.  The ASU required balance sheet recognition of leases deemed to be operating leases as well as additional disclosure requirements.  The recognition, measurement and presentation of expenses and cash flows were not significantly changed.


17


The Company also adopted the modified retrospective transition method allowed in ASU 2018-11, Leases (Topic 842) - Targeted Improvements, which allowed the Company to adopt the new leases standard as of January 1, 2019, with prior periods presented in the financial statements continuing to follow existing lease accounting guidance under Topic 840 (Leases) in the accounting literature.  Implementation of ASU 2018-11 had no effect on retained earnings, and the requirements of the new lease standard (Topic 842) are reflected in the 2019 financial statements and footnotes.

The Company elected the practical expedient package whereby it did not need to reassess whether or not an existing contract is or contains a lease or whether a lease is an operating or capital lease, and it did not need to reassess initial direct costs for leases. Election of this practical expedient allowed us to carry forward our historical lease classifications. The Company elected the practical expedient to not reevaluate land easements existing at adoption if they were not previously accounted for as leases. The Company also elected to use the discount rate as of the January 1, 2019 implementation date to discount its operating lease liabilities. The Company did not elect the hindsight practical expedient to determine the lease term for existing leases.

The Company determined the impact the ASUs had on its financial statements by reviewing its lease population and identifying lease data needed for the disclosure requirements. The Company implemented a new lease accounting system in 2019 to ensure ongoing compliance with the ASU’s requirements. Adoption of the new standard resulted in the recording of operating lease liabilities and right-of-use assets on the balance sheet upon transition at January 1, 2019 of $58.0 million at Eversource, $25.3 million at NSTAR Electric, $0.6 million at CL&P, and $0.6 million at PSNH. Implementation of the new guidance did not have an impact on each company’s results of operations or cash flows.

C.    Impairment of Northern Pass Transmission
Northern Pass is Eversource's planned 1,090 MW HVDC transmission line that would interconnect from the Québec-New Hampshire border to Franklin, New Hampshire and an associated alternating current radial transmission line between Franklin and Deerfield, New Hampshire. 

On March 30, 2018, the New Hampshire Site Evaluation Committee (“NHSEC”), one of the state regulatory agencies from which Northern Pass was required to obtain a siting permit, issued a written decision denying Northern Pass’ siting application. In the first quarter of 2018, Eversource conducted an impairment review of the Northern Pass project and concluded, at that time, that the recorded amount of project costs was recoverable. On July 12, 2018, the NHSEC issued a written decision denying Northern Pass’ April 2018 motion for rehearing, and on October 12, 2018, the New Hampshire Supreme Court accepted an appeal filed by Northern Pass that alleged that the NHSEC failed to follow applicable law in its review of the project. On July 19, 2019, the New Hampshire Supreme Court issued a decision denying Northern Pass’ appeal and affirming the NHSEC’s evaluation and decision that denied Northern Pass’ siting application.

Eversource evaluated the impact of the New Hampshire Supreme Court decision on the probability of construction and operation of Northern Pass. Eversource concluded that construction of the project was no longer probable and that substantially all of the capitalized project costs, which totaled $318 million, certain of which are subject to cost reimbursement agreements, were impaired. Eversource concluded that the New Hampshire Supreme Court decision is a subsequent event that required recognition in the financial statements as of and for the three and six months ended June 30, 2019.

Based on the conclusion that the construction of Northern Pass was not probable, Eversource recorded an impairment charge for all of the project costs associated with Northern Pass, which were primarily engineering design, siting, permitting and legal costs, along with appropriate allowances for funds used during construction, and recognized a receivable for certain cost reimbursement agreements. Additionally, Eversource recorded an impairment charge associated with the land acquired to construct Northern Pass in order to recognize the land at its estimated fair value based on assessed values and transaction costs. In total, this resulted in a pre-tax impairment charge of $239.6 million within Operating Income on the statement of income for the three and six months ended June 30, 2019, and was reflected in the Electric Transmission segment. The after-tax impact of the impairment charge was $204.4 million, or $0.64 per share, after giving effect to the estimated fair value of the related land, reimbursement agreements, and the impact of expected income tax benefits associated with the impairment charge. Eversource does not expect any significant estimated future cash expenditures associated with this impairment charge.

D.    Provision for Uncollectible Accounts
Eversource, including CL&P, NSTAR Electric and PSNH, presents its receivables at estimated net realizable value by maintaining a provision for uncollectible accounts.  This provision is determined based upon a variety of judgments and factors, including the application of an estimated uncollectible percentage to each receivable aging category.  The estimate is based upon historical collection and write-off experience and management's assessment of collectability from customers.  Management continuously assesses the collectability of receivables and adjusts collectability estimates based on actual experience.  Receivable balances are written off against the provision for uncollectible accounts when the customer accounts are terminated and these balances are deemed to be uncollectible.

The PURA allows CL&P and Yankee Gas to accelerate the recovery of accounts receivable balances attributable to qualified customers under financial or medical duress (uncollectible hardship accounts receivable) outstanding for greater than 180 days and 90 days, respectively.  The DPU allows NSTAR Electric and NSTAR Gas to recover in rates amounts associated with certain uncollectible hardship accounts receivable. These uncollectible hardship customer account balances are included in Regulatory Assets or Other Long-Term Assets on the balance sheets.


18


The total provision for uncollectible accounts is included in Receivables, Net on the balance sheets. The provision for uncollectible hardship accounts is included in the total uncollectible provision balance. The provision balances are as follows:
 
Total Provision for Uncollectible Accounts
 
Provision for Uncollectible Hardship Accounts
(Millions of Dollars)
As of June 30, 2019
 
As of December 31, 2018
 
As of June 30, 2019
 
As of December 31, 2018
Eversource
$
226.4

 
$
212.7

 
$
137.9

 
$
131.5

CL&P
88.7

 
88.0

 
70.9

 
71.9

NSTAR Electric
81.8

 
74.5

 
47.7

 
42.5

PSNH
11.2

 
11.1

 
—

 
—



Uncollectible expense associated with customers' accounts receivable included in Operations and Maintenance expense on the statements of income is as follows:
 
For the Three Months Ended
 
For the Six Months Ended
(Millions of Dollars)
June 30, 2019
 
June 30, 2018
 
June 30, 2019
 
June 30, 2018
Eversource
$
13.0

 
$
9.5

 
$
31.5

 
$
29.3

CL&P
3.5

 
3.8

 
7.6

 
7.7

NSTAR Electric
5.7

 
3.8

 
11.6

 
11.3

PSNH
1.4

 
1.5

 
3.1

 
3.2



E.    Fair Value Measurements
Fair value measurement guidance is applied to derivative contracts that are not elected or designated as "normal purchases" or "normal sales" ("normal") and to the marketable securities held in trusts.  Fair value measurement guidance is also applied to valuations of the investments used to calculate the funded status of pension and PBOP plans, the nonrecurring fair value measurements of nonfinancial assets such as goodwill and AROs, and the estimated fair value of preferred stock, long-term debt and RRBs.

Fair Value Hierarchy:  In measuring fair value, Eversource uses observable market data when available in order to minimize the use of unobservable inputs.  Inputs used in fair value measurements are categorized into three fair value hierarchy levels for disclosure purposes.  The entire fair value measurement is categorized based on the lowest level of input that is significant to the fair value measurement.  Eversource evaluates the classification of assets and liabilities measured at fair value on a quarterly basis, and Eversource's policy is to recognize transfers between levels of the fair value hierarchy as of the end of the reporting period.  The three levels of the fair value hierarchy are described below:

Level 1 - Inputs are quoted prices (unadjusted) in active markets for identical assets or liabilities as of the reporting date.  Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis.  

Level 2 - Inputs are quoted prices for similar instruments in active markets, quoted prices for identical or similar instruments in markets that are not active, and model-derived valuations in which all significant inputs are observable.

Level 3 - Quoted market prices are not available.  Fair value is derived from valuation techniques in which one or more significant inputs or assumptions are unobservable.  Where possible, valuation techniques incorporate observable market inputs that can be validated to external sources such as industry exchanges, including prices of energy and energy-related products.  

Uncategorized - Investments that are measured at net asset value are not categorized within the fair value hierarchy.

Determination of Fair Value:  The valuation techniques and inputs used in Eversource's fair value measurements are described in Note 4, "Derivative Instruments," Note 5, "Marketable Securities," and Note 11, "Fair Value of Financial Instruments," to the financial statements.

F.    Investments in Unconsolidated Affiliates
Investments in Offshore Wind Business: Eversource's offshore wind business includes ownership interests in North East Offshore and Bay State Wind, which collectively hold power purchase agreements for the Revolution Wind and South Fork Wind projects and are in process of negotiating a power purchase agreement for the Sunrise Wind project. Eversource's offshore wind projects are being developed in partnership with Ørsted.

On February 8, 2019, Eversource and Ørsted entered into a 50-50 partnership for key offshore wind assets in the Northeast. Eversource's initial payment and contribution under the terms of the partnership agreements totaled approximately $225 million for a 50 percent interest in North East Offshore, which holds the Revolution Wind and South Fork Wind power projects, as well as a 257 square-mile lease off the coasts of Massachusetts and Rhode Island. Eversource also has a 50 percent ownership in Bay State Wind, which holds the Sunrise Wind power project. These equity investments are included in long-term assets on the balance sheet and earnings impacts are included in Other Income, Net on the statement of income. As of June 30, 2019, Eversource's total equity investment balance in its offshore wind business was $499.5 million. In July 2019, Eversource made an additional capital contribution of $54.9 million.


19


G.    Other Income, Net
The components of Other Income, Net on the statements of income were as follows:
 
For the Three Months Ended
 
June 30, 2019
 
June 30, 2018
(Millions of Dollars)
Eversource
 
CL&P
 
NSTAR Electric
 
PSNH
 
Eversource
 
CL&P
 
NSTAR Electric
 
PSNH
Pension, SERP and PBOP Non-Service
   Income/(Expense) Components
$
5.8

 
$
(0.9
)
 
$
5.4

 
$
1.5

 
$
14.6

 
$
2.4

 
$
9.5

 
$
2.1

AFUDC Equity
13.1

 
3.2

 
5.1

 
0.9

 
10.9

 
3.3

 
3.9

 
—

Equity in Earnings (1)
25.9

 
0.1

 
0.2

 
—

 
22.9

 
—

 
0.4

 
—

Investment Income/(Loss)
(0.6
)
 
(0.1
)
 
(0.3
)
 
(0.1
)
 
(0.3
)
 
0.4

 
0.3

 
—

Interest Income
1.3

 
0.5

 
0.2

 
0.7

 
1.9

 
1.0

 
0.2

 
1.3

Other
0.4

 
0.1

 
0.1

 
—

 
0.1

 
—

 
—

 
—

Total Other Income, Net
$
45.9

 
$
2.9

 
$
10.7

 
$
3.0

 
$
50.1

 
$
7.1

 
$
14.3

 
$
3.4

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
For the Six Months Ended
 
June 30, 2019
 
June 30, 2018
(Millions of Dollars)
Eversource
 
CL&P
 
NSTAR Electric
 
PSNH
 
Eversource
 
CL&P
 
NSTAR Electric
 
PSNH
Pension, SERP and PBOP Non-Service
   Income/(Expense) Components
$
13.1

 
$
(1.6
)
 
$
12.4

 
$
2.0

 
$
29.8

 
$
5.3

 
$
17.9

 
$
4.4

AFUDC Equity
24.1

 
5.8

 
9.1

 
1.1

 
20.6

 
6.1

 
7.3

 
—

Equity in Earnings (1)
30.9

 
0.1

 
0.4

 
—

 
27.5

 
—

 
0.4

 
—

Investment Income/(Loss)
0.6

 
1.7

 
(0.6
)
 
0.2

 
0.4

 
0.2

 
0.9

 
0.1

Interest Income (2)
7.8

 
0.8

 
0.4

 
6.6

 
5.4

 
2.0

 
0.4

 
3.7

Other
0.4

 
(0.1
)
 
—

 
0.1

 
0.2

 
—

 
—

 
—

Total Other Income, Net
$
76.9

 
$
6.7

 
$
21.7

 
$
10.0

 
$
83.9

 
$
13.6

 
$
26.9

 
$
8.2


(1) Equity in earnings includes $20.4 million of unrealized gains associated with an investment in a renewable energy fund for both the three and six months ended June 30, 2019. For both the three and six months ended June 30, 2018, unrealized gains on this investment totaled $17.6 million.

(2) See Note 2, "Regulatory Accounting" for interest income recognized in 2019 for the equity return component of carrying charges on storm costs at PSNH.

H.    Other Taxes
Eversource's companies that serve customers in Connecticut collect gross receipts taxes levied by the state of Connecticut from their customers. These gross receipts taxes are recorded separately with collections in Operating Revenues and with payments in Taxes Other Than Income Taxes on the statements of income as follows:
 
For the Three Months Ended
 
For the Six Months Ended
(Millions of Dollars)
June 30, 2019
 
June 30, 2018
 
June 30, 2019
 
June 30, 2018
Eversource
$
36.4

 
$
35.6

 
$
81.4

 
$
79.0

CL&P
31.8

 
31.5

 
68.0

 
67.1



As agents for state and local governments, Eversource's companies that serve customers in Connecticut and Massachusetts collect certain sales taxes that are recorded on a net basis with no impact on the statements of income.   

Separate from above are amounts recorded as Taxes Other than Income Taxes related to the future remittance to the State of Connecticut of energy efficiency funds collected from customers in Operating Revenues. These amounts are $10.7 million and $21.4 million for the three and six months ended June 30, 2019, respectively, and $12.7 million and $25.4 million for the three and six months ended June 30, 2018, respectively. These amounts are recorded separately, with collections in Operating Revenues and with payments in Taxes Other than Income Taxes on the Eversource and CL&P statements of income.  


20


I.    Supplemental Cash Flow Information
Non-cash investing activities include plant additions included in Accounts Payable as follows:
(Millions of Dollars)
As of June 30, 2019
 
As of June 30, 2018
Eversource
$
323.7

 
$
305.7

CL&P
114.0

 
110.9

NSTAR Electric
85.2

 
71.1

PSNH
29.9

 
46.6



Beginning in 2019, Eversource began issuing treasury shares to satisfy awards under the Company's incentive plans, shares issued under the dividend reinvestment plan, and matching contributions under the Eversource 401k Plan. The issuance of treasury shares represents a non-cash transaction, as the treasury shares were used to fulfill Eversource's obligations that require the issuance of common shares.

The following table reconciles cash as reported on the balance sheets to the cash and restricted cash balance as reported on the statements of cash flows:
 
As of June 30, 2019
 
As of December 31, 2018
(Millions of Dollars)
Eversource
 
CL&P
 
NSTAR Electric
 
PSNH
 
Eversource
 
CL&P
 
NSTAR Electric
 
PSNH
Cash as reported on the Balance Sheets
$
20.6

 
$
2.2

 
$
0.2

 
$
0.3

 
$
108.1

 
$
87.7

 
$
1.6

 
$
1.4

Restricted cash included in:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Prepayments and Other Current Assets
54.1

 
4.6

 
6.1

 
35.0

 
72.1

 
3.5

 
13.0

 
47.5

Marketable Securities
20.5

 
0.3

 
0.1

 
0.6

 
25.9

 
0.4

 
0.1

 
0.6

Other Long-Term Assets
72.0

 
—

 
—

 
3.2

 
3.2

 
—

 
—

 
3.2

Cash and Restricted Cash reported on the
   Statements of Cash Flows
$
167.2

 
$
7.1

 
$
6.4

 
$
39.1

 
$
209.3

 
$
91.6

 
$
14.7

 
$
52.7



Restricted cash included in Prepayments and Other Current Assets primarily represents cash collections related to the PSNH RRB customer charges that are held in trust, and required ISO-NE cash deposits. Restricted cash included in Marketable Securities represents money market funds held in trusts to fund certain non-qualified executive benefits and restricted trusts to fund CYAPC and YAEC's spent nuclear fuel storage facilities obligations. Restricted cash included in Other Long-Term Assets at Eversource primarily relates to DOE Phase IV damages proceeds received at CYAPC and YAEC in the second quarter of 2019. See Note 9D, "Commitments and Contingencies - Spent Nuclear Fuel Obligations - Yankee Companies," for further information.

2.    REGULATORY ACCOUNTING

Eversource's utility companies are subject to rate regulation that is based on cost recovery and meets the criteria for application of accounting guidance for rate-regulated operations, which considers the effect of regulation on the timing of the recognition of certain revenues and expenses. The regulated companies' financial statements reflect the effects of the rate-making process.  The rates charged to the customers of Eversource's regulated companies are designed to collect each company's costs to provide service, including a return on investment.  

Management believes it is probable that each of the regulated companies will recover its respective investments in long-lived assets, including regulatory assets.  If management were to determine that it could no longer apply the accounting guidance applicable to rate-regulated enterprises to any of the regulated companies' operations, or if management could not conclude it is probable that costs would be recovered from customers in future rates, the costs would be charged to net income in the period in which the determination is made.

Regulatory Assets:  The components of regulatory assets were as follows:
 
As of June 30, 2019
 
As of December 31, 2018
(Millions of Dollars)
Eversource
 
CL&P
 
NSTAR
Electric
 
PSNH
 
Eversource
 
CL&P
 
NSTAR
Electric
 
PSNH
Benefit Costs
$
1,870.5

 
$
407.4

 
$
554.8

 
$
151.1

 
$
1,914.8

 
$
424.7

 
$
544.4

 
$
169.6

Income Taxes, Net
702.6

 
456.5

 
104.1

 
10.1

 
728.6

 
454.4

 
105.9

 
8.3

Securitized Stranded Costs
586.9

 
—

 
—

 
586.9

 
608.4

 
—

 
—

 
608.4

Storm Restoration Costs, Net
536.7

 
279.6

 
191.2

 
65.9

 
576.0

 
302.6

 
212.9

 
60.5

Regulatory Tracker Mechanisms
289.0

 
60.3

 
138.2

 
70.6

 
316.0

 
33.2

 
169.1

 
67.3

Derivative Liabilities
347.9

 
345.4

 
—

 
—

 
356.5

 
356.5

 
—

 
—

Goodwill-related
340.0

 
—

 
291.9

 
—

 
348.4

 
—

 
299.1

 
—

Asset Retirement Obligations
97.1

 
33.3

 
48.3

 
3.5

 
89.2

 
32.3

 
42.2

 
3.3

Other Regulatory Assets
148.8

 
26.0

 
60.5

 
17.7

 
208.0

 
27.0

 
64.6

 
12.1

Total Regulatory Assets
4,919.5

 
1,608.5


1,389.0


905.8


5,145.9

 
1,630.7


1,438.2


929.5

Less:  Current Portion
515.3

 
175.7

 
210.0

 
77.9

 
514.8

 
125.2

 
241.7

 
67.2

Total Long-Term Regulatory Assets
$
4,404.2

 
$
1,432.8


$
1,179.0


$
827.9


$
4,631.1

 
$
1,505.5


$
1,196.5


$
862.3



21



Storm Filings: On November 16, 2018, CL&P filed for recovery of $153 million of storm costs incurred from October 2017 through May 2018, with recovery over six years to begin May 1, 2019.  Through the course of the proceeding, CL&P updated its request to $145.5 million to reflect final invoicing and capitalization amounts. On April 17, 2019, PURA authorized recovery of $141.0 million as part of storm cost recovery and the remainder to be recorded to plant or other balance sheet accounts. All approved amounts will be fully recoverable through specific mechanisms or through future rate cases.

On March 26, 2019, the NHPUC approved the recovery of $38.1 million, plus carrying charges, of storm costs incurred from December 2013 through April 2016 and the transfer of funding from PSNH’s major storm reserve to recover those costs. The costs of these storms (excluding the equity return component of the carrying charges) were deferred as regulatory assets, and the funding reserve collected from customers was accrued as a regulatory liability. As a result of the duration of time between incurring storm costs in December 2013 through April 2016 and final approval from the NHPUC in 2019, PSNH recognized $5.2 million (pre-tax) for the equity return component of the carrying charges within Other Income, Net on the statement of income in the first quarter of 2019, which has been collected from customers. Also included in the March 26, 2019 NHPUC approval is a prospective requirement for PSNH to annually net its storm funding reserve collected from customers against deferred storm costs.

In addition, on June 27, 2019, the NHPUC approved a temporary rate settlement that permits PSNH to recover approximately $68.5 million in unrecovered storm costs over a five-year period beginning August 1, 2019, with debt carrying charges.

Regulatory Costs in Long-Term Assets:  Eversource's regulated companies had $142.0 million (including $43.6 million for CL&P, $61.4 million for NSTAR Electric and $15.3 million for PSNH) and $122.9 million (including $42.1 million for CL&P, $49.3 million for NSTAR Electric and $12.2 million for PSNH) of additional regulatory costs as of June 30, 2019 and December 31, 2018, respectively, that were included in long-term assets on the balance sheets.  These amounts represent incurred costs for which recovery has not yet been specifically approved by the applicable regulatory agency.  However, based on regulatory policies or past precedent on similar costs, management believes it is probable that these costs will ultimately be approved and recovered from customers in rates.

Regulatory Liabilities:  The components of regulatory liabilities were as follows:
 
As of June 30, 2019
 
As of December 31, 2018
(Millions of Dollars)
Eversource
 
CL&P
 
NSTAR
Electric
 
PSNH
 
Eversource
 
CL&P
 
NSTAR
Electric
 
PSNH
EDIT due to Tax Cuts and Jobs Act
$
2,860.7

 
$
1,028.7

 
$
1,090.0

 
$
395.4

 
$
2,883.0

 
$
1,031.0

 
$
1,103.7

 
$
396.4

Cost of Removal
544.9

 
51.0

 
319.4

 
21.4

 
521.0

 
39.9

 
307.1

 
22.1

Benefit Costs
83.8

 
—

 
70.9

 
—

 
91.2

 
—

 
76.9

 
—

Regulatory Tracker Mechanisms
333.3

 
110.0

 
141.9

 
31.2

 
309.0

 
89.5

 
163.7

 
48.3

AFUDC - Transmission
71.7

 
46.7

 
25.0

 
—

 
70.7

 
47.4

 
23.3

 
—

Revenue Subject to Refund due to Tax Cuts
  and Jobs Act
29.2

 
—

 
—

 
19.1

 
24.6

 
—

 
—

 
12.6

Other Regulatory Liabilities
96.1

 
29.4

 
38.6

 
4.1

 
80.2

 
24.0

 
29.2

 
4.2

Total Regulatory Liabilities
4,019.7

 
1,265.8


1,685.8


471.2


3,979.7

 
1,231.8


1,703.9


483.6

Less:  Current Portion
379.9

 
112.4

 
171.0

 
54.2

 
370.2

 
109.6

 
190.6

 
55.5

Total Long-Term Regulatory Liabilities
$
3,639.8

 
$
1,153.4


$
1,514.8


$
417.0


$
3,609.5

 
$
1,122.2


$
1,513.3


$
428.1




22



3.    PROPERTY, PLANT AND EQUIPMENT AND ACCUMULATED DEPRECIATION

The following tables summarize property, plant and equipment by asset category:
Eversource
As of June 30, 2019
 
As of December 31, 2018
(Millions of Dollars)
 
Distribution - Electric
$
15,472.1

 
$
15,071.1

Distribution - Natural Gas
3,632.9

 
3,546.2

Transmission - Electric
10,449.5

 
10,153.9

Distribution - Water
1,664.1

 
1,639.8

Solar
196.9

 
164.1

Utility
31,415.5

 
30,575.1

Other (1)
882.4

 
778.6

Property, Plant and Equipment, Gross
32,297.9

 
31,353.7

Less:  Accumulated Depreciation
 
 
 
Utility   
(7,357.9
)
 
(7,126.2
)
Other
(363.1
)
 
(336.7
)
Total Accumulated Depreciation
(7,721.0
)
 
(7,462.9
)
Property, Plant and Equipment, Net
24,576.9

 
23,890.8

Construction Work in Progress
1,727.5

 
1,719.6

Total Property, Plant and Equipment, Net
$
26,304.4

 
$
25,610.4


 
As of June 30, 2019
 
As of December 31, 2018
(Millions of Dollars)
CL&P
 
NSTAR
Electric
 
PSNH
 
CL&P
 
NSTAR
Electric
 
PSNH
Distribution - Electric
$
6,352.8

 
$
6,921.3

 
$
2,238.3

 
$
6,176.4

 
$
6,756.4

 
$
2,178.6

Transmission - Electric
4,880.6

 
4,148.8

 
1,415.2

 
4,700.5

 
4,065.9

 
1,338.7

Solar
—

 
196.9

 
—

 
—

 
164.1

 
—

Property, Plant and Equipment, Gross
11,233.4

 
11,267.0

 
3,653.5

 
10,876.9

 
10,986.4

 
3,517.3

Less:  Accumulated Depreciation
(2,352.2
)
 
(2,814.9
)
 
(806.4
)
 
(2,302.6
)
 
(2,702.0
)
 
(772.9
)
Property, Plant and Equipment, Net
8,881.2

 
8,452.1

 
2,847.1

 
8,574.3

 
8,284.4

 
2,744.4

Construction Work in Progress
404.4

 
623.7

 
122.2

 
335.4

 
510.3

 
135.7

Total Property, Plant and Equipment, Net
$
9,285.6

 
$
9,075.8

 
$
2,969.3

 
$
8,909.7

 
$
8,794.7

 
$
2,880.1



(1) 
These assets are primarily comprised of building improvements, computer software, hardware and equipment at Eversource Service.

In the second quarter of 2019, Eversource recorded an impairment charge for the NPT project costs, which had been recorded within Construction Work in Progress and also the Transmission - Electric asset category. For further information regarding the impairment of NPT, see Note 1C, "Summary of Significant Accounting Policies - Impairment of Northern Pass Transmission," to the financial statements.

4.    DERIVATIVE INSTRUMENTS

The electric and natural gas companies purchase and procure energy and energy-related products, which are subject to price volatility, for their customers.  The costs associated with supplying energy to customers are recoverable from customers in future rates.  These regulated companies manage the risks associated with the price volatility of energy and energy-related products through the use of derivative and non-derivative contracts.  

Many of the derivative contracts meet the definition of, and are designated as, normal and qualify for accrual accounting under the applicable accounting guidance.  The costs and benefits of derivative contracts that meet the definition of normal are recognized in Operating Expenses on the statements of income, as applicable, as electricity or natural gas is delivered.

Derivative contracts that are not designated as normal are recorded at fair value as current or long-term Derivative Assets or Derivative Liabilities on the balance sheets.  For the electric and natural gas companies, regulatory assets or regulatory liabilities are recorded to offset the fair values of derivatives, as contract settlement amounts are recovered from, or refunded to, customers in their respective energy supply rates.  


23


The gross fair values of derivative assets and liabilities with the same counterparty are offset and reported as net Derivative Assets or Derivative Liabilities, with current and long-term portions, on the balance sheets.  The following table presents the gross fair values of contracts, categorized by risk type, and the net amounts recorded as current or long-term derivative assets or liabilities:
 
 
 
As of June 30, 2019
 
As of December 31, 2018
(Millions of Dollars)
Fair Value Hierarchy
 
Commodity Supply and Price Risk
Management
 
Netting (1)
 
Net Amount
Recorded as a Derivative
 
Commodity Supply and Price Risk
Management
 
Netting (1)
 
Net Amount
Recorded as
a Derivative
Current Derivative Assets:
 
 
 
 
 
 
 
 
 
 
 
 
 
CL&P
Level 3
 
$
11.1

 
$
(0.3
)
 
$
10.8

 
$
9.6

 
$
(3.4
)
 
$
6.2

Other
Level 2
 
—

 
—

 
—

 
1.5

 
(0.9
)
 
0.6

Long-Term Derivative Assets:
 
 
 
 
 
 
 
 
 
 
 
 
 
CL&P
Level 3
 
71.8

 
(2.2
)
 
69.6

 
74.2

 
(2.3
)
 
71.9

Current Derivative Liabilities:
 
 
 
 
 
 
 
 
 
 
 
 
 
CL&P
Level 3
 
(62.1
)
 
—

 
(62.1
)
 
(55.1
)
 
—

 
(55.1
)
Other
Level 2
 
(2.4
)
 
—

 
(2.4
)
 
—

 
—

 
—

Long-Term Derivative Liabilities:
 
 
 
 
 
 
 
 
 
 
 
 
 
CL&P
Level 3
 
(363.7
)
 
—

 
(363.7
)
 
(379.5
)
 
—

 
(379.5
)
Other
Level 2
 
(0.1
)
 
—

 
(0.1
)
 
—

 
—

 
—


(1) 
Amounts represent derivative assets and liabilities that Eversource elected to record net on the balance sheets.  These amounts are subject to master netting agreements or similar agreements for which the right of offset exists.

For further information on the fair value of derivative contracts, see Note 1E, "Summary of Significant Accounting Policies - Fair Value Measurements," to the financial statements.

Derivative Contracts at Fair Value with Offsetting Regulatory Amounts
Commodity Supply and Price Risk Management:  As required by regulation, CL&P, along with UI, has capacity-related contracts with generation facilities.  CL&P has a sharing agreement with UI, with 80 percent of the costs or benefits of each contract borne by or allocated to CL&P and 20 percent borne by or allocated to UI.  The combined capacities of these contracts as of June 30, 2019 and December 31, 2018 are 679 MW and 787 MW, respectively.  The capacity contracts extend through 2026 and obligate both CL&P and UI to make or receive payments on a monthly basis to or from the generation facilities based on the difference between a set capacity price and the capacity market price received in the ISO-NE capacity markets.  In addition, CL&P has a contract to purchase 0.1 million MWh of energy per year through 2020.   

As of June 30, 2019 and December 31, 2018, Eversource had New York Mercantile Exchange ("NYMEX") financial contracts for natural gas futures in order to reduce variability associated with the price of 7.1 million and 12.5 million MMBtu of natural gas, respectively.

For the three months ended June 30, 2019 and 2018, there were losses of $5.1 million and gains of $8.6 million, respectively, deferred as regulatory costs, which reflect the change in fair value associated with Eversource's derivative contracts. For the six months ended June 30, 2019 and 2018, there were losses of $10.3 million and $27.5 million, respectively.

Fair Value Measurements of Derivative Instruments
Derivative contracts classified as Level 2 in the fair value hierarchy relate to the financial contracts for natural gas futures.  Prices are obtained from broker quotes and are based on actual market activity.  The contracts are valued using NYMEX natural gas prices.  Valuations of these contracts also incorporate discount rates using the yield curve approach.
 
The fair value of derivative contracts classified as Level 3 utilizes significant unobservable inputs.  The fair value is modeled using income techniques, such as discounted cash flow valuations adjusted for assumptions related to exit price.  Significant observable inputs for valuations of these contracts include energy and energy-related product prices in future years for which quoted prices in an active market exist.  Fair value measurements categorized in Level 3 of the fair value hierarchy are prepared by individuals with expertise in valuation techniques, pricing of energy and energy-related products, and accounting requirements.  The future power and capacity prices for periods that are not quoted in an active market or established at auction are based on available market data and are escalated based on estimates of inflation in order to address the full term of the contract.  

Valuations of derivative contracts using a discounted cash flow methodology include assumptions regarding the timing and likelihood of scheduled payments and also reflect non-performance risk, including credit, using the default probability approach based on the counterparty's credit rating for assets and the Company's credit rating for liabilities.  Valuations incorporate estimates of premiums or discounts that would be required by a market participant to arrive at an exit price, using historical market transactions adjusted for the terms of the contract.  


24


The following is a summary of Level 3 derivative contracts and the range of the significant unobservable inputs utilized in the valuations over the duration of the contracts:
 
As of June 30, 2019
 
As of December 31, 2018
CL&P
Range
 
Period Covered
 
Range
 
Period Covered
Capacity Prices
$
4.30

 
—
 
7.34

 
per kW-Month
 
2023 - 2026
 
$
4.30

 
—
 
7.44

 
per kW-Month
 
2022 - 2026
Forward Reserve
0.75

 
—
 
1.78

 
per kW-Month
 
2019 - 2024
 
0.75

 
—
 
1.78

 
per kW-Month
 
2019 - 2024


Exit price premiums of 3.1 percent through 14.6 percent are also applied to these contracts and reflect the uncertainty and illiquidity premiums that would be required based on the most recent market activity available for similar type contracts.

Significant increases or decreases in future capacity or forward reserve prices in isolation would decrease or increase, respectively, the fair value of the derivative liability.  Any increases in risk premiums would increase the fair value of the derivative liability.  Changes in these fair values are recorded as a regulatory asset or liability and do not impact net income.  

Valuations using significant unobservable inputs:  The following table presents changes in the Level 3 category of derivative assets and derivative liabilities measured at fair value on a recurring basis.  The derivative assets and liabilities are presented on a net basis.
CL&P
For the Three Months Ended June 30,
 
For the Six Months Ended June 30,
(Millions of Dollars)
2019
 
2018
 
2019
 
2018
Derivatives, Net:
 
 
 
 
 
 
 
Fair Value as of Beginning of Period
$
(353.1
)
 
$
(386.5
)
 
$
(356.5
)
 
$
(362.3
)
Net Realized/Unrealized (Losses)/Gains Included
  in Regulatory Assets
(2.5
)
 
8.6

 
(7.8
)
 
(28.2
)
Settlements
10.2

 
8.6

 
18.9

 
21.2

Fair Value as of End of Period
$
(345.4
)
 
$
(369.3
)
 
$
(345.4
)
 
$
(369.3
)


5.    MARKETABLE SECURITIES

Eversource holds marketable securities that are primarily used to fund certain non-qualified executive benefits.  The trusts that hold marketable securities are not subject to regulatory oversight by state or federal agencies.  CYAPC and YAEC maintain legally restricted trusts, each of which holds marketable securities, to fund the spent nuclear fuel removal obligations of their nuclear fuel storage facilities.

Equity Securities: Unrealized gains and losses on equity securities held in Eversource's non-qualified executive benefit trust are recorded in Other Income, Net on the statements of income. The fair value of these equity securities as of June 30, 2019 and December 31, 2018 was $45.2 million and $44.0 million, respectively.  For the three months ended June 30, 2019 and 2018, there were unrealized gains of $2.3 million and $0.9 million, respectively, recorded in Other Income, Net related to these equity securities. For the six months ended June 30, 2019 and 2018, there were unrealized gains of $3.3 million and $0.2 million, respectively.

Eversource's equity securities also include CYAPC's and YAEC's marketable securities held in spent nuclear fuel trusts, which had fair values of $158.5 million and $200.0 million as of June 30, 2019 and December 31, 2018, respectively.  Unrealized gains and losses for these spent nuclear fuel trusts are subject to regulatory accounting treatment and are recorded in Marketable Securities with the corresponding offset to Other Long-Term Liabilities on the balance sheets, with no impact on the statements of income.

Available-for-Sale Debt Securities: The following is a summary of the available-for-sale debt securities, which are recorded at fair value and are included in current and long-term Marketable Securities on the balance sheets.
 
As of June 30, 2019
 
As of December 31, 2018
Eversource
(Millions of Dollars)
Amortized Cost
 
Pre-Tax
Unrealized Gains
 
Pre-Tax
Unrealized
Losses
 
Fair Value
 
Amortized Cost
 
Pre-Tax
Unrealized Gains
 
Pre-Tax
Unrealized
Losses
 
Fair Value
Debt Securities
$
204.3

 
$
5.4

 
$
(0.1
)
 
$
209.6

 
$
190.0

 
$
0.4

 
$
(4.0
)
 
$
186.4



Eversource's debt securities include CYAPC's and YAEC's marketable securities held in spent nuclear fuel trusts in the amounts of $172.4 million and $143.9 million as of June 30, 2019 and December 31, 2018, respectively.

Unrealized gains and losses on available-for-sale debt securities held in Eversource's non-qualified benefit trust are recorded in Accumulated Other Comprehensive Income. There have been no significant unrealized losses, other-than-temporary impairments, or credit losses for the three and six months ended June 30, 2019 and 2018.  Factors considered in determining whether a credit loss exists include the duration and severity of the impairment, adverse conditions specifically affecting the issuer, and the payment history, ratings and rating changes of the security.  For asset-backed debt securities, underlying collateral and expected future cash flows are also evaluated.


25


As of June 30, 2019, the contractual maturities of available-for-sale debt securities were as follows:  
Eversource
(Millions of Dollars)
Amortized Cost
 
Fair Value
Less than one year (1)
$
26.9

 
$
26.9

One to five years
48.8

 
49.6

Six to ten years
38.4

 
40.0

Greater than ten years
90.2

 
93.1

Total Debt Securities
$
204.3

 
$
209.6


(1) 
Amounts in the Less than one year category include securities in the CYAPC and YAEC spent nuclear fuel trusts, which are restricted and are classified in long-term Marketable Securities on the balance sheets.

Realized Gains and Losses:  Realized gains and losses are recorded in Other Income, Net for Eversource's benefit trust and are offset in Other Long-Term Liabilities for CYAPC and YAEC.  Eversource utilizes the specific identification basis method for the Eversource non-qualified benefit trust, and the average cost basis method for the CYAPC and YAEC spent nuclear fuel trusts to compute the realized gains and losses on the sale of marketable securities.

Fair Value Measurements:  The following table presents the marketable securities recorded at fair value on a recurring basis by the level in which they are classified within the fair value hierarchy:
Eversource
(Millions of Dollars)
As of June 30, 2019
 
As of December 31, 2018
Level 1:  
 
 
 
Mutual Funds and Equities
$
203.7

 
$
244.0

Money Market Funds
20.5

 
25.9

Total Level 1
$
224.2

 
$
269.9

Level 2:
 
 
 
U.S. Government Issued Debt Securities (Agency and Treasury)
$
107.0

 
$
79.6

Corporate Debt Securities
46.1

 
39.5

Asset-Backed Debt Securities
13.4

 
14.0

Municipal Bonds
12.8

 
19.2

Other Fixed Income Securities
9.8

 
8.2

Total Level 2
$
189.1

 
$
160.5

Total Marketable Securities
$
413.3

 
$
430.4



U.S. government issued debt securities are valued using market approaches that incorporate transactions for the same or similar bonds and adjustments for yields and maturity dates.  Corporate debt securities are valued using a market approach, utilizing recent trades of the same or similar instruments and also incorporating yield curves, credit spreads and specific bond terms and conditions.  Asset-backed debt securities include collateralized mortgage obligations, commercial mortgage backed securities, and securities collateralized by auto loans, credit card loans or receivables.  Asset-backed debt securities are valued using recent trades of similar instruments, prepayment assumptions, yield curves, issuance and maturity dates, and tranche information.  Municipal bonds are valued using a market approach that incorporates reported trades and benchmark yields.  Other fixed income securities are valued using pricing models, quoted prices of securities with similar characteristics, and discounted cash flows.

6.    SHORT-TERM AND LONG-TERM DEBT

Short-Term Debt - Commercial Paper Programs and Credit Agreements: Eversource parent has a $1.45 billion commercial paper program allowing Eversource parent to issue commercial paper as a form of short-term debt.  Eversource parent, CL&P, PSNH, NSTAR Gas and Yankee Gas are also parties to a five-year $1.45 billion revolving credit facility, which terminates on December 8, 2023. The revolving credit facility serves to backstop Eversource parent's $1.45 billion commercial paper program.  

NSTAR Electric has a $650 million commercial paper program allowing NSTAR Electric to issue commercial paper as a form of short-term debt. NSTAR Electric is also a party to a five-year $650 million revolving credit facility, which terminates on December 8, 2023. The revolving credit facility serves to backstop NSTAR Electric's $650 million commercial paper program.  


26


The amount of borrowings outstanding and available under the commercial paper programs were as follows:
 
Borrowings Outstanding as of
 
Available Borrowing Capacity as of
 
Weighted-Average Interest Rate as of
 
June 30, 2019
 
December 31, 2018
 
June 30, 2019
 
December 31, 2018
 
June 30, 2019
 
December 31, 2018
(Millions of Dollars)
 
 
 
 
 
Eversource Parent Commercial Paper Program
$
566.0

 
$
631.5

 
$
884.0

 
$
818.5

 
2.55
%
 
2.77
%
NSTAR Electric Commercial Paper Program
163.0

 
278.5

 
487.0

 
371.5

 
2.42
%
 
2.50
%


There were no borrowings outstanding on either the Eversource parent or NSTAR Electric revolving credit facilities as of June 30, 2019 or December 31, 2018. Eversource's water distribution segment has a $100 million revolving credit facility, which expires on August 19, 2019, and there were no borrowings outstanding as of June 30, 2019 or December 31, 2018.

Amounts outstanding under the commercial paper programs and revolving credit facility are included in Notes Payable and are classified in current liabilities on the Eversource and NSTAR Electric balance sheets as all borrowings are outstanding for no more than 364 days at one time.

We expect the future operating cash flows of Eversource, CL&P, NSTAR Electric and PSNH, along with our existing borrowing availability and access to both debt and equity markets, will be sufficient to meet any working capital and future operating requirements, and capital investment forecasted opportunities.

Intercompany Borrowings: Eversource parent uses its available capital resources to provide loans to its subsidiaries to assist them in meeting their short-term borrowing needs. In addition, growth in Eversource's key business initiatives requires cash infusion to those subsidiaries. Eversource parent records intercompany interest income from its loans to subsidiaries, which is eliminated in consolidation. Intercompany loans from Eversource parent to its subsidiaries are eliminated in consolidation on Eversource's balance sheets. As of June 30, 2019, there were intercompany loans from Eversource parent to CL&P of $259.4 million, to PSNH of $20.1 million, and to Harbor Electric Energy Company, a wholly-owned subsidiary of NSTAR Electric ("HEEC"), of $40.3 million. As of December 31, 2018, there were intercompany loans from Eversource parent to PSNH of $57.0 million. Intercompany loans from Eversource parent are included in Notes Payable to Eversource Parent and are classified in current liabilities on the respective subsidiary's balance sheets.

Long-Term Debt Issuance Authorization: On April 26, 2019, the NHPUC approved PSNH’s request for authorization to issue up to $300 million in long-term debt through December 31, 2019.

Long-Term Debt: The following table summarizes long-term debt issuances and repayments:
(Millions of Dollars)
Issue Date
 
Issuance/(Repayment)
 
Maturity Date
 
Use of Proceeds for Issuance/
Repayment Information
CL&P:
 
 
 
 
 
 
 
4.00% 2018 Series A First Mortgage Bonds (1)
April 2019
 
$
300.0

 
April 2048
 
Repaid short-term borrowings that were used to repay long-term debt that matured on February 1, 2019 and fund capital expenditures and working capital
5.50% 2009 Series A First Mortgage Bonds
February 2009
 
(250.0
)
 
February 2019
 
Repaid at maturity on February 1, 2019
NSTAR Electric:
 
 
 
 
 
 
 
3.25% 2019 Debentures
May 2019
 
400.0

 
May 2029
 
Repaid short-term borrowings that were used to fund investments in eligible green expenditures
PSNH:
 
 
 
 
 
 
 
3.60% 2019 Series T First Mortgage Bonds
June 2019
 
300.0

 
July 2049
 
Repay long-term debt due to mature in December 2019, repaid short-term borrowings and fund capital expenditures and working capital
Other:
 
 
 
 
 
 
 
NSTAR Gas 3.74% Series Q First Mortgage Bonds
July 2019
 
75.0

 
August 2049
 
Repaid short-term borrowings and fund capital expenditures and working capital

(1) 
These bonds are part of the same series issued by CL&P in March 2018. The aggregate outstanding principal amount of these bonds is now $800 million.

As a result of the NSTAR Gas debt issuance in July 2019, $75 million of current portion of long-term debt was reclassified to Long-Term Debt on Eversource's consolidated balance sheet as of June 30, 2019.

7.    RATE REDUCTION BONDS AND VARIABLE INTEREST ENTITIES

Rate Reduction Bonds: On May 8, 2018, PSNH Funding, a wholly-owned subsidiary of PSNH, issued $635.7 million of securitized RRBs in multiple tranches with a weighted average interest rate of 3.66 percent, and final maturity dates ranging from 2026 to 2035.  The RRBs are expected to be repaid by February 1, 2033. RRB payments consist of principal and interest and will be paid semi-annually, beginning on February 1, 2019. The RRBs were issued pursuant to a finance order issued by the NHPUC on January 30, 2018 to recover remaining costs resulting from the divestiture of PSNH’s generation assets.


27


PSNH Funding is considered a VIE primarily because the equity capitalization is insufficient to support its operations. PSNH has the power to direct the significant activities of the VIE and is most closely associated with the VIE as compared to other interest holders. Therefore, PSNH is considered the primary beneficiary and consolidates PSNH Funding in its consolidated financial statements. The following tables summarize the impact of PSNH Funding on PSNH's balance sheets and income statements:
(Millions of Dollars)
 
 
 
Balance Sheet:
As of June 30, 2019
 
As of December 31, 2018
Restricted Cash - Current Portion (included in Prepayments and Other Current Assets)
$
35.0

 
$
47.5

Restricted Cash - Long-Term Portion (included in Other Long-Term Assets)
3.2

 
3.2

Securitized Stranded Costs (included in Regulatory Assets)
586.9

 
608.4

Other Regulatory Liabilities (included in Regulatory Liabilities)
7.9

 
5.8

Accrued Interest (included in Other Current Liabilities)
8.9

 
14.4

Rate Reduction Bonds - Current Portion
43.2

 
52.3

Rate Reduction Bonds - Long-Term Portion
561.7

 
583.3

(Millions of Dollars)
For the Three Months Ended
 
For the Six Months Ended
Income Statement:
June 30, 2019
 
June 30, 2018
 
June 30, 2019
 
June 30, 2018
Amortization of RRB Principal (included in Amortization of Regulatory Assets, Net)
$
10.8

 
$
6.8

 
$
21.5

 
$
6.8

Interest Expense on RRB Principal (included in Interest Expense)
5.3

 
2.8

 
10.7

 
2.8



8.    PENSION BENEFITS AND POSTRETIREMENT BENEFITS OTHER THAN PENSION

Eversource provides defined benefit retirement plans ("Pension Plans") that cover eligible employees.  In addition to the Pension Plans, Eversource maintains non-qualified defined benefit retirement plans ("SERP Plans"), which provide benefits in excess of Internal Revenue Code limitations to eligible participants consisting of current and retired employees. Eversource also provides defined benefit postretirement plans ("PBOP Plans") that provide life insurance and a health reimbursement arrangement created for the purpose of reimbursing retirees and dependents for health insurance premiums and certain medical expenses to eligible employees that meet certain age and service eligibility requirements.

The components of net periodic benefit expense/(income) for the Pension, SERP and PBOP Plans, prior to amounts capitalized as Property, Plant and Equipment or deferred as regulatory assets for future recovery, are shown below.  The service cost component of net periodic benefit expense, less the capitalized portion, is included in Operations and Maintenance expense on the statements of income. The remaining components of net periodic benefit expense/(income), less the deferred portion, are included in Other Income, Net on the statements of income. Pension, SERP and PBOP expense reflected in the statements of cash flows for CL&P, NSTAR Electric and PSNH does not include the intercompany allocations or the corresponding capitalized and deferred portion, as these amounts are cash settled on a short-term basis.
 
Pension and SERP
 
For the Three Months Ended June 30, 2019
 
For the Three Months Ended June 30, 2018
(Millions of Dollars)
Eversource
 
CL&P
 
NSTAR Electric
 
PSNH
 
Eversource
 
CL&P
 
NSTAR Electric
 
PSNH
Service Cost
$
16.1

 
$
4.4

 
$
3.6

 
$
1.5

 
$
20.7

 
$
5.2

 
$
4.3

 
$
2.7

Interest Cost
54.8

 
11.4

 
12.3

 
6.0

 
49.1

 
10.5

 
10.9

 
5.5

Expected Return on Pension Plan Assets
(91.7
)
 
(18.1
)
 
(24.2
)
 
(10.1
)
 
(97.9
)
 
(19.4
)
 
(26.6
)
 
(10.8
)
Actuarial Loss
35.6

 
6.3

 
11.8

 
2.3

 
35.7

 
7.1

 
10.1

 
3.3

Prior Service Cost
0.3

 
—

 
—

 
—

 
2.1

 
0.2

 
0.1

 
0.1

Total Net Periodic Benefit Expense/(Income)
$
15.1

 
$
4.0

 
$
3.5

 
$
(0.3
)
 
$
9.7

 
$
3.6

 
$
(1.2
)
 
$
0.8

Intercompany Allocations
N/A

 
$
5.8

 
$
5.3

 
$
—

 
N/A

 
$
1.5

 
$
1.6

 
$
0.5

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Pension and SERP
 
For the Six Months Ended June 30, 2019
 
For the Six Months Ended June 30, 2018
(Millions of Dollars)
Eversource
 
CL&P
 
NSTAR Electric
 
PSNH
 
Eversource
 
CL&P
 
NSTAR Electric
 
PSNH
Service Cost
$
35.4

 
$
9.2

 
$
7.5

 
$
4.1

 
$
43.1

 
$
11.0

 
$
9.0

 
$
5.7

Interest Cost
109.1

 
23.0

 
24.2

 
12.2

 
97.8

 
20.9

 
21.7

 
10.9

Expected Return on Pension Plan Assets
(183.8
)
 
(36.9
)
 
(48.6
)
 
(20.4
)
 
(195.8
)
 
(40.2
)
 
(51.8
)
 
(21.8
)
Actuarial Loss
72.1

 
14.3

 
21.2

 
5.9

 
71.8

 
14.8

 
20.7

 
6.5

Prior Service Cost
0.6

 
—

 
0.1

 
—

 
4.1

 
0.6

 
0.1

 
0.2

Total Net Periodic Benefit Expense/(Income)
$
33.4

 
$
9.6

 
$
4.4

 
$
1.8

 
$
21.0

 
$
7.1

 
$
(0.3
)
 
$
1.5

Intercompany Allocations
N/A

 
$
13.6

 
$
8.4

 
$
2.5

 
N/A

 
$
3.0

 
$
3.2

 
$
1.0



28


 
PBOP
 
For the Three Months Ended June 30, 2019
 
For the Three Months Ended June 30, 2018
(Millions of Dollars)
Eversource
 
CL&P
 
NSTAR
Electric
 
PSNH
 
Eversource
 
CL&P
 
NSTAR
Electric
 
PSNH
Service Cost
$
1.8

 
$
0.3

 
$
0.4

 
$
0.1

 
$
2.5

 
$
0.4

 
$
0.5

 
$
0.3

Interest Cost
8.2

 
1.6

 
2.4

 
0.8

 
6.8

 
1.5

 
2.2

 
0.9

Expected Return on Plan Assets
(16.8
)
 
(2.3
)
 
(7.5
)
 
(1.3
)
 
(16.7
)
 
(2.6
)
 
(8.1
)
 
(1.5
)
Actuarial Loss
1.6

 
0.3

 
0.7

 
—

 
1.6

 
0.4

 
0.4

 
0.2

Prior Service Cost/(Credit)
(5.8
)
 
0.3

 
(4.2
)
 
0.1

 
(5.7
)
 
0.3

 
(4.3
)
 
0.1

Total Net Periodic Benefit Expense/(Income)
$
(11.0
)
 
$
0.2

 
$
(8.2
)
 
$
(0.3
)
 
$
(11.5
)
 
$
—

 
$
(9.3
)
 
$
—

Intercompany Allocations
N/A

 
$
(0.3
)
 
$
(0.4
)
 
$
(0.1
)
 
N/A

 
$
(0.2
)
 
$
(0.3
)
 
$
(0.1
)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
PBOP
 
For the Six Months Ended June 30, 2019
 
For the Six Months Ended June 30, 2018
(Millions of Dollars)
Eversource
 
CL&P
 
NSTAR
Electric
 
PSNH
 
Eversource
 
CL&P
 
NSTAR
Electric
 
PSNH
Service Cost
$
3.9

 
$
0.7

 
$
0.9

 
$
0.4

 
$
5.0

 
$
0.9

 
$
1.0

 
$
0.6

Interest Cost
16.3

 
3.1

 
4.7

 
1.7

 
14.4

 
2.9

 
4.4

 
1.6

Expected Return on Plan Assets
(33.4
)
 
(4.5
)
 
(15.1
)
 
(2.8
)
 
(34.8
)
 
(5.2
)
 
(16.2
)
 
(3.0
)
Actuarial Loss
4.1

 
0.7

 
1.7

 
0.2

 
4.4

 
0.8

 
1.1

 
0.4

Prior Service Cost/(Credit)
(11.6
)
 
0.5

 
(8.5
)
 
0.2

 
(11.5
)
 
0.5

 
(8.5
)
 
0.3

Total Net Periodic Benefit Expense/(Income)
$
(20.7
)
 
$
0.5

 
$
(16.3
)
 
$
(0.3
)
 
$
(22.5
)
 
$
(0.1
)
 
$
(18.2
)
 
$
(0.1
)
Intercompany Allocations
N/A

 
$
(0.4
)
 
$
(0.6
)
 
$
(0.2
)
 
N/A

 
$
(0.5
)
 
$
(0.7
)
 
$
(0.2
)


9.    COMMITMENTS AND CONTINGENCIES

A.    Environmental Matters
Eversource, CL&P, NSTAR Electric and PSNH are subject to environmental laws and regulations intended to mitigate or remove the effect of past operations and improve or maintain the quality of the environment. These laws and regulations require the removal or the remedy of the effect on the environment of the disposal or release of certain specified hazardous substances at current and former operating sites. Eversource, CL&P, NSTAR Electric and PSNH have an active environmental auditing and training program and each believes it is substantially in compliance with all enacted laws and regulations.

The number of environmental sites and related reserves for which remediation or long-term monitoring, preliminary site work or site assessment is being performed are as follows:
 
As of June 30, 2019
 
As of December 31, 2018
 
Number of Sites
 
Reserve
(in millions)
 
Number of Sites
 
Reserve
(in millions)
Eversource
58

 
$
71.6

 
60

 
$
64.7

CL&P
15

 
5.8

 
15

 
5.4

NSTAR Electric
15

 
10.5

 
16

 
10.9

PSNH
9

 
5.4

 
9

 
5.4



Included in the number of sites and reserve amounts above are former MGP sites that were operated several decades ago and manufactured gas from coal and other processes, which resulted in certain by-products remaining in the environment that may pose a potential risk to human health and the environment, for which Eversource may have potential liability.  The reserve balances related to these former MGP sites were $57.1 million and $50.1 million as of June 30, 2019 and December 31, 2018, respectively, and related primarily to the natural gas business segment.

These reserve estimates are subjective in nature as they take into consideration several different remediation options at each specific site.  The reliability and precision of these estimates can be affected by several factors, including new information concerning either the level of contamination at the site, the extent of Eversource's, CL&P's, NSTAR Electric's and PSNH's responsibility for remediation or the extent of remediation required, recently enacted laws and regulations or changes in cost estimates due to certain economic factors.  It is possible that new information or future developments could require a reassessment of the potential exposure to required environmental remediation.  As this information becomes available, management will continue to assess the potential exposure and adjust the reserves accordingly.


29


B.     Long-Term Contractual Arrangements
On December 28, 2018, under Public Act 17-3, "An Act Concerning Zero Carbon Procurement," DEEP selected the Millstone Nuclear Power Station generation facility, along with smaller generation facilities, in DEEP’s zero-carbon request for proposal. CL&P and UI were directed by DEEP to enter into ten-year contracts to purchase a combined total of approximately 9 million MWh annually from the Millstone generation facility. On March 15, 2019, CL&P and UI each signed a ten-year contract with the owner of Millstone Nuclear Power Station in order to purchase a combined amount of approximately 50 percent of the facility's output (approximately 40 percent by CL&P). The Millstone Nuclear Power Station has a 2,112 MW nameplate capacity. The parties filed the contract with PURA on March 29, 2019 for review and approval. A decision from PURA is expected in the third quarter of 2019.

The significant output of the generation facility, the contract period, and the pricing will result in a significant multi-billion dollar contractual commitment. We plan to sell the energy purchased under this contract into the market and use the proceeds from these energy sales to offset the contract costs.  As the net costs under this contract will be recovered from customers in future rates, the contract will not have an impact on the net income of CL&P.

C.    Guarantees and Indemnifications
In the normal course of business, Eversource parent provides credit assurances on behalf of its subsidiaries, including CL&P, NSTAR Electric and PSNH, in the form of guarantees.

Eversource parent issued a guaranty on behalf of its subsidiary, NPT, under which, beginning at the time the Northern Pass Transmission line would go into commercial operation, Eversource parent would guarantee the financial obligations of NPT under the TSA with HQ in an amount not to exceed $25 million.  Eversource parent's obligations under the guaranty expire upon the full, final and indefeasible payment of the guaranteed obligations. Eversource parent also entered into a guaranty on behalf of NPT under which Eversource parent would guarantee NPT's obligations under a facility with a financial institution pursuant to which NPT may request letters of credit in an aggregate amount of up to approximately $14 million. In the second quarter of 2019, Eversource concluded that construction of the NPT project was no longer probable. For further information regarding the impairment of NPT, see Note 1C, "Summary of Significant Accounting Policies - Impairment of Northern Pass Transmission," to the financial statements. While these guarantees are currently outstanding, it is expected that they will be extinguished pending the final dissolution of NPT.

Management does not anticipate a material impact to net income or cash flows as a result of these various guarantees and indemnifications.  The following table summarizes Eversource parent's exposure to guarantees and indemnifications of its subsidiaries to external parties, as of June 30, 2019:  
Company
 
Description
 
Maximum Exposure
(in millions)
 
Expiration Dates
On behalf of subsidiaries:
 
 
 
 
 
 
Eversource Investment LLC
 
North East Offshore (1)
 
$
113.9

 
-
Various
 
Surety Bonds (2)
 
34.0

 
2019 - 2021
Rocky River Realty Company and Eversource Service
 
Lease Payments for Real Estate
 
7.1

 
2024
Bay State Wind
 
Real Estate Purchase
 
2.5

 
2020

(1) 
Eversource parent issued a declining balance guaranty on behalf of its subsidiary, Eversource Investment LLC, which holds an ownership interest in North East Offshore. Eversource parent will guarantee, as a primary obligor, the financial obligations, primarily all post-closing payment obligations of Eversource Investment LLC, under the Sale and Purchase Agreement and an Irrevocable Equity Commitment Letter with Ørsted. Eversource parent's obligations under the guaranty expire upon the full, final and indefeasible payment of the guaranteed obligations.

(2) 
Surety bond expiration dates reflect termination dates, the majority of which will be renewed or extended.  Certain surety bonds contain credit ratings triggers that would require Eversource parent to post collateral in the event that the unsecured debt credit ratings of Eversource parent are downgraded.  

D.     Spent Nuclear Fuel Obligations - Yankee Companies
CL&P, NSTAR Electric and PSNH have plant closure and fuel storage cost obligations to the Yankee Companies, which have each completed the physical decommissioning of their respective nuclear facilities and are now engaged in the long-term storage of their spent fuel. The Yankee Companies fund these costs through litigation proceeds received from the DOE and, to the extent necessary, through wholesale, FERC-approved rates charged under power purchase agreements with several New England utilities, including CL&P, NSTAR Electric and PSNH. CL&P, NSTAR Electric and PSNH, in turn recover these costs from their customers through state regulatory commission-approved retail rates. The Yankee Companies collect amounts that management believes are adequate to recover the remaining plant closure and fuel storage cost estimates for the respective plants. Management believes CL&P and NSTAR Electric will recover their shares of these obligations from their customers. PSNH has recovered its total share of these costs from its customers.


30


Spent Nuclear Fuel Litigation:
The Yankee Companies have filed complaints against the DOE in the Court of Federal Claims seeking monetary damages resulting from the DOE's failure to provide for a permanent facility to store spent nuclear fuel pursuant to the terms of the 1983 spent fuel and high level waste disposal contracts between the Yankee Companies and the DOE. The court had previously awarded the Yankee Companies damages for Phase I, II and III of litigation resulting from the DOE's failure to meet its contractual obligations. These Phases covered damages incurred in the years 1998 through 2012, and the awarded damages have been received by the Yankee Companies with certain amounts of the damages refunded to their customers.

DOE Phase IV Damages - On May 22, 2017, each of the Yankee Companies filed subsequent lawsuits against the DOE in the Court of Federal
Claims. The Yankee Companies sought monetary damages totaling $104.4 million for CYAPC, YAEC and MYAPC, resulting from the DOE's failure to begin accepting spent nuclear fuel for disposal covering the years from 2013 to 2016 (“DOE Phase IV”). On February 21, 2019, the Yankee Companies received a partial summary judgment and partial final judgment in their favor for the undisputed amount of monetary damages of $103.2 million. The court awarded CYAPC, YAEC and MYAPC damages of $40.7 million, $28.1 million and $34.4 million, respectively. The DOE did not appeal the court's judgment and the decision became final on April 23, 2019. On June 12, 2019, CYAPC and YAEC received damages of $40.7 million and $28.1 million, respectively, which were recorded as restricted cash within Other Long-Term Assets on the Eversource consolidated balance sheet as of June 30, 2019.

The Yankee Companies are in the process of preparing a required informational filing with FERC as to the use of proceeds. At this time, the damages are primarily expected to be used by the Yankee Companies to fund remaining fuel storage obligations, and management does not expect significant amounts to be refunded to Eversource utilities (CL&P, NSTAR Electric and PSNH). The utilities would then ultimately refund any amounts received to utility customers.

On June 12, 2019, the court accepted an offer of judgment in the amount of $0.5 million to settle the disputed amount of approximately $1 million in Phase IV contested damages. The Yankee Companies received the $0.5 million payment in July 2019.

E.    FERC ROE Complaints
Four separate complaints have been filed at the FERC by combinations of New England state attorneys general, state regulatory commissions, consumer advocates, consumer groups, municipal parties and other parties (collectively the "Complainants"). In each of the first three complaints, filed on October 1, 2011, December 27, 2012, and July 31, 2014, respectively, the Complainants challenged the NETOs' base ROE of 11.14 percent that had been utilized since 2005 and sought an order to reduce it prospectively from the date of the final FERC order and for the separate 15-month complaint periods. In the fourth complaint, filed April 29, 2016, the Complainants challenged the NETOs' base ROE billed of 10.57 percent and the maximum ROE for transmission incentive ("incentive cap") of 11.74 percent, asserting that these ROEs were unjust and unreasonable.

The ROE originally billed during the period October 1, 2011 (beginning of the first complaint period) through October 15, 2014 consisted of a base ROE of 11.14 percent and incentives up to 13.1 percent. On October 16, 2014, the FERC set the base ROE at 10.57 percent and the incentive cap at 11.74 percent for the first complaint period. This was also effective for all prospective billings to customers beginning October 16, 2014. This FERC order was vacated on April 14, 2017 by the U.S. Court of Appeals for the D.C. Circuit (the "Court").

All amounts associated with the first complaint period have been refunded, which totaled $38.9 million (pre-tax and excluding interest) at Eversource and reflected both the base ROE and incentive cap prescribed by the FERC order. The refund consisted of $22.4 million for CL&P, $13.7 million for NSTAR Electric and $2.8 million for PSNH.

Eversource has recorded a reserve of $39.1 million (pre-tax and excluding interest) for the second complaint period as of June 30, 2019. This reserve represents the difference between the billed rates during the second complaint period and a 10.57 percent base ROE and 11.74 percent incentive cap. The reserve consisted of $21.4 million for CL&P, $14.6 million for NSTAR Electric and $3.1 million for PSNH as of June 30, 2019.

On October 16, 2018, FERC issued an order on all four complaints describing how it intends to address the issues that were remanded by the Court. FERC proposed a new framework to determine (1) whether an existing ROE is unjust and unreasonable and, if so, (2) how to calculate a replacement ROE. The parties to these proceedings were directed to submit briefs on this new proposed framework and how they would apply the proposed framework in each of the four complaint proceedings. Initial briefs were filed by the NETOs, Complainants and FERC Trial Staff on January 11, 2019 and reply briefs were filed on March 8, 2019. The NETOs' brief was supportive of the overall ROE methodology determined in the October 16, 2018 order provided the FERC does not change the proposed methodology or alter its implementation in a manner that has a material impact on the results.

The FERC order included illustrative calculations for the first complaint using FERC's proposed frameworks with financial data from that complaint. Those preliminary calculations indicated that for the first complaint period, for the NETOs that FERC concludes are of average financial risk, (1) a preliminary range of presumptively just and reasonable base ROEs is 9.60 percent to 10.99 percent; (2) the pre-existing base ROE of 11.14 percent is therefore unjust and unreasonable; (3) the preliminary just and reasonable base ROE is 10.41 percent; and (4) the preliminary incentive cap on total ROE is 13.08 percent.

If the results of these illustrative calculations were included in a final FERC order for each of the complaint periods, then a 10.41 percent base ROE and a 13.08 percent incentive cap would not have a significant impact on our financial statements for all of the complaint periods.


31


Although the order provided illustrative calculations, FERC stated that these calculations are merely preliminary. The FERC’s preliminary calculations are not binding and do not represent what we believe to be the most likely outcome of a final FERC order, as changes to the methodology by FERC are possible as a result of the parties’ arguments and calculations in the briefing process. Until FERC issues a final decision on each of these four complaints, there is significant uncertainty, and at this time, the Company cannot reasonably estimate a range of gain or loss for any of the four complaint proceedings. The October 16, 2018 FERC order or the 2019 briefs did not provide a reasonable basis for a change to the reserve or recognized ROEs for any of the complaint periods.

Eversource, CL&P, NSTAR Electric and PSNH currently record revenues at the 10.57 percent base ROE and incentive cap at 11.74 percent established in the October 16, 2014 FERC order.

The average impact of a 10 basis point change to the base ROE for each of the 15-month complaint periods would affect Eversource's after-tax earnings by approximately $3 million.

F.    Eversource and NSTAR Electric Boston Harbor Civil Action
On July 15, 2016, the United States Attorney on behalf of the United States Army Corps of Engineers filed a civil action in the United States District Court for the District of Massachusetts under provisions of the Rivers and Harbors Act of 1899 and the Clean Water Act against NSTAR Electric, HEEC, and the Massachusetts Water Resources Authority (together with NSTAR Electric and HEEC, the "Defendants").  The action alleged that the Defendants failed to comply with certain permitting requirements related to the placement of the HEEC-owned electric distribution cable beneath Boston Harbor.  The action sought an order to compel HEEC to comply with cable depth requirements in the United States Army Corps of Engineers' permit or alternatively to remove the electric distribution cable and cease unauthorized work in U.S. waterways.  The action also sought civil penalties and other costs.

The parties reached a settlement pursuant to which HEEC agreed to install a new 115kV distribution cable across Boston Harbor to Deer Island, utilizing a different route, and remove portions of the existing cable. Upon the installation and completion of the new cable and the removal of the portions of the existing cable, all issues surrounding the current permit from the United States Army Corps of Engineers are expected to be resolved, and such litigation is expected to be dismissed with prejudice.

NSTAR Electric agreed to provide a rate base credit of $17.5 million to the Massachusetts Water Resources Authority for the new cable. This negotiated credit resulted in the initial $17.5 million of construction costs on the new cable being expensed as incurred, all of which was fully expensed in 2018. Construction of the new cable is underway and is expected to be completed in 2019.

10.     LEASES

Eversource, including CL&P, NSTAR Electric and PSNH, has entered into lease agreements as a lessee for the use of land, office space, service centers, vehicles, information technology, and equipment. These lease agreements are classified as either finance or operating leases and the liability and right-of-use asset are recognized on the balance sheet at lease commencement.  Leases with an initial term of 12 months or less are not recorded on the balance sheet and are recognized as lease expense on a straight-line basis over the lease term.

Eversource determines whether or not a contract contains a lease based on whether or not it provides Eversource with the use of a specifically identified asset for a period of time, as well as both the right to direct the use of that asset and receive the significant economic benefits of the asset. Eversource has elected the practical expedient to not separate non-lease components from lease components and instead to account for both as a single lease component, with the exception of the information technology asset class where the lease and non-lease components are separated.

The provisions of Eversource, CL&P, NSTAR Electric and PSNH lease agreements contain renewal options. The renewal options range from one year to twenty years. The renewal period is included in the measurement of the lease liability if it is reasonably certain that Eversource will exercise these renewal options.

For leases entered into or modified after the January 1, 2019 implementation date, the discount rate utilized for classification and measurement purposes as of the inception date of the lease is based on each company's collateralized incremental interest rate to borrow over a comparable term for an individual lease, as the rate implicit in the lease is not determinable.

CL&P and PSNH entered into certain contracts for the purchase of energy that qualify as leases.  These contracts do not have minimum lease payments and therefore are not recognized as a lease liability on the balance sheet and are not reflected in the future minimum lease payments table below.  Expense related to these contracts are included as variable lease cost in the table below. The expense and long-term obligation for these contracts are included in the annually reported contractual obligations table in Note 12B, "Commitments and Contingencies - Long-Term Contractual Arrangements," of the Eversource 2018 Form 10-K.  

32



The components of lease cost, prior to amounts capitalized, are as follows:
 
For the Three Months Ended June 30, 2019
 
For the Six Months Ended June 30, 2019
(Millions of Dollars)
Eversource
 
CL&P
 
NSTAR Electric
 
PSNH
 
Eversource
 
CL&P
 
NSTAR Electric
 
PSNH
Financing Lease Cost:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Amortization of Right-of-use-Assets
$
0.4

 
$
0.2

 
$
—

 
$
—

 
$
0.7

 
$
0.4

 
$
0.1

 
$
—

Interest on Lease Liabilities
0.3

 
0.1

 
0.2

 
—

 
0.7

 
0.3

 
0.3

 
—

Total Finance Lease Cost
0.7

 
0.3

 
0.2

 
—

 
1.4

 
0.7

 
0.4

 
—

Operating Lease Cost
2.9

 
0.1

 
0.5

 
—

 
5.9

 
0.1

 
0.9

 
—

Variable Lease Cost
15.7

 
3.1

 
—

 
12.6

 
31.1

 
6.5

 
—

 
24.6

Total Lease Cost
$
19.3

 
$
3.5

 
$
0.7

 
$
12.6

 
$
38.4

 
$
7.3

 
$
1.3

 
$
24.6



Operating lease cost, less the capitalized portion, is included in Operations and Maintenance (or Purchased Power, Fuel and Transmission expense for transmission segment leases) on the statements of income. Amortization of finance lease assets is included in Depreciation on the statements of income. Interest expense on finance leases is included in Interest Expense, Net on the statements of income.

Supplemental balance sheet information related to leases is as follows:
 
 
 
As of June 30, 2019
(Millions of Dollars)
Balance Sheet Classification
 
Eversource
 
CL&P
 
NSTAR Electric
 
PSNH
Operating Leases:
 
 
 
 
 
 
 
 
 
Operating Lease Right-of-use-Assets, Net
Other Long-Term Assets
 
$
54.6

 
$
0.6

 
$
24.4

 
$
0.8

Operating Lease Liabilities
 
 
 
 
 
 
 
 
 
Operating Lease Liabilities - Current Portion
Other Current Liabilities
 
$
8.8

 
$
0.2

 
$
0.5

 
$
0.2

Operating Lease Liabilities - Long-Term
Other Long-Term Liabilities
 
45.8

 
0.4

 
23.9

 
0.6

Total Operating Lease Liabilities
 
 
$
54.6

 
$
0.6

 
$
24.4

 
$
0.8

Finance Leases:
 
 
 
 
 
 
 
 
 
Finance Lease Right-of-use-Assets, Net
Property, Plant and Equipment, Net
 
$
9.4

 
$
2.6

 
$
3.4

 
$
0.9

Finance Lease Liabilities
 
 
 
 
 
 
 
 
 
Finance Lease Liabilities - Current Portion
Other Current Liabilities
 
$
2.3

 
$
1.5

 
$
—

 
$
0.1

Finance Lease Liabilities - Long-Term
Other Long-Term Liabilities
 
9.3

 
2.3

 
4.4

 
0.8

Total Finance Lease Liabilities
 
 
$
11.6

 
$
3.8

 
$
4.4

 
$
0.9



The finance lease payments that NSTAR Electric will make over the next twelve months are entirely interest-related, due to escalating payments. As such, none of the finance lease payments over the next twelve months will reduce the finance lease liability.

Other information related to leases is as follows (in millions of dollars, unless otherwise noted):
 
Eversource
 
CL&P
 
NSTAR Electric
 
PSNH
As of June 30, 2019
 
 
 
 
 
 
 
Weighted-Average Remaining Lease Term (Years):
 
 
 
 
 
 
 
Operating Leases
12

 
4

 
21

 
8

Financing Leases
11

 
2

 
23

 
9

Weighted-Average Discount Rate (Percentage):
 
 
 
 
 
 
 
Operating Leases
3.9
%
 
2.7
%
 
4.1
%
 
3.6
%
Financing Leases
4.3
%
 
10.5
%
 
2.9
%
 
3.5
%
 
 
 
 
 
 
 
 
For the Three Months Ended June 30, 2019
 
 
 
 
 
 
 
Cash Paid for Amounts Included in the Measurement of Lease Liabilities:
 
 
 
 
 
 
 
Operating Cash Flows from Operating Leases
$
3.0

 
$
0.1

 
$
0.5

 
$
—

Operating Cash Flows from Finance Leases
0.3

 
0.1

 
0.1

 
—

Financing Cash Flows from Finance Leases
0.5

 
0.4

 
—

 
—

Supplemental Non-Cash Information on Lease Liabilities:
 
 
 
 
 
 
 
Right-of-use-Assets Obtained in Exchange for New Operating Lease Liabilities
0.4

 
0.2

 
—

 
0.2

Right-of-use-Assets Obtained in Exchange for New Finance Lease Liabilities
1.3

 
—

 
—

 
—



33


 
Eversource
 
CL&P
 
NSTAR Electric
 
PSNH
For the Six Months Ended June 30, 2019
 
 
 
 
 
 
 
Cash Paid for Amounts Included in the Measurement of Lease Liabilities:
 
 
 
 
 
 
 
Operating Cash Flows from Operating Leases
$
5.9

 
$
0.1

 
$
0.8

 
$
—

Operating Cash Flows from Finance Leases
0.6

 
0.3

 
0.3

 
—

Financing Cash Flows from Finance Leases
0.9

 
0.7

 
—

 
—

Supplemental Non-Cash Information on Lease Liabilities:
 
 
 
 
 
 
 
Right-of-use-Assets Obtained in Exchange for New Operating Lease Liabilities
1.7

 
0.2

 
—

 
0.2

Right-of-use-Assets Obtained in Exchange for New Finance Lease Liabilities
1.3

 
—

 
—

 
—



Future minimum lease payments, excluding variable costs, under long-term leases, as of June 30, 2019 are as follows:
 
Operating Leases
 
Finance Leases

(Millions of Dollars)
Eversource
 
CL&P
 
NSTAR Electric
 
PSNH
 
Eversource
 
CL&P
 
NSTAR Electric
 
PSNH
July 1, 2019 through December 31, 2019
$
5.7

 
$
0.3

 
$
0.8

 
$
0.2

 
$
1.7

 
$
1.0

 
$
0.3

 
$
0.1

Year Ending December 31,
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
2020
10.3

 
0.2

 
1.6

 
0.2

 
3.4

 
2.0

 
0.5

 
0.1

2021
9.2

 
0.1

 
1.6

 
0.2

 
2.9

 
1.5

 
0.5

 
0.1

2022
7.5

 
—

 
1.6

 
0.1

 
1.5

 
—

 
0.6

 
0.1

2023
4.9

 
—

 
1.6

 
0.1

 
0.7

 
—

 
0.6

 
0.1

2024
2.9

 
—

 
1.7

 
—

 
0.7

 
—

 
0.6

 
0.1

Thereafter
29.2

 
0.1

 
28.9

 
0.2

 
13.2

 
—

 
12.8

 
0.4

Future lease payments
69.7

 
0.7

 
37.8

 
1.0

 
24.1

 
4.5

 
15.9

 
1.0

Less amount representing interest
15.1

 
0.1

 
13.4

 
0.2

 
12.5

 
0.7

 
11.5

 
0.1

Present value of future minimum lease payments
$
54.6

 
$
0.6

 
$
24.4

 
$
0.8

 
$
11.6

 
$
3.8

 
$
4.4

 
$
0.9



At December 31, 2018, future minimum rental payments, excluding executory costs, such as property taxes, state use taxes, insurance, and maintenance were as follows:
Operating Leases
(Millions of Dollars)
Eversource
 
CL&P
 
NSTAR Electric
 
PSNH
2019
$
11.5

 
$
1.5

 
$
7.2

 
$
0.5

2020
9.8

 
1.4

 
6.0

 
0.4

2021
8.7

 
1.2

 
5.3

 
0.4

2022
7.2

 
1.1

 
4.4

 
0.4

2023
4.7

 
0.5

 
3.1

 
0.2

Thereafter
32.7

 
0.2

 
29.5

 
0.3

Future minimum lease payments
$
74.6

 
$
5.9

 
$
55.5

 
$
2.2


Capital Leases
(Millions of Dollars)
Eversource
 
CL&P
 
NSTAR Electric
 
PSNH
2019
$
3.4

 
$
2.0

 
$
0.5

 
$
0.1

2020
3.4

 
2.0

 
0.5

 
0.1

2021
2.9

 
1.5

 
0.5

 
0.1

2022
1.5

 
—

 
0.6

 
0.1

2023
0.7

 
—

 
0.6

 
0.1

Thereafter
13.9

 
—

 
13.4

 
0.5

Future minimum lease payments
25.8

 
5.5

 
16.1

 
1.0

Less amount representing interest
13.8

 
1.0

 
12.4

 
0.1

Present value of future minimum lease payments
$
12.0

 
$
4.5

 
$
3.7

 
$
0.9




34


11.    FAIR VALUE OF FINANCIAL INSTRUMENTS

The following methods and assumptions were used to estimate the fair value of each of the following financial instruments:

Preferred Stock, Long-Term Debt and Rate Reduction Bonds:  The fair value of CL&P's and NSTAR Electric's preferred stock is based upon pricing models that incorporate interest rates and other market factors, valuations or trades of similar securities and cash flow projections.  The fair value of long-term debt and RRB debt securities is based upon pricing models that incorporate quoted market prices for those issues or similar issues adjusted for market conditions, credit ratings of the respective companies and treasury benchmark yields.  The fair values provided in the table below are classified as Level 2 within the fair value hierarchy.  Carrying amounts and estimated fair values are as follows:
 
Eversource
 
CL&P
 
NSTAR Electric
 
PSNH
(Millions of Dollars)
Carrying
Amount
 
Fair
Value
 
Carrying
Amount
 
Fair
Value
 
Carrying
Amount
 
Fair
Value
 
Carrying
Amount
 
Fair
Value
As of June 30, 2019:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Preferred Stock Not Subject to Mandatory Redemption
$
155.6

 
$
161.0

 
$
116.2

 
$
117.4

 
$
43.0

 
$
43.6

 
$
—

 
$
—

Long-Term Debt
13,818.5

 
14,639.4

 
3,309.5

 
3,724.9

 
3,341.5

 
3,599.6

 
1,101.8

 
1,145.3

Rate Reduction Bonds
604.9

 
642.2

 
—

 
—

 
—

 
—

 
604.9

 
642.2

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
As of December 31, 2018:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Preferred Stock Not Subject to Mandatory Redemption
$
155.6

 
$
156.8

 
$
116.2

 
$
113.8

 
$
43.0

 
$
43.0

 
$
—

 
$
—

Long-Term Debt
13,086.1

 
13,154.9

 
3,254.0

 
3,429.2

 
2,944.8

 
3,024.1

 
805.2

 
819.5

Rate Reduction Bonds
635.7

 
645.8

 
—

 
—

 
—

 
—

 
635.7

 
645.8



Derivative Instruments and Marketable Securities: Derivative instruments and investments in marketable securities are carried at fair value.  For further information, see Note 4, "Derivative Instruments," and Note 5, "Marketable Securities," to the financial statements.  

See Note 1E, "Summary of Significant Accounting Policies - Fair Value Measurements," for the fair value measurement policy and the fair value hierarchy.

12.    ACCUMULATED OTHER COMPREHENSIVE INCOME/(LOSS)

The changes in accumulated other comprehensive income/(loss) by component, net of tax, are as follows:
 
For the Six Months Ended June 30, 2019
 
For the Six Months Ended June 30, 2018
Eversource 
(Millions of Dollars)
Qualified
Cash Flow
Hedging
Instruments
 
Unrealized
Gains/(Losses)
 on Marketable
Securities
 
Defined
Benefit Plans
 
Total
 
Qualified
Cash Flow
Hedging
Instruments
 
Unrealized
Losses on
Marketable
Securities
 
Defined
Benefit Plans
 
Total
Balance as of January 1st
$
(4.4
)
 
$
(0.5
)
 
$
(55.1
)
 
$
(60.0
)
 
$
(6.2
)
 
$
—

 
$
(60.2
)
 
$
(66.4
)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
OCI Before Reclassifications
—

 
1.1

 
2.6

 
3.7

 
—

 
(0.6
)
 
2.6

 
2.0

Amounts Reclassified from AOCI
0.6

 
—

 
2.1

 
2.7

 
1.2

 
—

 
2.2

 
3.4

Net OCI
0.6

 
1.1

 
4.7

 
6.4

 
1.2

 
(0.6
)
 
4.8

 
5.4

Balance as of June 30th
$
(3.8
)
 
$
0.6

 
$
(50.4
)
 
$
(53.6
)
 
$
(5.0
)
 
$
(0.6
)
 
$
(55.4
)
 
$
(61.0
)


Eversource's qualified cash flow hedging instruments represent interest rate swap agreements on debt issuances that were settled in prior years. The settlement amount was recorded in AOCI and is being amortized into Net Income over the term of the underlying debt instrument.  CL&P, NSTAR Electric and PSNH continue to amortize interest rate swaps settled in prior years from AOCI into Interest Expense over the remaining life of the associated long-term debt. Such interest rate swaps are not material to their respective financial statements.

Defined benefit plan OCI amounts before reclassifications relate to actuarial gains and losses that arose during the year and were recognized in AOCI. The unamortized actuarial gains and losses and prior service costs on the defined benefit plans are amortized from AOCI into Other Income, Net over the average future employee service period, and are reflected in amounts reclassified from AOCI.

Eversource did not elect to reclassify the income tax effects of the Tax Cuts and Jobs Act from AOCI to Retained Earnings as permitted by ASU 2018-02, Income Statement—Reporting Comprehensive Income (Topic 220).


35


13.    COMMON SHARES

The following table sets forth the Eversource parent common shares and the shares of common stock of CL&P, NSTAR Electric and PSNH that were authorized and issued, as well as the respective per share par values:  
 
Shares
 
 
 
Authorized as of June 30, 2019 and December 31, 2018
 
Issued as of
 
Par Value
 
 
June 30, 2019
 
December 31, 2018
Eversource
$
5

 
380,000,000

 
339,858,402

 
333,878,402

CL&P
$
10

 
24,500,000

 
6,035,205

 
6,035,205

NSTAR Electric
$
1

 
100,000,000

 
200

 
200

PSNH
$
1

 
100,000,000

 
301

 
301



Common Share Issuance and Forward Sale Agreement: On June 4, 2019, Eversource completed an equity offering of 17,940,000 common shares, consisting of 5,980,000 common shares issued directly by the Company and 11,960,000 common shares issuable pursuant to a forward sale agreement with an investment bank. The issuance of 5,980,000 common shares resulted in proceeds of $426.9 million, net of issuance costs, and was reflected in shareholders’ equity and as a financing activity on the statement of cash flows.

Under the forward sale agreement, a total of 11,960,000 common shares were borrowed from third parties and sold to the underwriters. The forward sale agreement allows Eversource, at its election and prior to May 29, 2020, to physically settle the forward sale agreement by issuing common shares in exchange for net proceeds at the then-applicable forward sale price specified by the agreement (initially, $71.48 per share) or, alternatively, to settle the forward sale agreement in whole or in part through the delivery or receipt of shares or cash. The forward sale price is subject to adjustment daily based on a floating interest rate factor and will decrease in respect of certain fixed amounts specified in the agreement, such as dividends.

Eversource’s intent is to physically settle the forward sale agreement by issuing common shares. As of June 30, 2019, if Eversource had elected to net settle the forward sale agreement, Eversource would have been required to pay $50.2 million under a cash settlement or would have been required to deliver 662,694 common shares under a net share settlement.

Issuances of shares under the forward sale agreement are classified as equity transactions. Accordingly, no amounts relating to the forward sale agreement have or will be recorded in the financial statements until settlements take place. Prior to any settlements, the only impact to the financial statements is the inclusion of incremental shares within the calculation of diluted EPS using the treasury stock method. See Note 15, "Earnings Per Share," for information on the forward sale agreement’s impact on the calculation of diluted EPS.

Treasury Shares: As of June 30, 2019 and December 31, 2018, there were 16,283,963 and 16,992,594 Eversource common shares held as treasury shares, respectively. As of June 30, 2019 and December 31, 2018, Eversource common shares outstanding were 323,574,439 and 316,885,808, respectively.

Beginning in 2019, Eversource began issuing treasury shares to satisfy awards under the Company's incentive plans, shares issued under the dividend reinvestment plan, and matching contributions under the Eversource 401k Plan.

14.    COMMON SHAREHOLDERS' EQUITY AND NONCONTROLLING INTERESTS

Dividends on the preferred stock of CL&P and NSTAR Electric totaled $1.9 million for each of the three months ended June 30, 2019 and 2018 and $3.8 million for each of the six months ended June 30, 2019 and 2018. These dividends were presented as Net Income Attributable to Noncontrolling Interests on the Eversource statements of income. Noncontrolling Interest – Preferred Stock of Subsidiaries on the Eversource balance sheets totaled $155.6 million as of June 30, 2019 and December 31, 2018. On the Eversource balance sheets, Common Shareholders' Equity was fully attributable to Eversource parent and Noncontrolling Interest – Preferred Stock of Subsidiaries was fully attributable to the noncontrolling interest.

15.    EARNINGS PER SHARE

Basic EPS is computed based upon the weighted average number of common shares outstanding during each period.  Diluted EPS is computed on the basis of the weighted average number of common shares outstanding plus the potential dilutive effect of certain share-based compensation awards and the equity forward sale agreement, as if they were converted into outstanding common shares.  The dilutive effect of unvested RSU and performance share awards, as well as the equity forward sale agreement, is calculated using the treasury stock method.  RSU and performance share awards are included in basic weighted average common shares outstanding as of the date that all necessary vesting conditions have been satisfied.  

36



As described in Note 13, "Common Shares," earnings per share dilution, if any, related to the forward sale agreement will be determined under the treasury stock method until settlement of the forward sale agreement. Under this method, the number of Eversource common shares used in calculating diluted EPS is deemed to be increased by the excess, if any, of the number of shares that would be issued upon physical settlement of the forward sale agreement less the number of shares that would be purchased by Eversource in the market (based on the average market price during the same reporting period) using the proceeds receivable upon settlement (based on the adjusted forward sale price at the end of that reporting period). Share dilution occurs when the average market price of Eversource's common shares is higher than the adjusted forward sale price.

The following table sets forth the components of basic and diluted EPS:
Eversource
(Millions of Dollars, except share information)
For the Three Months Ended
 
For the Six Months Ended
June 30, 2019
 
June 30, 2018
 
June 30, 2019
 
June 30, 2018
Net Income Attributable to Common Shareholders
$
31.5

 
$
242.8

 
$
340.1

 
$
512.3

Weighted Average Common Shares Outstanding:
 
 
 
 
 
 
 
Basic
319,664,998

 
317,344,596

 
318,644,796

 
317,370,825

Dilutive Effect of:
 
 
 
 
 
 
 
Share-Based Compensation Awards and Other
645,450

 
540,591

 
668,470

 
568,269

Equity Forward Sale Agreement
78,042

 
—

 
39,021

 
—

Total Dilutive Effect
723,492

 
540,591

 
707,491

 
568,269

Diluted
320,388,490

 
317,885,187

 
319,352,287

 
317,939,094

Basic and Diluted EPS
$
0.10

 
$
0.76

 
$
1.07

 
$
1.61



16.    REVENUES

The following tables present operating revenues disaggregated by revenue source:
 
For the Three Months Ended June 30, 2019
Eversource
(Millions of Dollars)
Electric
Distribution
 
Natural Gas
Distribution
 
Electric
Transmission
 
Water Distribution
 
Other
 
Eliminations
 
Total
Revenues from Contracts with Customers
 
 
 
 
 
 
 
 
 
 
 
 
 
Retail Tariff Sales
 
 
 
 
 
 
 
 
 
 
 
 
 
Residential
$
805.0

 
$
100.2

 
$
—

 
$
33.6

 
$
—

 
$
—

 
$
938.8

Commercial
612.8

 
69.5

 
—

 
16.0

 
—

 
(0.9
)
 
697.4

Industrial
81.3

 
23.5

 
—

 
1.1

 
—

 
(2.8
)
 
103.1

Total Retail Tariff Sales Revenues
1,499.1


193.2

 
—

 
50.7


—

 
(3.7
)
 
1,739.3

Wholesale Transmission Revenues
—

 
—

 
281.2

 
—

 
14.7

 
(239.8
)
 
56.1

Wholesale Market Sales Revenues
39.4

 
14.4

 
—

 
0.9

 
—

 
—

 
54.7

Other Revenues from Contracts with Customers
15.1

 
0.4

 
3.7

 
1.8

 
236.1

 
(236.8
)
 
20.3

Reserve for Revenues Subject to Refund
(3.1
)
 
1.5

 
—

 
(0.6
)
 
—

 
—

 
(2.2
)
Total Revenues from Contracts with Customers
1,550.5


209.5

 
284.9

 
52.8


250.8

 
(480.3
)
 
1,868.2

Alternative Revenue Programs
6.3

 
(2.7
)
 
64.6

 
0.7

 
—

 
(58.8
)
 
10.1

Other Revenues (1)
5.0

 
0.9

 
0.1

 
0.2

 
—

 
—

 
6.2

Total Operating Revenues
$
1,561.8


$
207.7

 
$
349.6

 
$
53.7


$
250.8

 
$
(539.1
)
 
$
1,884.5

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
For the Six Months Ended June 30, 2019
Eversource
(Millions of Dollars)
Electric
Distribution
 
Natural Gas
Distribution
 
Electric
Transmission
 
Water Distribution
 
Other
 
Eliminations
 
Total
Revenues from Contracts with Customers
 
 
 
 
 
 
 
 
 
 
 
 
 
Retail Tariff Sales
 
 
 
 
 
 
 
 
 
 
 
 
 
Residential
$
1,838.3

 
$
359.1

 
$
—

 
$
60.5

 
$
—

 
$
—

 
$
2,257.9

Commercial
1,265.3

 
213.3

 
—

 
30.3

 
—

 
(2.0
)
 
1,506.9

Industrial
163.4

 
54.4

 
—

 
2.2

 
—

 
(5.5
)
 
214.5

Total Retail Tariff Sales Revenues
3,267.0

 
626.8

 
—

 
93.0

 
—

 
(7.5
)
 
3,979.3

Wholesale Transmission Revenues
—

 
—

 
606.1

 
—

 
28.3

 
(510.7
)
 
123.7

Wholesale Market Sales Revenues
90.8

 
36.1

 
—

 
1.9

 
—

 
—

 
128.8

Other Revenues from Contracts with Customers
27.7

 
1.4

 
6.9

 
3.5

 
480.7

 
(482.2
)
 
38.0

Reserve for Revenues Subject to Refund
(6.1
)
 
3.1

 
—

 
(1.2
)
 
—

 
—

 
(4.2
)
Total Revenues from Contracts with Customers
3,379.4

 
667.4

 
613.0

 
97.2

 
509.0

 
(1,000.4
)
 
4,265.6

Alternative Revenue Programs
8.4

 
7.7

 
77.0

 
1.5

 
—

 
(69.8
)
 
24.8

Other Revenues (1)
7.8

 
1.5

 
0.1

 
0.5

 
—

 
—

 
9.9

Total Operating Revenues
$
3,395.6

 
$
676.6

 
$
690.1

 
$
99.2

 
$
509.0

 
$
(1,070.2
)
 
$
4,300.3



37


 
For the Three Months Ended June 30, 2018
Eversource
(Millions of Dollars)
Electric
Distribution
 
Natural Gas
Distribution
 
Electric
Transmission
 
Water Distribution
 
Other
 
Eliminations
 
Total
Revenues from Contracts with Customers
 
 
 
 
 
 
 
 
 
 
 
 
 
Retail Tariff Sales
 
 
 
 
 
 
 
 
 
 
 
 
 
Residential
$
794.4

 
$
104.1

 
$
—

 
$
32.3

 
$
—

 
$
—

 
$
930.8

Commercial
622.0

 
70.0

 
—

 
15.7

 
—

 
(2.0
)
 
705.7

Industrial
88.4

 
23.5

 
—

 
1.1

 
—

 
(2.4
)
 
110.6

Total Retail Tariff Sales Revenues
1,504.8

 
197.6

 
—

 
49.1

 
—

 
(4.4
)
 
1,747.1

Wholesale Transmission Revenues
—

 
—

 
310.8

 
—

 
12.6

 
(268.0
)
 
55.4

Wholesale Market Sales Revenues
34.2

 
12.1

 
—

 
0.9

 
—

 
—

 
47.2

Other Revenues from Contracts with Customers
18.4

 
(0.6
)
 
3.2

 
1.9

 
224.4

 
(225.1
)
 
22.2

Reserve for Revenues Subject to Refund
(7.3
)
 
(3.5
)
 
—

 
(0.5
)
 
—

 
—

 
(11.3
)
Total Revenues from Contracts with Customers
1,550.1

 
205.6

 
314.0

 
51.4

 
237.0

 
(497.5
)
 
1,860.6

Alternative Revenue Programs
(14.4
)
 
0.1

 
3.4

 
1.9

 
—

 
(2.9
)
 
(11.9
)
Other Revenues
4.2

 
0.8

 
—

 
0.2

 
—

 
—

 
5.2

Total Operating Revenues
$
1,539.9

 
$
206.5

 
$
317.4

 
$
53.5

 
$
237.0

 
$
(500.4
)
 
$
1,853.9

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
For the Six Months Ended June 30, 2018
Eversource
(Millions of Dollars)
Electric
Distribution
 
Natural Gas
Distribution
 
Electric
Transmission
 
Water Distribution
 
Other
 
Eliminations
 
Total
Revenues from Contracts with Customers
 
 
 
 
 
 
 
 
 
 
 
 
 
Retail Tariff Sales
 
 
 
 
 
 
 
 
 
 
 
 
 
Residential
$
1,788.7

 
$
352.9

 
$
—

 
$
59.7

 
$
—

 
$
—

 
$
2,201.3

Commercial
1,233.4

 
204.7

 
—

 
30.0

 
—

 
(2.1
)
 
1,466.0

Industrial
169.9

 
53.1

 
—

 
2.1

 
—

 
(5.0
)
 
220.1

Total Retail Tariff Sales Revenues
3,192.0

 
610.7

 
—

 
91.8

 
—

 
(7.1
)
 
3,887.4

Wholesale Transmission Revenues
—

 
—

 
624.5

 
—

 
22.7

 
(526.7
)
 
120.5

Wholesale Market Sales Revenues
92.7

 
29.9

 
—

 
1.7

 
—

 
—

 
124.3

Other Revenues from Contracts with Customers
35.3

 
(0.9
)
 
6.2

 
3.7

 
445.2

 
(446.3
)
 
43.2

Reserve for Revenues Subject to Refund
(26.5
)
 
(8.0
)
 
—

 
(2.0
)
 
—

 
—

 
(36.5
)
Total Revenues from Contracts with Customers
3,293.5

 
631.7

 
630.7

 
95.2

 
467.9

 
(980.1
)
 
4,138.9

Alternative Revenue Programs
(5.7
)
 
(1.7
)
 
(8.3
)
 
2.6

 
—

 
7.7

 
(5.4
)
Other Revenues
6.7

 
1.4

 
—

 
0.2

 
—

 
—

 
8.3

Total Operating Revenues
$
3,294.5

 
$
631.4

 
$
622.4

 
$
98.0

 
$
467.9

 
$
(972.4
)
 
$
4,141.8


38


 
For the Three Months Ended June 30, 2019
 
For the Three Months Ended June 30, 2018
(Millions of Dollars)
CL&P
 
NSTAR Electric
 
PSNH
 
CL&P
 
NSTAR Electric
 
PSNH
Revenues from Contracts with Customers
 
 
 
 
 
 
 
 
 
 
 
Retail Tariff Sales
 
 
 
 
 
 
 
 
 
 
 
Residential
$
402.8

 
$
282.3

 
$
119.9

 
$
387.1

 
$
292.5

 
$
114.8

Commercial
224.7

 
315.8

 
72.7

 
220.7

 
325.5

 
76.2

Industrial
33.8

 
28.9

 
18.6

 
36.5

 
30.9

 
21.0

Total Retail Tariff Sales Revenues
661.3

 
627.0

 
211.2

 
644.3

 
648.9

 
212.0

Wholesale Transmission Revenues
115.9

 
127.5

 
37.8

 
139.9

 
120.9

 
50.1

Wholesale Market Sales Revenues
12.1

 
17.2

 
10.1

 
10.6

 
13.4

 
10.9

Other Revenues from Contracts with Customers
9.1

 
6.1

 
4.2

 
8.3

 
9.3

 
3.9

Reserve for Revenues Subject to Refund
—

 
—

 
(3.1
)
 
(4.2
)
 
—

 
(3.1
)
Total Revenues from Contracts with Customers
798.4

 
777.8

 
260.2

 
798.9

 
792.5

 
273.8

Alternative Revenue Programs
55.1

 
2.1

 
13.7

 
1.0

 
(6.9
)
 
(5.0
)
Other Revenues (1)
2.7

 
1.9

 
0.5

 
2.4

 
1.6

 
0.2

Eliminations
(115.4
)
 
(99.9
)
 
(33.5
)
 
(107.4
)
 
(96.5
)
 
(33.9
)
Total Operating Revenues
$
740.8

 
$
681.9

 
$
240.9

 
$
694.9

 
$
690.7

 
$
235.1

 
 
 
 
 
 
 
 
 
 
 
 
 
For the Six Months Ended June 30, 2019
 
For the Six Months Ended June 30, 2018
(Millions of Dollars)
CL&P
 
NSTAR Electric
 
PSNH
 
CL&P
 
NSTAR Electric
 
PSNH
Revenues from Contracts with Customers
 
 
 
 
 
 
 
 
 
 
 
Retail Tariff Sales
 
 
 
 
 
 
 
 
 
 
 
Residential
$
913.4

 
$
653.2

 
$
271.7

 
$
870.4

 
$
656.7

 
$
261.6

Commercial
461.3

 
652.3

 
152.6

 
443.2

 
640.0

 
151.1

Industrial
68.4

 
57.8

 
37.2

 
72.3

 
59.0

 
38.6

Total Retail Tariff Sales Revenues
1,443.1

 
1,363.3

 
461.5

 
1,385.9

 
1,355.7

 
451.3

Wholesale Transmission Revenues
270.7

 
250.1

 
85.3

 
290.6

 
239.5

 
94.3

Wholesale Market Sales Revenues
25.8

 
41.6

 
23.4

 
21.0

 
38.2

 
34.9

Other Revenues from Contracts with Customers
18.0

 
10.1

 
7.8

 
16.2

 
18.3

 
7.5

Reserve for Revenues Subject to Refund
—

 
—

 
(6.1
)
 
(16.6
)
 
(3.7
)
 
(6.2
)
Total Revenues from Contracts with Customers
1,757.6

 
1,665.1

 
571.9

 
1,697.1

 
1,648.0

 
581.8

Alternative Revenue Programs
60.9

 
9.3

 
15.2

 
(4.1
)
 
(0.2
)
 
(9.6
)
Other Revenues (1)
3.7

 
3.4

 
0.8

 
3.3

 
2.7

 
0.6

Eliminations
(232.1
)
 
(198.3
)
 
(70.6
)
 
(216.4
)
 
(189.6
)
 
(70.3
)
Total Operating Revenues
$
1,590.1

 
$
1,479.5

 
$
517.3

 
$
1,479.9

 
$
1,460.9

 
$
502.5


(1)  
Other Revenues include certain fees charged to customers, which are not considered revenue from contracts with customers. Other revenues also includes lease revenues under lessor accounting guidance of $1.1 million at Eversource, $0.3 million at CL&P, and $0.7 million at NSTAR Electric for the three months ended June 30, 2019, and $2.2 million at Eversource, $0.5 million at CL&P, and $1.3 million at NSTAR Electric for the six months ended June 30, 2019, respectively.

17.    SEGMENT INFORMATION

Eversource is organized into the Electric Distribution, Electric Transmission, Natural Gas Distribution and Water Distribution reportable segments and Other based on a combination of factors, including the characteristics of each segments' services, the sources of operating revenues and expenses and the regulatory environment in which each segment operates.  These reportable segments represent substantially all of Eversource's total consolidated revenues.  Revenues from the sale of electricity, natural gas and water primarily are derived from residential, commercial and industrial customers and are not dependent on any single customer.  The Electric Distribution reportable segment includes the results of PSNH's generation facilities prior to sales in January and August 2018, and NSTAR Electric's solar power facilities. Eversource's reportable segments are determined based upon the level at which Eversource's chief operating decision maker assesses performance and makes decisions about the allocation of company resources.
 

39


The remainder of Eversource's operations is presented as Other in the tables below and primarily consists of 1) the equity in earnings of Eversource parent from its subsidiaries and intercompany interest income, both of which are eliminated in consolidation, and interest expense related to the debt of Eversource parent, 2) the revenues and expenses of Eversource Service, most of which are eliminated in consolidation, 3) the operations of CYAPC and YAEC, 4) Eversource Water Ventures, Inc., parent company of Aquarion, and 5) the results of other unregulated subsidiaries, which are not part of its core business. In addition, Other in the tables below includes Eversource parent's equity ownership interests that are not consolidated, which include a natural gas pipeline project owned by Enbridge, Inc., the offshore wind business, a renewable energy investment fund, and two companies that transmit hydroelectricity imported from the Hydro-Quebec system in Canada. In the ordinary course of business, Yankee Gas and NSTAR Gas purchase natural gas transmission services from the Enbridge, Inc. natural gas pipeline project described above. These affiliate transaction costs total approximately $62.5 million annually and are classified as Purchased Power, Fuel and Transmission on the Eversource statements of income.

Each of Eversource's subsidiaries, including CL&P, NSTAR Electric and PSNH, has one reportable segment.

Cash flows used for investments in plant included in the segment information below are cash capital expenditures that do not include amounts incurred but not paid, cost of removal, AFUDC related to equity funds, and the capitalized portions of pension and PBOP expense.   

Eversource's segment information is as follows:
 
For the Three Months Ended June 30, 2019
Eversource
(Millions of Dollars)
Electric
Distribution
 
Natural Gas
Distribution
 
Electric
Transmission
 
Water Distribution
 
Other
 
Eliminations
 
Total
Operating Revenues
$
1,561.8

 
$
207.7

 
$
349.6

 
$
53.7

 
$
250.8

 
$
(539.1
)
 
$
1,884.5

Depreciation and Amortization
(150.1
)
 
(19.5
)
 
(62.3
)
 
(12.0
)
 
(14.7
)
 
0.6

 
(258.0
)
Impairment of Northern Pass Transmission
—

 
—

 
(239.6
)
 
—

 
—

 
—

 
(239.6
)
Other Operating Expenses
(1,243.0
)
 
(179.8
)
 
(108.4
)
 
(25.0
)
 
(218.4
)
 
538.7

 
(1,235.9
)
Operating Income/(Loss)
$
168.7

 
$
8.4

 
$
(60.7
)
 
$
16.7

 
$
17.7

 
$
0.2

 
$
151.0

Interest Expense
$
(50.8
)
 
$
(11.9
)
 
$
(30.5
)
 
$
(8.6
)
 
$
(44.5
)
 
$
13.6

 
$
(132.7
)
Other Income/(Loss), Net
12.2

 
0.7

 
8.7

 
0.1

 
(114.9
)
 
139.1

 
45.9

Net Income/(Loss) Attributable to Common Shareholders
105.4

 
(1.8
)
 
(87.4
)
 
8.0

 
(145.6
)
 
152.9

 
31.5

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
For the Six Months Ended June 30, 2019
Eversource
(Millions of Dollars)
Electric Distribution
 
Natural Gas Distribution
 
Electric Transmission
 
Water Distribution
 
Other
 
Eliminations
 
Total
Operating Revenues
$
3,395.6

 
$
676.6

 
$
690.1

 
$
99.2

 
$
509.0

 
$
(1,070.2
)
 
$
4,300.3

Depreciation and Amortization
(329.3
)
 
(39.9
)
 
(123.7
)
 
(23.9
)
 
(28.3
)
 
1.1

 
(544.0
)
Impairment of Northern Pass Transmission
—

 
—

 
(239.6
)
 
—

 
—

 
—

 
(239.6
)
Other Operating Expenses
(2,718.6
)
 
(521.1
)
 
(207.2
)
 
(49.9
)
 
(444.0
)
 
1,069.8

 
(2,871.0
)
Operating Income
$
347.7

 
$
115.6

 
$
119.6

 
$
25.4

 
$
36.7

 
$
0.7

 
$
645.7

Interest Expense
$
(100.0
)
 
$
(23.7
)
 
$
(61.0
)
 
$
(17.2
)
 
$
(88.6
)
 
$
26.1

 
$
(264.4
)
Other Income, Net
30.4

 
1.0

 
16.8

 
0.4

 
316.8

 
(288.5
)
 
76.9

Net Income Attributable to Common Shareholders
225.4

 
74.7

 
30.9

 
8.8

 
262.0

 
(261.7
)
 
340.1

Cash Flows Used for Investments in Plant
571.3

 
202.7

 
449.2

 
51.4

 
103.2

 
—

 
1,377.8


40


 
For the Three Months Ended June 30, 2018
Eversource
(Millions of Dollars)
Electric
Distribution
 
Natural Gas
Distribution
 
Electric
Transmission
 
Water Distribution
 
Other
 
Eliminations
 
Total
Operating Revenues
$
1,539.9

 
$
206.5

 
$
317.4

 
$
53.5

 
$
237.0

 
$
(500.4
)
 
$
1,853.9

Depreciation and Amortization
(135.5
)
 
(19.3
)
 
(57.0
)
 
(12.2
)
 
(11.9
)
 
0.6

 
(235.3
)
Other Operating Expenses
(1,233.0
)
 
(170.6
)
 
(88.8
)
 
(24.5
)
 
(211.7
)
 
501.4

 
(1,227.2
)
Operating Income
$
171.4

 
$
16.6

 
$
171.6

 
$
16.8

 
$
13.4

 
$
1.6

 
$
391.4

Interest Expense
$
(52.1
)
 
$
(11.4
)
 
$
(30.0
)
 
$
(8.6
)
 
$
(32.3
)
 
$
8.0

 
$
(126.4
)
Other Income/(Loss), Net
19.0

 
1.6

 
9.9

 
(0.6
)
 
302.0

 
(281.8
)
 
50.1

Net Income Attributable to Common Shareholders
101.3

 
5.0

 
112.7

 
7.2

 
288.8

 
(272.2
)
 
242.8

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
For the Six Months Ended June 30, 2018
Eversource
(Millions of Dollars)
Electric
Distribution
 
Natural Gas
Distribution
 
Electric
Transmission
 
Water Distribution
 
Other
 
Eliminations
 
Total
Operating Revenues
$
3,294.5

 
$
631.4

 
$
622.4

 
$
98.0

 
$
467.9

 
$
(972.4
)
 
$
4,141.8

Depreciation and Amortization
(279.9
)
 
(45.7
)
 
(113.5
)
 
(22.9
)
 
(23.9
)
 
1.1

 
(484.8
)
Other Operating Expenses
(2,676.5
)
 
(483.2
)
 
(172.0
)
 
(48.4
)
 
(416.3
)
 
973.3

 
(2,823.1
)
Operating Income
$
338.1

 
$
102.5

 
$
336.9

 
$
26.7

 
$
27.7

 
$
2.0

 
$
833.9

Interest Expense
$
(99.5
)
 
$
(22.5
)
 
$
(59.7
)
 
$
(16.9
)
 
$
(64.3
)
 
$
15.4

 
$
(247.5
)
Other Income/(Loss), Net
38.6

 
3.5

 
17.8

 
(1.1
)
 
662.1

 
(637.0
)
 
83.9

Net Income Attributable to Common Shareholders
205.5

 
62.8

 
220.1

 
8.7

 
634.8

 
(619.6
)
 
512.3

Cash Flows Used for Investments in Plant
475.6

 
150.3

 
508.5

 
40.2

 
77.1

 
—

 
1,251.7


The following table summarizes Eversource's segmented total assets:
Eversource
(Millions of Dollars)
Electric
Distribution
 
Natural Gas
Distribution
 
Electric
Transmission
 
Water Distribution
 
Other
 
Eliminations
 
Total
As of June 30, 2019
$
21,628.8

 
$
4,031.3

 
$
10,499.7

 
$
2,290.5

 
$
18,550.4

 
$
(18,004.8
)
 
$
38,995.9

As of December 31, 2018
21,389.1

 
3,904.9

 
10,285.0

 
2,253.0

 
17,874.2

 
(17,464.9
)
 
38,241.3


For further information regarding the 2019 impairment of NPT, see Note 1C, "Summary of Significant Accounting Policies - Impairment of Northern Pass Transmission," to the financial statements.


41


EVERSOURCE ENERGY AND SUBSIDIARIES

Management's Discussion and Analysis of Financial Condition and Results of Operations

The following discussion and analysis should be read in conjunction with our unaudited condensed consolidated financial statements and related combined notes included in this combined Quarterly Report on Form 10-Q, the combined Quarterly Report on Form 10-Q for the quarter ended March 31, 2019, as well as the Eversource 2018 Form 10-K.  References in this combined Quarterly Report on Form 10-Q to "Eversource," the "Company," "we," "us," and "our" refer to Eversource Energy and its consolidated subsidiaries.  All per-share amounts are reported on a diluted basis.  The unaudited condensed consolidated financial statements of Eversource, NSTAR Electric and PSNH and the unaudited condensed financial statements of CL&P are herein collectively referred to as the "financial statements."  

Refer to the Glossary of Terms included in this combined Quarterly Report on Form 10-Q for abbreviations and acronyms used throughout this Management's Discussion and Analysis of Financial Condition and Results of Operations.  

The only common equity securities that are publicly traded are common shares of Eversource.  The earnings and EPS of each business discussed below do not represent a direct legal interest in the assets and liabilities of such business but rather represent a direct interest in our assets and liabilities as a whole.  EPS by business is a financial measure not recognized under GAAP calculated by dividing the Net Income Attributable to Common Shareholders of each business by the weighted average diluted Eversource common shares outstanding for the period.  Our earnings discussion also includes a non-GAAP financial measure referencing our 2019 earnings and EPS excluding the impairment charge for the NPT project.

We use these non-GAAP financial measures to evaluate and provide details of earnings results by business and to more fully compare and explain our 2019 results without including the impact of the NPT impairment charge. We believe the NPT impairment charge is not indicative of our ongoing performance.  Due to the nature and significance of the impairment charge on Net Income Attributable to Common Shareholders, we believe that the non-GAAP presentation is a more meaningful representation of our financial performance and provides additional and useful information to readers of this report in analyzing historical and future performance of our business. These non-GAAP financial measures should not be considered as an alternative to reported Net Income Attributable to Common Shareholders or EPS determined in accordance with GAAP as an indicator of operating performance.

From time to time, we make statements concerning our expectations, beliefs, plans, objectives, goals, strategies, assumptions of future events, future financial performance or growth and other statements that are not historical facts.  These statements are "forward-looking statements" within the meaning of the Private Securities Litigation Reform Act of 1995.  You can generally identify our forward-looking statements through the use of words or phrases such as "estimate," "expect," "anticipate," "intend," "plan," "project," "believe," "forecast," "should," "could," and other similar expressions.  Forward-looking statements are based on the current expectations, estimates, assumptions or projections of management and are not guarantees of future performance.  These expectations, estimates, assumptions or projections may vary materially from actual results.  Accordingly, any such statements are qualified in their entirety by reference to, and are accompanied by, the following important factors that could cause our actual results to differ materially from those contained in our forward-looking statements, including, but not limited to:

•
cyberattacks or breaches, including those resulting in the compromise of the confidentiality of our proprietary information and the personal information of our customers,
•
acts of war or terrorism, physical attacks or grid disturbances that may damage and disrupt our transmission and distribution systems,
•
ability or inability to commence and complete our major strategic development projects and opportunities,
•
actions or inaction of local, state and federal regulatory, public policy and taxing bodies,
•
substandard performance of third-party suppliers and service providers,
•
fluctuations in weather patterns, including extreme weather due to climate change,
•
changes in business conditions, which could include disruptive technology related to our current or future business model,
•
increased conservation measures of customers and development of alternative energy sources,
•
contamination of, or disruption in, our water supplies,
•
changes in economic conditions, including impact on interest rates, tax policies, and customer demand and payment ability,
•
changes in levels or timing of capital expenditures,
•
disruptions in the capital markets or other events that make our access to necessary capital more difficult or costly,
•
changes in laws, regulations or regulatory policy, including compliance with environmental laws and regulations,
•
changes in accounting standards and financial reporting regulations,
•
actions of rating agencies, and
•
other presently unknown or unforeseen factors.  

Other risk factors are detailed in our reports filed with the SEC and updated as necessary, and we encourage you to consult such disclosures.

All such factors are difficult to predict and contain uncertainties that may materially affect our actual results, many of which are beyond our control.  You should not place undue reliance on the forward-looking statements, as each speaks only as of the date on which such statement is made, and, except as required by federal securities laws, we undertake no obligation to update any forward-looking statement or statements to reflect events or circumstances after the date on which such statement is made or to reflect the occurrence of unanticipated events.  New factors emerge from time to time and it is not possible for us to predict all of such factors, nor can we assess the impact of each such factor on the business or the extent to which any factor, or combination of factors, may cause actual results to differ materially from those contained in any forward-looking statements. For more information, see Item 1A, Risk Factors, included in this combined Quarterly Report on Form 10-Q and in Eversource's 2018 combined Annual Report on Form 10-K.  This combined Quarterly Report on Form 10-Q and Eversource's 2018 combined

42


Annual Report on Form 10-K also describe material contingencies and critical accounting policies in the accompanying Management's Discussion and Analysis of Financial Condition and Results of Operations and Combined Notes to Financial Statements.  We encourage you to review these items.

Financial Condition and Business Analysis

Executive Summary

The following items in this executive summary are explained in more detail in this combined Quarterly Report on Form 10-Q:

Earnings Overview and Future Outlook: 

•
We earned $31.5 million, or $0.10 per share, in the second quarter of 2019, and $340.1 million, or $1.07 per share, in the first half of 2019, compared with $242.8 million, or $0.76 per share, in the second quarter of 2018, and $512.3 million, or $1.61 per share, in the first half of 2018.  Results for the second quarter and first half of 2019 include an after-tax impairment charge of $204.4 million, or $0.64 per share, related to our investment in the NPT project. Excluding that impairment charge, we earned $235.9 million, or $0.74 per share, in the second quarter of 2019, and $544.5 million, or $1.71 per share, in the first half of 2019.

•
Our electric distribution segment earned $105.4 million, or $0.33 per share, in the second quarter of 2019, and $225.4 million, or $0.71 per share, in the first half of 2019, compared with $101.3 million, or $0.32 per share, in the second quarter of 2018, and $205.5 million, or $0.65 per share, in the first half of 2018.  Our natural gas distribution segment had a net loss of $(1.8) million in the second quarter of 2019, and earnings of $74.7 million, or $0.23 per share, in the first half of 2019, compared with earnings of $5.0 million, or $0.02 per share, in the second quarter of 2018, and $62.8 million, or $0.20 per share, in the first half of 2018.  Our water distribution segment earned $8.0 million, or $0.02 per share, in the second quarter of 2019, and $8.8 million, or $0.03 per share, in the first half of 2019, compared with $7.2 million, or $0.02 per share, in the second quarter of 2018, and $8.7 million, or $0.03 per share, in the first half of 2018.

•
Our electric transmission segment had a net loss of $(87.4) million, or $(0.27) per share, in the second quarter of 2019, and earnings of $30.9 million, or $0.10 per share, in the first half of 2019, compared with earnings of $112.7 million, or $0.35 per share, in the second quarter of 2018, and $220.1 million, or $0.69 per share, in the first half of 2018.  Excluding the after-tax NPT impairment charge of $204.4 million, or $0.64 per share, our electric transmission segment earned $117.0 million, or $0.37 per share, in the second quarter of 2019, and $235.3 million, or $0.74 per share, in the first half of 2019.

•
Eversource parent and other companies earned $7.3 million, or $0.02 per share, in the second quarter of 2019, and $0.3 million in the first half of 2019, compared with $16.6 million, or $0.05 per share, in the second quarter of 2018, and $15.2 million, or $0.04 per share, in the first half of 2018.  

•
Excluding the NPT impairment charge, we continue to project non-GAAP 2019 earnings of between $3.40 per share and $3.50 per share.

Liquidity:

•
Cash flows provided by operating activities totaled $924.6 million in the first half of 2019, compared with $698.1 million in the first half of 2018. Investments in property, plant and equipment totaled $1.38 billion in the first half of 2019, compared with $1.25 billion in the first half of 2018.  Cash totaled $20.6 million as of June 30, 2019, compared with $108.1 million as of December 31, 2018.

•
On June 4, 2019, we completed an equity offering of 17,940,000 common shares, consisting of 5,980,000 common shares issued directly by us and 11,960,000 common shares issuable pursuant to a forward sale agreement with an investment bank. The issuance of 5,980,000 common shares resulted in proceeds of $426.9 million, net of issuance costs, and was reflected in shareholders’ equity and as a financing activity on the statement of cash flows.

•
In the second quarter of 2019, we issued $1.0 billion of new long-term debt, consisting of $300 million by CL&P, $400 million by NSTAR Electric and $300 million by PSNH. Proceeds from these new issuances were used primarily to repay short-term borrowings and to repay long-term debt at maturity.

•
On May 1, 2019, our Board of Trustees approved a common share dividend payment of $0.535 per share, which was paid on June 28, 2019 to shareholders of record as of May 23, 2019.

Strategic:

•
On July 19, 2019, the New Hampshire Supreme Court issued a decision denying Northern Pass’ appeal and affirming the NHSEC’s evaluation and decision in March 2018 that denied Northern Pass’ siting application. As a result of the New Hampshire Supreme Court decision, Eversource concluded that construction of the project was no longer probable and that substantially all of the capitalized project costs, which totaled $318 million, certain of which are subject to cost reimbursement agreements, were impaired. Eversource recorded a pre-tax impairment charge of $239.6 million (after-tax charge of $204.4 million, or $0.64 per share) for the three and six months ended June 30, 2019, which was reflected in the Electric Transmission segment.

43



•
On July 18, 2019, NYSERDA announced that Sunrise Wind, a joint project between Eversource and Ørsted, was selected to negotiate a 25-year power purchase agreement for an 880 MW offshore wind facility. Sunrise Wind will be developed 30 miles east of Montauk Point, Long Island. Subject to contract signing and Eversource’s and Ørsted's final investment decisions, the project is expected to be operational in 2024.

Earnings Overview

Consolidated:  Below is a summary of our earnings by business, which also reconciles the non-GAAP financial measures of consolidated non-GAAP earnings and EPS, as well as EPS by business, to the most directly comparable GAAP measures of consolidated Net Income Attributable to Common Shareholders and diluted EPS.
 
For the Three Months Ended June 30,
 
For the Six Months Ended June 30,
 
2019
 
2018
 
2019
 
2018
(Millions of Dollars, Except Per Share Amounts)
Amount
 
Per Share
 
Amount
 
Per Share
 
Amount
 
Per Share
 
Amount
 
Per Share
Net Income Attributable to Common
  Shareholders (GAAP)
$
31.5

 
$
0.10

 
$
242.8

 
$
0.76

 
$
340.1

 
$
1.07

 
$
512.3

 
$
1.61

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Regulated Companies
$
228.6

 
$
0.72

 
$
226.2

 
$
0.71

 
$
544.2

 
$
1.71

 
$
497.1

 
$
1.57

Eversource Parent and Other Companies
7.3

 
0.02

 
16.6

 
0.05

 
0.3

 
—

 
15.2

 
0.04

Non-GAAP Earnings
$
235.9

 
$
0.74

 
$
242.8

 
$
0.76

 
$
544.5

 
$
1.71

 
$
512.3

 
$
1.61

Impairment of Northern Pass Transmission
  (after-tax)
(204.4
)
 
(0.64
)
 
—

 
—

 
(204.4
)
 
(0.64
)
 
—

 
—

Net Income Attributable to Common
  Shareholders (GAAP)
$
31.5

 
$
0.10

 
$
242.8


$
0.76

 
$
340.1

 
$
1.07

 
$
512.3

 
$
1.61


Regulated Companies:  Our regulated companies comprise the electric distribution, electric transmission, natural gas distribution and water distribution segments. A summary of our segment earnings and EPS is as follows: 
 
For the Three Months Ended June 30,
 
For the Six Months Ended June 30,
 
2019
 
2018
 
2019
 
2018
(Millions of Dollars, Except Per Share Amounts)
Amount
 
Per Share
 
Amount
 
Per Share
 
Amount
 
Per Share
 
Amount
 
Per Share
Net Income - Regulated Companies (GAAP)
$
24.2

 
$
0.08

 
$
226.2

 
$
0.71

 
$
339.8

 
$
1.07

 
$
497.1

 
$
1.57

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Electric Distribution
$
105.4

 
$
0.33

 
$
101.3

 
$
0.32

 
$
225.4

 
$
0.71

 
$
205.5

 
$
0.65

Electric Transmission, excluding Northern Pass Transmission impairment (Non-GAAP)
117.0

 
0.37

 
112.7

 
0.35

 
235.3

 
0.74

 
220.1

 
0.69

Natural Gas Distribution
(1.8
)
 
—

 
5.0

 
0.02

 
74.7

 
0.23

 
62.8

 
0.20

Water Distribution
8.0

 
0.02

 
7.2

 
0.02

 
8.8

 
0.03

 
8.7

 
0.03

Net Income - Regulated Companies (Non-GAAP)
$
228.6

 
$
0.72

 
$
226.2

 
$
0.71

 
$
544.2

 
$
1.71

 
$
497.1

 
$
1.57

Impairment of Northern Pass Transmission
  (after-tax)
(204.4
)
 
(0.64
)
 
—

 
—

 
(204.4
)
 
(0.64
)
 
—

 
—

Net Income - Regulated Companies (GAAP)
$
24.2

 
$
0.08

 
$
226.2

 
$
0.71

 
$
339.8

 
$
1.07

 
$
497.1

 
$
1.57


Our electric distribution segment earnings increased $4.1 million in the second quarter of 2019, as compared to the second quarter of 2018, due primarily to CL&P base distribution rate increases effective May 1, 2019 and May 1, 2018, an NSTAR Electric base distribution rate increase effective January 1, 2019, and higher earnings from CL&P's capital tracker mechanism effective July 1, 2018 due to increased electric system improvements, partially offset by higher operations and maintenance expense, higher depreciation expense, lower non-service income from our benefit plans and the absence in 2019 of generation earnings at PSNH due to the sale of its generation assets in 2018.

Our electric distribution segment earnings increased $19.9 million in the first half of 2019, as compared to the first half of 2018, due primarily to CL&P and NSTAR Electric base distribution rate increases, higher earnings from CL&P's capital tracker mechanism effective July 1, 2018 due to increased electric system improvements, and the recognition in the first quarter of 2019 of carrying charges on PSNH storm costs approved for recovery. The earnings increase was partially offset by higher depreciation expense, higher operations and maintenance expense, lower non-service income from our benefit plans, and the absence in 2019 of generation earnings at PSNH due to the sale of its generation assets in 2018.

Our electric transmission segment earnings decreased $200.1 million and $189.2 million in the second quarter and first half of 2019, respectively, as compared to the second quarter and first half of 2018, due primarily to the impairment of NPT, which resulted in an after-tax charge of $204.4 million, or $0.64 per share. Excluding the NPT impairment charge, earnings increased $4.3 million and $15.2 million in the second quarter and first half of 2019, respectively, as compared to the second quarter and first half of 2018, due primarily to a higher transmission rate base as a result of our continued investment in our transmission infrastructure, partially offset by a lower benefit from the annual billing and cost reconciliation filing with FERC. For further information on the impairment of NPT, see "Business Development and Capital Expenditures - Electric Transmission Business - Northern Pass" in this Management's Discussion and Analysis of Financial Condition and Results of Operations.
 

44


Our natural gas distribution segment earnings decreased $6.8 million in the second quarter of 2019, as compared to the second quarter of 2018, due primarily to higher operations and maintenance expense, lower revenues due to the seasonality of the decoupled rate structure arising from the Yankee Gas base distribution rate case, which provides lower earnings in non-heating months, and higher depreciation and property tax expense. 

Our natural gas distribution segment earnings increased $11.9 million in the first half of 2019, as compared to the first half of 2018, due primarily to the impact of the Yankee Gas base distribution rate increase effective November 15, 2018 and higher earnings from capital tracker mechanisms due to continued investment in infrastructure. Yankee Gas' decoupled rate structure is seasonally structured and provides greater earnings in the winter heating months. The earnings increase was partially offset by higher operations and maintenance expense, higher property and other taxes expense, and higher depreciation expense.

Our water distribution segment earnings increased $0.8 million and $0.1 million in the second quarter and first half of 2019, respectively, as compared to the second quarter and first half of 2018. Our water distribution business is seasonal, with lower earnings occurring during the winter months and higher earnings occurring during the summer months.

Eversource Parent and Other Companies:  Eversource parent and other companies had earnings of $7.3 million in the second quarter of 2019 and $0.3 million in the first half of 2019, compared with $16.6 million in the second quarter of 2018 and $15.2 million in the first half of 2018.  The decrease in earnings in both periods was due primarily to the absence in 2019 of an income tax benefit associated with our investments in the second quarter of 2018, higher interest expense, and a higher effective tax rate, partially offset by higher return at Eversource Service as a result of increased investments in property, plant and equipment.

Electric, Natural Gas and Water Sales Volumes:  Weather, fluctuations in energy supply costs, conservation measures (including utility-sponsored energy efficiency programs), and economic conditions affect customer energy usage and water consumption.  Industrial sales volumes are less sensitive to temperature variations than residential and commercial sales volumes.  In our service territories, weather impacts both electric and water sales volumes during the summer and both electric and natural gas sales volumes during the winter; however, natural gas sales volumes are more sensitive to temperature variations than electric sales volumes.  Customer heating or cooling usage may not directly correlate with historical levels or with the level of degree-days that occur.

Fluctuations in retail electric sales volumes at PSNH impact earnings ("Traditional" in the table below).  For CL&P, NSTAR Electric, Yankee Gas, and NSTAR Gas, fluctuations in retail sales volumes do not impact earnings due to their respective regulatory commission-approved distribution revenue decoupling mechanisms ("Decoupled" in the table below).  These distribution revenues are decoupled from their customer sales volumes, which breaks the relationship between sales volumes and revenues recognized.  Fluctuations in water sales volumes largely do not impact earnings as our Connecticut water distribution business is also decoupled.

A summary of our retail electric GWh sales volumes, our firm natural gas MMcf sales volumes, and our water MG sales volumes, and percentage changes, is as follows:  
 
Electric
 
Firm Natural Gas
 
Water
 
Sales Volumes (GWh)
 
Percentage
Decrease
 
Sales Volumes (MMcf)
 
Percentage
Increase/
(Decrease)
 
Sales Volumes (MG)
 
Percentage
Decrease
Three Months Ended June 30:
2019
 
2018 (1)
 
 
2019
 
2018 (2)
 
 
2019
 
2018
 
Traditional
1,757

 
1,803

 
(2.6
)%
 
—

 
—

 
—
 %
 
459

 
485

 
(5.4
)%
Decoupled and Special Contracts (3)
9,853

 
10,330

 
(4.6
)%
 
18,191

 
18,932

 
(3.9
)%
 
4,834

 
5,016

 
(3.6
)%
Total Sales Volumes
11,610

 
12,133

 
(4.3
)%
 
18,191

 
18,932

 
(3.9
)%
 
5,293

 
5,501

 
(3.8
)%
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Six Months Ended June 30:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Traditional
3,724

 
3,775

 
(1.4
)%
 
—

 
—

 
—
 %
 
910

 
953

 
(4.5
)%
Decoupled and Special Contracts (3)
21,037

 
21,579

 
(2.5
)%
 
63,358

 
61,983

 
2.2
 %
 
9,212

 
9,373

 
(1.7
)%
Total Sales Volumes
24,761

 
25,354

 
(2.3
)%
 
63,358

 
61,983

 
2.2
 %
 
10,122

 
10,326

 
(2.0
)%

(1)    Effective February 1, 2018, NSTAR Electric operated entirely under a decoupled rate structure. The 2018 sales volumes for NSTAR Electric have been recast to present January 2018 as decoupled to conform to the current year presentation.

(2)    Effective November 15, 2018, Yankee Gas operated under a decoupled rate structure. The 2018 sales volumes for Yankee Gas have been recast to present 2018 as decoupled to conform to the current year presentation.
 
(3)    Special contracts are unique to Yankee Gas natural gas distribution customers who take service under such an arrangement and generally specify the amount of distribution revenue to be paid to Yankee Gas regardless of the customers' usage.


45


Liquidity

Cash totaled $20.6 million as of June 30, 2019, compared with $108.1 million as of December 31, 2018.

Short-Term Debt - Commercial Paper Programs and Credit Agreements: Eversource parent has a $1.45 billion commercial paper program allowing Eversource parent to issue commercial paper as a form of short-term debt.  Eversource parent, CL&P, PSNH, NSTAR Gas and Yankee Gas are also parties to a five-year $1.45 billion revolving credit facility, which terminates on December 8, 2023. The revolving credit facility serves to backstop Eversource parent's $1.45 billion commercial paper program.  

NSTAR Electric has a $650 million commercial paper program allowing NSTAR Electric to issue commercial paper as a form of short-term debt. NSTAR Electric is also a party to a five-year $650 million revolving credit facility, which terminates on December 8, 2023. The revolving credit facility serves to backstop NSTAR Electric's $650 million commercial paper program.  

The amount of borrowings outstanding and available under the commercial paper programs were as follows:
 
Borrowings Outstanding as of
 
Available Borrowing Capacity as of
 
Weighted-Average Interest Rate as of
 
June 30, 2019
 
December 31, 2018
 
June 30, 2019
 
December 31, 2018
 
June 30, 2019
 
December 31, 2018
(Millions of Dollars)
 
 
 
 
 
Eversource Parent Commercial Paper Program
$
566.0

 
$
631.5

 
$
884.0

 
$
818.5

 
2.55
%
 
2.77
%
NSTAR Electric Commercial Paper Program
163.0

 
278.5

 
487.0

 
371.5

 
2.42
%
 
2.50
%

There were no borrowings outstanding on either the Eversource parent or NSTAR Electric revolving credit facilities as of June 30, 2019 or December 31, 2018. Eversource's water distribution segment has a $100 million revolving credit facility, which expires on August 19, 2019, and there were no borrowings outstanding as of June 30, 2019 or December 31, 2018.

Amounts outstanding under the commercial paper programs and revolving credit facility are included in Notes Payable and are classified in current liabilities on the Eversource and NSTAR Electric balance sheets as all borrowings are outstanding for no more than 364 days at one time.

Intercompany Borrowings: Eversource parent uses its available capital resources to provide loans to its subsidiaries to assist them in meeting their short-term borrowing needs. In addition, growth in Eversource's key business initiatives requires cash infusion to those subsidiaries. Eversource parent records intercompany interest income from its loans to subsidiaries, which is eliminated in consolidation. Intercompany loans from Eversource parent to its subsidiaries are eliminated in consolidation on Eversource's balance sheets. As of June 30, 2019, there were intercompany loans from Eversource parent to CL&P of $259.4 million, to PSNH of $20.1 million, and to Harbor Electric Energy Company, a wholly-owned subsidiary of NSTAR Electric ("HEEC"), of $40.3 million. As of December 31, 2018, there were intercompany loans from Eversource parent to PSNH of $57.0 million. Intercompany loans from Eversource parent are included in Notes Payable to Eversource Parent and are classified in current liabilities on the respective subsidiary's balance sheets.

Long-Term Debt: The following table summarizes long-term debt issuances and repayments:
(Millions of Dollars)
Issue Date
 
Issuance/(Repayment)
 
Maturity Date
 
Use of Proceeds for Issuance/
Repayment Information
CL&P:
 
 
 
 
 
 
 
4.00% 2018 Series A First Mortgage Bonds (1)
April 2019
 
$
300.0

 
April 2048
 
Repaid short-term borrowings that were used to repay long-term debt that matured on February 1, 2019 and fund capital expenditures and working capital
5.50% 2009 Series A First Mortgage Bonds
February 2009
 
(250.0
)
 
February 2019
 
Repaid at maturity on February 1, 2019
NSTAR Electric:
 
 
 
 
 
 
 
3.25% 2019 Debentures
May 2019
 
400.0

 
May 2029
 
Repaid short-term borrowings that were used to fund investments in eligible green expenditures
PSNH:
 
 
 
 
 
 
 
3.60% 2019 Series T First Mortgage Bonds
June 2019
 
300.0

 
July 2049
 
Repay long-term debt due to mature in December 2019, repaid short-term borrowings and fund capital expenditures and working capital
Other:
 
 
 
 
 
 
 
NSTAR Gas 3.74% Series Q First Mortgage Bonds
July 2019
 
75.0

 
August 2049
 
Repaid short-term borrowings and fund capital expenditures and working capital

(1) 
These bonds are part of the same series issued by CL&P in March 2018. The aggregate outstanding principal amount of these bonds is now $800 million.

As a result of the NSTAR Gas debt issuance in July 2019, $75 million of current portion of long-term debt was reclassified to Long-Term Debt on Eversource's consolidated balance sheet as of June 30, 2019.


46


Rate Reduction Bonds: PSNH's RRB payments consist of principal and interest and are paid semi-annually, beginning on February 1, 2019. PSNH paid $30.7 million of RRB principal payments and $16.2 million of interest payments in the first half of 2019.

Common Share Issuance and Forward Sale Agreement: On June 4, 2019, Eversource completed an equity offering of 17,940,000 common shares, consisting of 5,980,000 common shares issued directly by us and 11,960,000 common shares issuable pursuant to a forward sale agreement with an investment bank. The issuance of 5,980,000 common shares resulted in proceeds of $426.9 million, net of issuance costs, and was reflected in shareholders’ equity and as a financing activity on the statement of cash flows.

Under the forward sale agreement, a total of 11,960,000 common shares were borrowed from third parties and sold to the underwriters. The forward sale agreement allows Eversource, at its election and prior to May 29, 2020, to physically settle the forward sale agreement by issuing common shares in exchange for net proceeds at the then-applicable forward sale price specified by the agreement (initially, $71.48 per share) or, alternatively, to settle the forward sale agreement in whole or in part through the delivery or receipt of shares or cash. The forward sale price is subject to adjustment daily based on a floating interest rate factor and will decrease in respect of certain fixed amounts specified in the agreement, such as dividends.

Eversource’s intent is to physically settle the forward sale agreement by issuing common shares. As of June 30, 2019, if Eversource had elected to net settle the forward sale agreement, Eversource would have been required to pay $50.2 million under a cash settlement or would have been required to deliver 662,694 common shares under a net share settlement.

Issuances of shares under the forward sale agreement are classified as equity transactions. Accordingly, no amounts relating to the forward sale agreement have or will be recorded in the financial statements until settlements take place. Prior to any settlements, the only impact to the financial statements is the inclusion of incremental shares within the calculation of diluted EPS using the treasury stock method. See Note 15, "Earnings Per Share," for information on the forward sale agreement’s impact on the calculation of diluted EPS.

Eversource intends to use the net proceeds received upon the direct issuance of common shares and the net proceeds expected to be received upon settlement of the forward sale agreement to repay short-term debt under the commercial paper program, to fund capital spending to enhance reliability and fund clean energy initiatives, and for general corporate purposes.

Cash Flows:  Cash flows provided by operating activities totaled $924.6 million in the first half of 2019, compared with $698.1 million in the first half of 2018. The increase in operating cash flows was due primarily to a $172.4 million decrease in pension and PBOP cash contributions made in the first half of 2019 compared to the first half of 2018, approximately $172 million of storm restoration cost payments made in the first half of 2018, and the timing of cash collections on our accounts receivable. Also contributing to the increase were lower income tax payments made in the first half of 2019 of $59.2 million and $68.8 million in DOE Phase IV proceeds received by CYAPC and YAEC in the second quarter of 2019. Partially offsetting these favorable impacts were the timing of collections for regulatory tracking mechanisms, and the timing of accounts payable cash payments and other working capital items.

On May 1, 2019, our Board of Trustees approved a common share dividend payment of $0.535 per share, which was paid on June 28, 2019 to shareholders of record as of May 23, 2019. In the first half of 2019, we paid cash dividends of $323.3 million, compared with $320.1 million paid in the first half of 2018.

In the first half of 2019, CL&P, NSTAR Electric and PSNH paid $275.4 million, $181.8 million, and $233.0 million, respectively, in common stock dividends to Eversource parent.

Beginning in 2019, Eversource began issuing treasury shares to satisfy awards under the Company's incentive plans, shares issued under the dividend reinvestment plan, and matching contributions under the Eversource 401k Plan.

Investments in Property, Plant and Equipment on the statements of cash flows do not include amounts incurred on capital projects but not yet paid, cost of removal, AFUDC related to equity funds, and the capitalized and deferred portions of pension and PBOP expense.  In the first half of 2019, investments for Eversource, CL&P, NSTAR Electric, and PSNH were $1.38 billion, $466.1 million, $418.6 million, and $132.8 million, respectively.

We expect the future operating cash flows of Eversource, CL&P, NSTAR Electric and PSNH, along with our existing borrowing availability and access to both debt and equity markets, will be sufficient to meet any working capital and future operating requirements, and capital investment forecasted opportunities.


47


Credit Ratings:  On June 5, 2019, Moody’s raised the credit ratings of NSTAR Electric from A2 positive to A1 stable. On July 25, 2019, S&P downgraded the ratings on Eversource and all of it's subsidiaries and revised the outlooks from negative to stable.

A summary of our corporate credit ratings and outlooks by Moody's, S&P and Fitch is as follows:
 
Moody's
 
S&P
 
Fitch
 
Current
 
Outlook
 
Current
 
Outlook
 
Current
 
Outlook
Eversource Parent
Baa1
 
Stable
 
A-
 
Stable
 
BBB+
 
Stable
CL&P
A3
 
Stable
 
A
 
Stable
 
A- 
 
Stable
NSTAR Electric
A1
 
Stable
 
A
 
Stable
 
A  
 
Stable
PSNH
A3
 
Stable
 
A
 
Stable
 
A-
 
Stable

A summary of the current credit ratings and outlooks by Moody's, S&P and Fitch for senior unsecured debt of Eversource parent and NSTAR Electric, and senior secured debt of CL&P and PSNH is as follows:
 
Moody's
 
S&P
 
Fitch
 
Current
 
Outlook
 
Current
 
Outlook
 
Current
 
Outlook
Eversource Parent
Baa1
 
Stable
 
BBB+
 
Stable
 
BBB+ 
 
Stable
CL&P
A1
 
Stable
 
A+
 
Stable
 
A+
 
Stable
NSTAR Electric
A1
 
Stable
 
A
 
Stable
 
A+
 
Stable
PSNH
A1
 
Stable
 
A+
 
Stable
 
A+ 
 
Stable

Business Development and Capital Expenditures

Our consolidated capital expenditures, including amounts incurred but not paid, cost of removal, AFUDC, and the capitalized and deferred portions of pension and PBOP expense (all of which are non-cash factors), totaled $1.41 billion in the first half of 2019, compared to $1.18 billion in the first half of 2018.  These amounts included $97.6 million and $69.8 million in the first half of 2019 and 2018, respectively, related to information technology and facilities upgrades and enhancements, primarily at Eversource Service and The Rocky River Realty Company.

Electric Transmission Business:  Our consolidated electric transmission business capital expenditures decreased by $30.8 million in the first half of 2019, as compared to the first half of 2018.  A summary of electric transmission capital expenditures by company is as follows:  
 
For the Six Months Ended June 30,
(Millions of Dollars)
2019
 
2018
CL&P
$
220.6

 
$
240.4

NSTAR Electric
166.4

 
138.6

PSNH
59.6

 
88.7

NPT
9.7

 
19.4

Total Electric Transmission Segment
$
456.3

 
$
487.1


Northern Pass:  Northern Pass is Eversource's planned 1,090 MW HVDC transmission line that would interconnect from the Québec-New Hampshire border to Franklin, New Hampshire and an associated alternating current radial transmission line between Franklin and Deerfield, New Hampshire. 

On March 30, 2018, the New Hampshire Site Evaluation Committee (“NHSEC”), one of the state regulatory agencies from which Northern Pass was required to obtain a siting permit, issued a written decision denying Northern Pass’ siting application. In the first quarter of 2018, Eversource conducted an impairment review of the Northern Pass project and concluded, at that time, that the recorded amount of project costs was recoverable. On July 12, 2018, the NHSEC issued a written decision denying Northern Pass’ April 2018 motion for rehearing, and on October 12, 2018, the New Hampshire Supreme Court accepted an appeal filed by Northern Pass that alleged that the NHSEC failed to follow applicable law in its review of the project. On July 19, 2019, the New Hampshire Supreme Court issued a decision denying Northern Pass’ appeal and affirming the NHSEC’s evaluation and decision that denied Northern Pass’ siting application.

Eversource evaluated the impact of the New Hampshire Supreme Court decision on the probability of construction and operation of Northern Pass. Eversource concluded that construction of the project was no longer probable and that substantially all of the capitalized project costs, which totaled $318 million, certain of which are subject to cost reimbursement agreements, were impaired. Eversource concluded that the New Hampshire Supreme Court decision is a subsequent event that required recognition in the financial statements as of and for the three and six months ended June 30, 2019.


48


Based on the conclusion that the construction of Northern Pass was not probable, Eversource recorded an impairment charge for all of the project costs associated with Northern Pass, which were primarily engineering design, siting, permitting and legal costs, along with appropriate allowances for funds used during construction, and recognized a receivable for certain cost reimbursement agreements. Additionally, Eversource recorded an impairment charge associated with the land acquired to construct Northern Pass in order to recognize the land at its estimated fair value based on assessed values and transaction costs. In total, this resulted in a pre-tax impairment charge of $239.6 million within Operating Income on the statement of income for the three and six months ended June 30, 2019, and was reflected in the Electric Transmission segment. The after-tax impact of the impairment charge was $204.4 million, or $0.64 per share, after giving effect to the estimated fair value of the related land, reimbursement agreements, and the impact of expected income tax benefits associated with the impairment charge. Eversource does not expect any significant estimated future cash expenditures associated with this impairment charge.

Greater Boston Reliability Solution: The Greater Boston and New Hampshire Solution consists of a portfolio of electric transmission upgrades in southern New Hampshire and northern Massachusetts and continuing into the greater Boston metropolitan area, of which 28 upgrades are in Eversource's service territory (two in New Hampshire and 26 in Massachusetts). The two New Hampshire upgrades, including the Merrimack Valley Reliability Project, have been placed in service and 17 Massachusetts upgrades have been placed in service. Seven upgrades are under construction and one upgrade is expected to enter construction in the fourth quarter of 2019. We anticipate approval from the Massachusetts Energy Facilities Siting Board on the remaining project in 2019. Most upgrades are expected to be completed by the end of 2019.  Four projects are expected to be in service by the end of 2020 and another project by mid-2021. We estimate our portion of the investment in the Solution will be approximately $560 million, of which $396.7 million has been spent and capitalized through June 30, 2019.

GHCC:  The Greater Hartford Central Connecticut ("GHCC") projects, which have been approved by ISO-NE, consist of 27 projects with an expected investment of approximately $350 million. As of June 30, 2019, 24 projects have been placed in service, and three projects are in active construction and are expected to be placed in service through 2019. As of June 30, 2019, CL&P had spent and capitalized $253.1 million in costs associated with GHCC.

Seacoast Reliability Project:  The Seacoast Reliability Project consists of a 13-mile, 115kV transmission line within several New Hampshire communities, using a combination of overhead, underground and underwater line designs to help meet the growing demand for electricity in the Seacoast region. On December 10, 2018, the NHSEC indicated its unanimous approval of the project, and subsequently issued its written decision on January 31, 2019. On April 11, 2019, the NHSEC issued its written decision denying motions for rehearing submitted by three entities that intervened in the proceeding. On May 13, 2019, two appeals of the NHSEC's approval orders were filed with the New Hampshire Supreme Court. The court has not yet determined whether it will hear those appeals. On July 3, 2019, the U.S. Army Corps of Engineers issued its permit allowing construction in wetlands to proceed. This project is scheduled to be completed by the end of 2019.  We estimate the investment in this project to be approximately $84 million, of which PSNH had spent and capitalized $38.5 million in costs through June 30, 2019.

Distribution Business:  A summary of distribution capital expenditures is as follows:
 
For the Six Months Ended June 30,
(Millions of Dollars)
 CL&P
 
 NSTAR Electric
 
 PSNH
 
 Total Electric
 
 Natural Gas
 
Water
 
 Total
2019
 
 
 
 
 
 
 
 
 
 
 
 
 
Basic Business
$
142.9

 
$
142.4

 
$
19.1

 
$
304.4

 
$
29.4

 
$
5.6

 
$
339.4

Aging Infrastructure
96.0

 
96.6

 
52.7

 
245.3

 
125.8

 
42.9

 
414.0

Load Growth and Other
32.0

 
28.6

 
7.1

 
67.7

 
26.3

 
0.9

 
94.9

Total Distribution
270.9

 
267.6

 
78.9

 
617.4

 
181.5

 
49.4

 
848.3

Solar
—

 
4.8

 
—

 
4.8

 
—

 
—

 
4.8

Total
$
270.9

 
$
272.4

 
$
78.9

 
$
622.2

 
$
181.5

 
$
49.4

 
$
853.1

2018
 
 
 
 
 
 
 
 
 
 
 
 
 
Basic Business
$
87.2

 
$
92.6

 
$
37.5

 
$
217.3

 
$
29.0

 
$
7.5

 
$
253.8

Aging Infrastructure
54.2

 
45.3

 
41.0

 
140.5

 
87.6

 
27.8

 
255.9

Load Growth and Other
34.9

 
14.1

 
5.9

 
54.9

 
19.1

 
1.1

 
75.1

Total Distribution
176.3

 
152.0

 
84.4

 
412.7

 
135.7

 
36.4

 
584.8

Solar and Generation
—

 
38.5

 
0.8

 
39.3

 
—

 
—

 
39.3

Total
$
176.3

 
$
190.5

 
$
85.2

 
$
452.0

 
$
135.7

 
$
36.4

 
$
624.1


For the electric distribution business, basic business includes the purchase of meters, tools, vehicles, information technology, transformer replacements, equipment facilities, and the relocation of plant.  Aging infrastructure relates to reliability and the replacement of overhead lines, plant substations, underground cable replacement, and equipment failures.  Load growth and other includes requests for new business and capacity additions on distribution lines and substation additions and expansions.

For the natural gas distribution business, basic business addresses daily operational needs including meters, pipe relocations due to public works projects, vehicles, and tools.  Aging infrastructure projects seek to improve the reliability of the system through enhancements related to cast iron and bare steel replacement of main and services, corrosion mediation, and station upgrades.  Load growth and other reflects growth in existing service territories including new developments, installation of services, and expansion.


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For the water distribution business, basic business addresses daily operational needs including periodic meter replacement, water main relocation, facility maintenance, and tools. Aging infrastructure relates to reliability and the replacement of water mains, regulators, storage tanks, pumping stations, wellfields, reservoirs, and treatment facilities. Load growth and other reflects growth in our service territory, including improvements to acquisitions, installation of new services, and interconnections of systems.

Offshore Wind Business: Our offshore wind business includes ownership interests in North East Offshore and Bay State Wind, which collectively hold power purchase agreements for the Revolution Wind and South Fork Wind projects and are in process of negotiating a power purchase agreement for the Sunrise Wind project. Our offshore wind projects are being developed in partnership with Ørsted. This business also participates in opportunities for future solicitations for offshore wind in the Northeast U.S.

On February 8, 2019, Eversource and Ørsted entered into a 50-50 partnership for key offshore wind assets in the Northeast. Eversource's initial payment and contribution under the terms of the partnership agreements totaled approximately $225 million for a 50 percent interest in North East Offshore, which holds the Revolution Wind and South Fork Wind power projects, as well as a 257 square-mile lease off the coasts of Massachusetts and Rhode Island. Eversource also has a 50 percent ownership in Bay State Wind, which holds the Sunrise Wind power project. Bay State Wind is located approximately 25 miles south of the coast of Massachusetts on a separate 300-square-mile ocean lease adjacent to the North East Offshore area and has the ultimate potential to generate at least 2,000 MW of clean, renewable energy. Together, the Bay State Wind and the North East Offshore lease sites jointly-owned by Eversource and Ørsted could eventually develop at least 4,000 MW of offshore wind generation. As of June 30, 2019, Eversource's total equity investment balance in its offshore wind business was $499.5 million. In July 2019, Eversource made an additional capital contribution of $54.9 million.

Revolution Wind and South Fork Wind Projects: Revolution Wind is a 704 MW offshore wind power project that will deliver power to Rhode Island (400 MW) and Connecticut (304 MW). The Revolution Wind project was selected under separate respective Connecticut and Rhode Island competitive RFPs based on each state's clean energy requirements. In Connecticut, two 20-year power purchase agreements for a total of 200 MW were executed and have been approved by the PURA, and two 20-year power purchase agreements for a total of 104 MW were executed and are currently awaiting regulatory approval. In Rhode Island, a 20-year power purchase agreement for 400 MW was executed and has been approved by the Rhode Island Public Utilities Commission.

South Fork Wind is a 130 MW offshore wind power project that will interconnect into eastern Long Island where it will deliver power to the Long Island Power Authority. The South Fork Wind project was selected by the Long Island Power Authority, and a 20-year power purchase agreement for 90 MW was executed. Subsequently, the Long Island Power Authority agreed to expand the original power purchase agreement to 130 MW through an amendment to the original agreement. Negotiations are currently underway to finalize this amendment.

South Fork Wind is expected to be commissioned by the end of 2022, and Revolution Wind is expected to be commissioned in 2023. The completion dates are subject to permitting, engineering, siting and finalizing power purchase agreements, where applicable.

Sunrise Wind Project: On February 14, 2019, Eversource and Ørsted submitted joint proposals under the project name Sunrise Wind in response to a New York State Energy Research and Development Authority ("NYSERDA") RFP that was issued in November 2018. NYSERDA had the authority to award more than 800 MW in the first solicitation if sufficient attractive offers were received. On July 18, 2019, NYSERDA announced that Sunrise Wind was selected to negotiate a 25-year power purchase agreement for an 880 MW offshore wind facility. Sunrise Wind will be developed 30 miles east of Montauk Point, Long Island. Subject to contract signing and Eversource’s and Ørsted's final investment decisions, the project is expected to be operational in 2024.

Future Solicitations for OffShore Wind: Eversource and Ørsted are considering participation in the following opportunities for future solicitations for offshore wind based on each state's clean energy requirements:

•
Massachusetts’ second offshore wind RFP for 400 MW to 800 MW was issued on May 23, 2019. Bids are due in August 2019 and contracts are expected to be awarded to selected bidders by the end of 2019. Eversource and Ørsted are evaluating participation in the RFP.

•
Connecticut’s offshore wind RFP for 400 MW (and up to 2,000 MW) is expected to be issued in August 2019, with bids due in September 2019 and contracts awarded to selected bidders by the end of 2019. Eversource and Ørsted are evaluating participation in the RFP.

FERC Regulatory Matters

FERC ROE Complaints: Four separate complaints have been filed at the FERC by combinations of New England state attorneys general, state regulatory commissions, consumer advocates, consumer groups, municipal parties and other parties (collectively the "Complainants"). In each of the first three complaints, filed on October 1, 2011, December 27, 2012, and July 31, 2014, respectively, the Complainants challenged the NETOs' base ROE of 11.14 percent that had been utilized since 2005 and sought an order to reduce it prospectively from the date of the final FERC order and for the separate 15-month complaint periods. In the fourth complaint, filed April 29, 2016, the Complainants challenged the NETOs' base ROE billed of 10.57 percent and the maximum ROE for transmission incentive ("incentive cap") of 11.74 percent, asserting that these ROEs were unjust and unreasonable.

The ROE originally billed during the period October 1, 2011 (beginning of the first complaint period) through October 15, 2014 consisted of a base ROE of 11.14 percent and incentives up to 13.1 percent. On October 16, 2014, the FERC set the base ROE at 10.57 percent and the incentive cap at 11.74 percent for the first complaint period. This was also effective for all prospective billings to customers beginning October 16, 2014. This FERC order was vacated on April 14, 2017 by the U.S. Court of Appeals for the D.C. Circuit (the "Court").

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All amounts associated with the first complaint period have been refunded. Eversource has recorded a reserve of $39.1 million (pre-tax and excluding interest) for the second complaint period as of June 30, 2019. This reserve represents the difference between the billed rates during the second complaint period and a 10.57 percent base ROE and 11.74 percent incentive cap. The reserve consisted of $21.4 million for CL&P, $14.6 million for NSTAR Electric and $3.1 million for PSNH as of June 30, 2019.

On October 16, 2018, FERC issued an order on all four complaints describing how it intends to address the issues that were remanded by the Court. FERC proposed a new framework to determine (1) whether an existing ROE is unjust and unreasonable and, if so, (2) how to calculate a replacement ROE. The parties to these proceedings were directed to submit briefs on this new proposed framework and how they would apply the proposed framework in each of the four complaint proceedings. Initial briefs were filed by the NETOs, Complainants and FERC Trial Staff on January 11, 2019 and reply briefs were filed on March 8, 2019. The NETOs' brief was supportive of the overall ROE methodology determined in the October 16, 2018 order provided the FERC does not change the proposed methodology or alter its implementation in a manner that has a material impact on the results.

The FERC order included illustrative calculations for the first complaint using FERC's proposed frameworks with financial data from that complaint. Those preliminary calculations indicated that for the first complaint period, for the NETOs that FERC concludes are of average financial risk, (1) a preliminary range of presumptively just and reasonable base ROEs is 9.60 percent to 10.99 percent; (2) the pre-existing base ROE of 11.14 percent is therefore unjust and unreasonable; (3) the preliminary just and reasonable base ROE is 10.41 percent; and (4) the preliminary incentive cap on total ROE is 13.08 percent.

If the results of these illustrative calculations were included in a final FERC order for each of the complaint periods, then a 10.41 percent base ROE and a 13.08 percent incentive cap would not have a significant impact on our financial statements for all of the complaint periods.

Although the order provided illustrative calculations, FERC stated that these calculations are merely preliminary. The FERC’s preliminary calculations are not binding and do not represent what we believe to be the most likely outcome of a final FERC order, as changes to the methodology by FERC are possible as a result of the parties’ arguments and calculations in the briefing process. Until FERC issues a final decision on each of these four complaints, there is significant uncertainty, and at this time, the Company cannot reasonably estimate a range of gain or loss for any of the four complaint proceedings. The October 16, 2018 FERC order or the 2019 briefs did not provide a reasonable basis for a change to the reserve or recognized ROEs for any of the complaint periods.

Eversource, CL&P, NSTAR Electric and PSNH currently record revenues at the 10.57 percent base ROE and incentive cap at 11.74 percent established in the October 16, 2014 FERC order.

The average impact of a 10 basis point change to the base ROE for each of the 15-month complaint periods would affect Eversource's after-tax earnings by approximately $3 million.

FERC Notices of Inquiry: On March 21, 2019, FERC issued two Notices of Inquiry ("NOI") that may affect Eversource transmission ROEs and incentives. One NOI (the "FERC ROE NOI") seeks comments from all stakeholders on FERC's policies for evaluating ROEs for electric public utilities, and interstate natural gas and oil pipelines. The other NOI (the "FERC transmission incentives NOI") seeks comments on FERC's policies for implementing electric transmission incentives. On June 26, 2019, the NETOs jointly filed comments in the FERC ROE NOI, supporting the methodology established in the FERC’s October 16, 2018 order with minor enhancements going forward. Also on June 26, 2019, Eversource filed comments in the FERC transmission incentives NOI, requesting that FERC retain policies that have been effective in encouraging new transmission investment and remain flexible enough to attract investment in new and emerging transmission technologies. The NETOs jointly filed reply comments in the FERC ROE NOI on July 26, 2019.  Reply comments in the FERC transmission incentives NOI are due August 26, 2019. At this time, Eversource cannot predict how these NOIs will affect its ROEs or incentives.

FERC Transmission Rate Settlement: On December 28, 2015, FERC initiated a proceeding to review the NETOs' regional and local transmission formula rates due to a lack of transparency, finding that the formula rates appeared to lack sufficient details to determine how costs are derived and recovered in rates. This proceeding was set for hearing but held in abeyance to provide time for settlement judge procedures. On August 17, 2018, a signed Settlement Agreement between twenty-eight parties, including all six New England state regulatory commissions, the NETOs (including CL&P, NSTAR Electric and PSNH) and other settling parties, was filed at the FERC. The Settlement Agreement included, among other things, a new formula rate template, to be effective on January 1, 2020, in which all regional and local transmission revenue requirements will be determined through a single formula rate. The Settlement Agreement was contested by a group of municipal entities and the FERC Trial Staff. On May 22, 2019, FERC rejected the Settlement Agreement and remanded the proceeding for hearings. On July 29, 2019, in response to a request by the NETOs to continue settlement discussions, the FERC Chief Judge suspended the procedural schedule for 45 days and set the date for hearings to begin on April 27, 2020, with the initial decision from the trial judge to be issued September 21, 2020.
 


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Regulatory Developments and Rate Matters

Electric, Natural Gas and Water Utility Base Distribution Rates: The regulated companies’ distribution rates are set by their respective state regulatory commissions, and their tariffs include mechanisms for periodically adjusting their rates for the recovery of specific incurred costs. Other than as described below, for the first half of 2019, changes made to the regulated companies’ rates did not have a material impact on their earnings, financial position, or cash flows.  For further information, see "Financial Condition and Business Analysis – Regulatory Developments and Rate Matters" included in Item 7, "Management’s Discussion and Analysis of Financial Condition and Results of Operations," of the Eversource 2018 Form 10-K.

U.S. Federal Corporate Income Taxes: On December 22, 2017, the Tax Cuts and Jobs Act became law, which amended existing federal tax rules to reduce the U.S. federal corporate income tax rate from 35 percent to 21 percent effective January 1, 2018. For our regulated companies, the most significant changes are (1) the benefit of incurring a lower federal income tax expense and (2) the reduction in ADIT liabilities (now excess ADIT or EDIT), which are estimated to be approximately $2.9 billion and included in regulatory liabilities as of June 30, 2019. The refund of these EDIT regulatory liabilities to customers will generally be made over the same period as the remaining useful lives of the underlying assets that gave rise to the ADIT liabilities. The refund of EDIT has begun at several of our distribution companies and is reflected in rates. The refund to customers and resulting amortization of the EDIT regulatory liabilities results in lower Revenues on the statements of income and lower current tax expense. This is offset by the reduction to Income Tax Expense due to the amortization of the EDIT. The refund of EDIT results in a lower effective tax rate and no impact on net income.
                         
Connecticut:

CL&P Storm Filing: CL&P's approved rate case settlement in 2018 incorporated $18.6 million of rate base recovery for catastrophic storms occurring after December 31, 2016, subject to a future storm filing.  On November 16, 2018, CL&P filed for recovery of $153 million of storm costs incurred from October 2017 through May 2018, with recovery over six years to begin May 1, 2019.  Through the course of the proceeding, CL&P updated its request to $145.5 million to reflect final invoicing and capitalization amounts. On April 17, 2019, PURA authorized recovery of $141.0 million as part of storm cost recovery and the remainder to be recorded to plant or other balance sheet accounts. All approved amounts will be fully recoverable through specific mechanisms or through future rate cases.

Massachusetts:

Hingham Condemnation: On April 22, 2019, the town of Hingham, Massachusetts voted to acquire the water system and treatment plant that supply the towns of Hingham, Hull and North Cohasset with water.  The acquisition price is currently estimated to be more than $100 million, subject to adjustment based on actual capital investments as legally required and other future closing adjustments.  Aquarion will continue to operate the water system during the transition period until the sale occurs.  The Company is evaluating the impact of the sale on its financial statements, which will be recorded when the sale transaction occurs. No loss is expected. The transaction is expected to close by the first quarter of 2020. As of June 30, 2019, these water distribution assets were included within Property, Plant and Equipment, Net and goodwill on the balance sheet and were also reflected in the Water Distribution segment and reporting unit.

New Hampshire:

Distribution Rates: On April 26, 2019, PSNH filed an application with the NHPUC for approval of a temporary annual base distribution rate increase of approximately $33 million, effective July 1, 2019. On June 27, 2019, the NHPUC approved a settlement agreement that was reached by PSNH, the NHPUC Staff, the Office of the Consumer Advocate, and another settling party, to implement a temporary annual base distribution rate increase of $28.3 million. Although new rates were implemented on August 1, 2019 to customers, the provisions of the temporary base distribution rate increase were effective July 1, 2019. The settlement agreement also permits PSNH to recover approximately $68.5 million in unrecovered storm costs over a five-year period beginning August 1, 2019, with debt carrying charges, which is included in the temporary rate increase.

On May 28, 2019, PSNH filed an application with the NHPUC for a permanent increase in base distribution rates of approximately $70 million, effective July 1, 2020, which includes the temporary rate increase request.  The temporary rates are subject to reconciliation based on the outcome of the permanent rate case now before the NHPUC.

Legislative and Policy Matters

New Hampshire:  On July 8, 2019, the New Hampshire Superior Court approved a settlement between PSNH and the Town of Bow, New Hampshire, where the town had over-assessed the value of the property owned by PSNH for the 2014 through 2018 property tax years.  The result of this settlement was $10.0 million in over-paid property taxes that will be refundable to PSNH, with $4.3 million payable in 2019, and the remainder to be received over the following 4 years.

Critical Accounting Policies

The preparation of financial statements in conformity with GAAP requires management to make estimates, assumptions and, at times, difficult, subjective or complex judgments.  Changes in these estimates, assumptions and judgments, in and of themselves, could materially impact our financial position, results of operations or cash flows.  Our management communicates to and discusses with the Audit Committee of our Board of Trustees significant matters relating to critical accounting policies.  Our critical accounting policies that we believed were the most critical in nature were reported in the Eversource 2018 Form 10-K.  There have been no material changes with regard to these critical accounting policies.

52



Refer to Note 1C, "Summary of Significant Accounting Policies - Impairment of Northern Pass Transmission," to the financial statements for further discussion of critical accounting estimates surrounding impairment analysis.

Other Matters

Accounting Standards:  For information regarding new accounting standards, see Note 1B, "Summary of Significant Accounting Policies – Accounting Standards," to the financial statements.

Contractual Obligations and Commercial Commitments:  Refer to Note 9B, "Commitments and Contingencies – Long-Term Contractual
Arrangements," for discussion of material changes to contractual obligations.

Web Site:  Additional financial information is available through our website at www.eversource.com.  We make available through our website a link to the SEC's EDGAR website (http://www.sec.gov/edgar/searchedgar/companysearch.html), at which site Eversource's, CL&P's, NSTAR Electric's and PSNH's combined Annual Reports on Form 10-K, combined Quarterly Reports on Form 10-Q, Current Reports on Form 8-K and any amendments to those reports may be reviewed.  Information contained on the Company's website or that can be accessed through the website is not incorporated into and does not constitute a part of this combined Quarterly Report on Form 10-Q.


53


RESULTS OF OPERATIONS – EVERSOURCE ENERGY AND SUBSIDIARIES

The following provides the amounts and variances in operating revenues and expense line items in the statements of income for Eversource for the three and six months ended June 30, 2019 and 2018 included in this combined Quarterly Report on Form 10-Q:  
 
For the Three Months Ended June 30,
 
For the Six Months Ended June 30,
(Millions of Dollars)
2019
 
2018
 
Increase/
(Decrease)
 
2019
 
2018
 
Increase/
(Decrease)
Operating Revenues
$
1,884.5

 
$
1,853.9

 
$
30.6

 
$
4,300.3

 
$
4,141.8

 
$
158.5

Operating Expenses:
 

 
 

 
 

 
 
 
 

 
 

Purchased Power, Fuel and Transmission
620.9

 
653.9

 
(33.0
)
 
1,595.8

 
1,600.7

 
(4.9
)
Operations and Maintenance
328.0

 
293.9

 
34.1

 
663.6

 
626.4

 
37.2

Depreciation
219.1

 
199.1

 
20.0

 
434.0

 
403.4

 
30.6

Amortization
38.9

 
36.2

 
2.7

 
109.9

 
81.4

 
28.5

Energy Efficiency Programs
105.8

 
102.0

 
3.8

 
246.0

 
236.2

 
9.8

Taxes Other Than Income Taxes
181.2

 
177.5

 
3.7

 
365.7

 
359.8

 
5.9

Impairment of Northern Pass Transmission
239.6

 
—

 
239.6

 
239.6

 
—

 
239.6

Total Operating Expenses
1,733.5

 
1,462.6

 
270.9

 
3,654.6

 
3,307.9

 
346.7

Operating Income
151.0

 
391.3

 
(240.3
)
 
645.7

 
833.9

 
(188.2
)
Interest Expense
132.7

 
126.4

 
6.3

 
264.5

 
247.5

 
17.0

Other Income, Net
45.9

 
50.1

 
(4.2
)
 
76.9

 
83.9

 
(7.0
)
Income Before Income Tax Expense
64.2

 
315.0

 
(250.8
)
 
458.1

 
670.3

 
(212.2
)
Income Tax Expense
30.8

 
70.4

 
(39.6
)
 
114.2

 
154.2

 
(40.0
)
Net Income
33.4

 
244.6

 
(211.2
)
 
343.9

 
516.1

 
(172.2
)
Net Income Attributable to Noncontrolling Interests
1.9

 
1.9

 
—

 
3.8

 
3.8

 
—

Net Income Attributable to Common Shareholders
$
31.5

 
$
242.7

 
$
(211.2
)
 
$
340.1

 
$
512.3

 
$
(172.2
)

Operating Revenues
Sales Volumes: A summary of our retail electric GWh sales volumes, our firm natural gas MMcf sales volumes, and our water MG sales volumes, and percentage changes, is as follows: 
 
Electric
 
Firm Natural Gas
 
Water
 
Sales Volumes (GWh)
 
Percentage
Decrease
 
Sales Volumes (MMcf)
 
Percentage
Increase/
(Decrease)
 
Sales Volumes (MG)
 
Percentage
Decrease
Three Months Ended June 30:
2019
 
2018 (1)
 
 
2019
 
2018 (2)
 
 
2019
 
2018
 
Traditional
1,757

 
1,803

 
(2.6
)%
 
—

 
—

 
—
 %
 
459

 
485

 
(5.4
)%
Decoupled and Special Contracts (3)
9,853

 
10,330

 
(4.6
)%
 
18,191

 
18,932

 
(3.9
)%
 
4,834

 
5,016

 
(3.6
)%
Total Sales Volumes
11,610

 
12,133

 
(4.3
)%
 
18,191

 
18,932

 
(3.9
)%
 
5,293

 
5,501

 
(3.8
)%
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Six Months Ended June 30:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Traditional
3,724

 
3,775

 
(1.4
)%
 
—

 
—

 
—
 %
 
910

 
953

 
(4.5
)%
Decoupled and Special Contracts (3)
21,037

 
21,579

 
(2.5
)%
 
63,358

 
61,983

 
2.2
 %
 
9,212

 
9,373

 
(1.7
)%
Total Sales Volumes
24,761

 
25,354

 
(2.3
)%
 
63,358

 
61,983

 
2.2
 %
 
10,122

 
10,326

 
(2.0
)%

(1)    Effective February 1, 2018, NSTAR Electric operated entirely under a decoupled rate structure. The 2018 sales volumes for NSTAR Electric have been recast to present January 2018 as decoupled to conform to the current year presentation.

(2)    Effective November 15, 2018, Yankee Gas operated under a decoupled rate structure. The 2018 sales volumes for Yankee Gas have been recast to present 2018 as decoupled to conform to the current year presentation.

(3)    Special contracts are unique to Yankee Gas natural gas distribution customers who take service under such an arrangement and generally specify the amount of distribution revenue to be paid to Yankee Gas regardless of the customers' usage.

Fluctuations in retail electric sales volumes at PSNH impact earnings ("Traditional" in the table above).  For CL&P, NSTAR Electric, Yankee Gas, and NSTAR Gas, fluctuations in retail sales volumes do not impact earnings due to their respective regulatory commission-approved distribution revenue decoupling mechanisms ("Decoupled" in the table above).  These distribution revenues are decoupled from their customer sales volumes, which breaks the relationship between sales volumes and revenues recognized.  Fluctuations in water sales volumes largely do not impact earnings as our Connecticut water distribution business is also decoupled.


54


Operating Revenues: Operating Revenues by segment increased for the three and six months ended June 30, 2019, as compared to the same periods in 2018, as follows:
(Millions of Dollars)
Three Months Ended
 
Six Months Ended
Electric Distribution
$
21.9

 
$
101.1

Natural Gas Distribution
1.2

 
45.2

Electric Transmission
32.2

 
67.7

Water Distribution
0.2

 
1.2

Other
13.8

 
41.1

Eliminations
(38.7
)
 
(97.8
)
Total Operating Revenues
$
30.6

 
$
158.5


Three Months Ended:
Electric Distribution Revenues:
•
Base electric distribution revenues increased $20.9 million due primarily to the impact of CL&P base distribution rate increases effective May 1, 2019 and May 1, 2018, which includes recovery of storm costs and certain other items that do not impact earnings, and an NSTAR Electric base distribution rate increase effective January 1, 2019.

•
Tracked revenues consist of certain costs that are recovered from customers in retail rates through regulatory commission-approved cost tracking mechanisms and therefore, recovery of these costs have no impact on earnings.  Costs recovered through cost tracking mechanisms include, among others, energy supply procurement and other energy-related costs, retail transmission charges, energy efficiency program costs, restructuring and stranded cost recovery revenues (including securitized RRB charges), and additionally for NSTAR Electric, pension and PBOP benefits and net metering for distributed generation. In addition, tracked revenues include certain incentives earned, certain return on rate base, and carrying charges that are billed in rates to customers. Tracked retail electric distribution revenues decreased as a result of a decrease in retail electric transmission charges ($41.4 million) and a decrease in other distribution tracking mechanisms ($1.1 million), partially offset by an increase in electric energy supply costs ($37.5 million). Tracked revenues also include wholesale market sales transactions, such as sales of energy and energy-related products into the ISO-NE wholesale electricity market and the sale of RECs to various counterparties, which increased $5.2 million.

Natural Gas Distribution Revenues:
•
Base natural gas distribution revenues decreased $3.5 million due primarily to the seasonality of the decoupled rate structure arising from the Yankee Gas base distribution rate case, which provides lower revenues in non-heating months.

•
Tracked natural gas distribution revenues increased as a result of an increase in wholesale sales of natural gas to third party suppliers ($2.3 million), an increase in capital tracker and other distribution tracking mechanisms ($1.2 million), and an increase in natural gas supply costs ($0.9 million).

Electric Transmission Revenues:  Electric transmission revenues increased $32.2 million due primarily to ongoing investments in our transmission infrastructure.

Other Revenues and Eliminations: Other revenues primarily include the revenues of Eversource's service company, most of which are eliminated in consolidation. Eliminations are primarily related to the Eversource electric transmission revenues that are derived
from ISO-NE regional transmission charges to the distribution businesses of CL&P, NSTAR Electric and PSNH that recover the costs of the
wholesale transmission business, and revenues from Eversource's service company.

Six Months Ended:
Electric Distribution Revenues:
•
Base electric distribution revenues increased $39.2 million due primarily to the impact of CL&P base distribution rate increases effective May 1, 2019 and May 1, 2018, which includes recovery of storm costs and certain other items that do not impact earnings, and an NSTAR Electric base distribution rate increase effective January 1, 2019.

•
Tracked retail electric distribution revenues increased as a result of an increase in electric energy supply costs ($93.6 million), an increase in stranded cost recovery revenues ($13.9 million), and an increase in other distribution tracking mechanisms ($26.8 million), partially offset by a decrease in retail electric transmission charges ($73.2 million). Tracked revenues also include wholesale market sales transactions, such as sales of energy and energy-related products into the ISO-NE wholesale electricity market and the sale of RECs to various counterparties, which decreased $1.9 million.

Natural Gas Distribution Revenues:
•
Base natural gas distribution revenues increased $16.7 million due primarily to the seasonality of the decoupled rate structure arising from the Yankee Gas base distribution rate case, which provides higher revenues in the winter heating months.

•
Tracked natural gas distribution revenues increased as a result of an increase in natural gas supply costs ($22.1 million), an increase in wholesale sales of natural gas to third party suppliers ($6.2 million) and an increase in capital tracker and other distribution tracking mechanisms ($3.9 million).

55



Electric Transmission Revenues:  Electric transmission revenues increased $67.7 million due primarily to ongoing investments in our transmission infrastructure.

Other Revenues and Eliminations: Other revenues primarily include the revenues of Eversource's service company, most of which are eliminated in consolidation. Eliminations are primarily related to the Eversource electric transmission revenues that are derived
from ISO-NE regional transmission charges to the distribution businesses of CL&P, NSTAR Electric and PSNH that recover the costs of the
wholesale transmission business, and revenues from Eversource's service company.

Purchased Power, Fuel and Transmission expense includes costs associated with purchasing electricity and natural gas on behalf of our customers.  These electric and natural gas supply costs are recovered from customers in rates through commission-approved cost tracking mechanisms, which have no impact on earnings (tracked costs).  Purchased Power, Fuel and Transmission expense increased/(decreased) for the three and six months ended June 30, 2019, as compared to the same periods in 2018, due primarily to the following:
(Millions of Dollars)
Three Months Ended
 
Six Months Ended
Electric Distribution
$
23.9

 
$
84.3

Natural Gas Distribution
3.6

 
29.1

Transmission
(37.1
)
 
(64.5
)
Eliminations
(23.4
)
 
(53.8
)
Total Purchased Power, Fuel and Transmission
$
(33.0
)
 
$
(4.9
)

The increase in purchased power expense at the electric distribution business for the three and six months ended June 30, 2019, as compared to the same periods in 2018, was driven primarily by higher prices associated with the procurement of energy supply. The increase in natural gas supply costs at our natural gas distribution business was due primarily to higher average sales volumes.

The decrease in transmission costs for the three and six months ended June 30, 2019, as compared to the same periods in 2018, was primarily the result of a decrease in the retail transmission cost deferral, which reflects the actual costs of transmission service compared to estimated amounts billed to customers, a decrease in costs billed by ISO-NE that support regional grid investments and a decrease in Local Network Service charges, which reflect the cost of transmission service provided by Eversource over our local transmission network.

Operations and Maintenance expense includes tracked costs and costs that are part of base electric, natural gas and water distribution rates with changes impacting earnings (non-tracked costs).  Operations and Maintenance expense increased/(decreased) for the three and six months ended June 30, 2019, as compared to the same periods in 2018, due primarily to the following:
(Millions of Dollars)
Three Months Ended
 
Six Months
Ended
Base Electric Distribution (Non-Tracked Costs):
 
 
 
Employee-related expenses, including labor and benefits
$
0.4

 
$
(12.0
)
Operations-related expenses, including vegetation management, vehicles, and outside services
7.8

 
17.9

Storm Restoration Costs
5.1

 
4.0

Other non-tracked operations and maintenance
1.0


2.4

Total Base Electric Distribution (Non-Tracked Costs)
14.3


12.3

Base Natural Gas Distribution (Non-Tracked Costs)
4.8

 
7.9

Water Distribution
0.4

 
1.1

Tracked Costs (Electric Distribution, Electric Transmission and Natural Gas Distribution) - Increase due primarily to higher electric transmission expenses, partially offset by the absence in 2019 of PSNH generation operations expenses due to the 2018 sales of thermal and hydroelectric generation assets
21.5


30.9

Other and eliminations:
 
 
 
Eversource Parent and Other Companies - other operations and maintenance
6.6

 
27.3

Eliminations
(13.5
)
 
(42.3
)
Total Operations and Maintenance
$
34.1


$
37.2


Depreciation expense increased for the three and six months ended June 30, 2019, as compared to the same periods in 2018, due primarily to higher utility plant in service balances and new depreciation rates effective with the CL&P distribution rate case settlement agreement.

Amortization expense includes the deferral of energy supply and energy-related costs included in certain regulatory commission-approved cost tracking mechanisms, and the amortization of certain costs.  This deferral adjusts expense to match the corresponding revenues. Amortization increased for the three and six months ended June 30, 2019, as compared to the same periods in 2018, due primarily to the deferral of energy supply and energy-related costs, which can fluctuate from period to period based on the timing of costs incurred and the related rate changes to recover these costs. Energy supply and energy-related costs are recovered from customers in rates and have no impact on earnings. The increase for the three and six month periods is also due to higher amortization of PSNH's securitized regulatory asset related to the 2018 RRB issuance of $4.0 million and $14.7 million, respectively.


56


Energy Efficiency Programs expense increased for the three and six months ended June 30, 2019, as compared to the same periods in 2018, due primarily to higher spending for CL&P's, NSTAR Electric's and PSNH's energy efficiency programs. The costs for the majority of the state energy policy initiatives and expanded energy efficiency programs are recovered from customers in rates and have no impact on earnings.

Taxes Other Than Income Taxes expense increased for the three and six months ended June 30, 2019, as compared to the same periods in 2018, due primarily to higher property taxes as a result of higher utility plant in service balances and higher gross earnings taxes (the costs of which are tracked), partially offset by a decrease related to CL&P's remittance of energy efficiency funds to the State of Connecticut of $2.0 million and $4.0 million for the three and six month periods, respectively, and a decrease in NSTAR Electric's property taxes due to a decrease in tax rates.

Impairment of Northern Pass Transmission reflects an impairment charge of $239.6 million that was recorded in the second quarter of 2019 as a result of the July 19, 2019 New Hampshire Supreme Court decision. The after-tax impact of this impairment charge was $204.4 million. For further information on the impairment of NPT, see "Business Development and Capital Expenditures - Electric Transmission Business - Northern Pass" in this Management's Discussion and Analysis of Financial Condition and Results of Operations.

Interest Expense increased for the three and six months ended June 30, 2019, as compared to the same periods in 2018, due primarily to an increase in interest on long-term debt ($7.1 million and $11.3 million, respectively) as a result of new debt issuances, an increase in interest on the 2018 PSNH RRB issuance ($2.5 million and $7.9 million, respectively) and an increase in interest on notes payable ($2.9 million and $7.1 million, respectively). Partially offsetting these increases was an increase in AFUDC related to debt funds and other capitalized interest ($5.4 million and $10.9 million, respectively).

Other Income, Net decreased for the three and six months ended June 30, 2019, as compared to the same periods in 2018, due primarily to a decrease related to pension, SERP and PBOP non-service income components ($8.8 million and $16.7 million, respectively), partially offset by an increase in equity in earnings related to Eversource's equity method investments ($3.0 million and $3.4 million, respectively), an increase in AFUDC related to equity funds ($2.2 million and $3.5 million, respectively) and the recognition in the first quarter of 2019 of $5.2 million of the equity return component of the carrying charges related to storm costs incurred from December 2013 through April 2016 recorded in interest income at PSNH.

Income Tax Expense decreased for the three months ended June 30, 2019, as compared to the same period in 2018, due primarily to the impairment of NPT ($35.2 million), the amortization of EDIT ($8.8 million), and lower pre-tax earnings ($2.4 million), partially offset by items that impact our tax rate as a result of regulatory treatment (flow-through items) and permanent differences ($6.8 million). The impact of the amortization of the EDIT regulatory liability, including the tax gross up portion, that reduced revenue is $12.1 million offset by current tax benefit of $3.4 million and amortization of EDIT of $8.8 million, for the three months ended June 30, 2019, which results in no impact on net income.

Income Tax Expense decreased for the six months ended June 30, 2019, as compared to the same period in 2018, due primarily to the impairment of NPT ($35.2 million), and the amortization of EDIT ($17 million), partially offset by higher pre-tax earnings ($5.8 million), higher state taxes ($1.3 million), and by items that impact our tax rate as a result of regulatory treatment (flow-through items) and permanent differences ($5.1 million). The impact of the amortization of the EDIT regulatory liability, including the tax gross up portion, that reduced revenue is $23.3 million offset by current tax benefit of $6.3 million and amortization of EDIT of $17 million, for the six months ended June 30, 2019, which results in no impact on net income.





57


RESULTS OF OPERATIONS –
THE CONNECTICUT LIGHT AND POWER COMPANY
NSTAR ELECTRIC COMPANY AND SUBSIDIARY
PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES

The following provides the amounts and variances in operating revenues and expense line items in the statements of income for CL&P, NSTAR Electric and PSNH for the six months ended June 30, 2019 and 2018 included in this combined Quarterly Report on Form 10-Q:
 
For the Six Months Ended June 30,
 
CL&P
 
NSTAR Electric
 
PSNH
(Millions of Dollars)
2019
 
2018
 
Increase/
(Decrease)
 
2019
 
2018
 
Increase/
(Decrease)
 
2019
 
2018
 
Increase/
(Decrease)
Operating Revenues
$
1,590.1

 
$
1,479.9

 
$
110.2

 
$
1,479.5

 
$
1,460.9

 
$
18.6

 
$
517.3

 
$
502.5

 
$
14.8

Operating Expenses:
 

 
 

 
 

 
 
 
 
 
 

 
 
 
 
 
 

Purchased Power, Fuel and Transmission
566.4

 
536.2

 
30.2

 
558.5

 
598.7

 
(40.2
)
 
199.3

 
193.2

 
6.1

Operations and Maintenance
264.0

 
227.0

 
37.0

 
221.9

 
220.8

 
1.1

 
105.4

 
97.9

 
7.5

Depreciation
147.8

 
136.9

 
10.9

 
145.6

 
134.6

 
11.0

 
46.2

 
46.3

 
(0.1
)
Amortization of Regulatory Assets, Net
48.0

 
43.4

 
4.6

 
45.8

 
18.3

 
27.5

 
19.5

 
14.0

 
5.5

Energy Efficiency Programs
46.8

 
41.4

 
5.4

 
142.6

 
140.0

 
2.6

 
12.9

 
9.8

 
3.1

Taxes Other Than Income Taxes
178.5

 
174.7

 
3.8

 
93.1

 
95.9

 
(2.8
)
 
38.0

 
38.7

 
(0.7
)
Total Operating Expenses
1,251.5

 
1,159.6

 
91.9

 
1,207.5

 
1,208.3

 
(0.8
)
 
421.3

 
399.9

 
21.4

Operating Income
338.6

 
320.3

 
18.3

 
272.0

 
252.6

 
19.4

 
96.0

 
102.6

 
(6.6
)
Interest Expense
72.7

 
75.5

 
(2.8
)
 
56.1

 
53.8

 
2.3

 
28.3

 
27.4

 
0.9

Other Income, Net
6.7

 
13.7

 
(7.0
)
 
21.7

 
26.9

 
(5.2
)
 
10.0

 
8.2

 
1.8

Income Before Income Tax Expense
272.6

 
258.5

 
14.1

 
237.6

 
225.7

 
11.9

 
77.7

 
83.4

 
(5.7
)
Income Tax Expense
57.3

 
60.2

 
(2.9
)
 
53.9

 
60.6

 
(6.7
)
 
18.1

 
22.5

 
(4.4
)
Net Income
$
215.3

 
$
198.3

 
$
17.0

 
$
183.7

 
$
165.1

 
$
18.6

 
$
59.6

 
$
60.9

 
$
(1.3
)

Operating Revenues
Sales Volumes: A summary of our retail electric GWh sales volumes was as follows:
 
For the Six Months Ended June 30,
 
2019
 
2018
 
Decrease
 
Percentage Decrease
CL&P
9,953

 
10,222

 
(269
)
 
(2.6
)%
NSTAR Electric
11,084

 
11,357

 
(273
)
 
(2.4
)%
PSNH
3,724

 
3,775

 
(51
)
 
(1.4
)%

Fluctuations in retail electric sales volumes at PSNH impact earnings.  For CL&P and NSTAR Electric, fluctuations in retail electric sales volumes do not impact earnings due to their respective regulatory commission-approved distribution revenue decoupling mechanisms.

Operating Revenues: Operating Revenues, which consist of base distribution revenues and tracked revenues further described below, increased $110.2 million at CL&P, $18.6 million at NSTAR Electric and $14.8 million at PSNH for the six months ended June 30, 2019, as compared to the same period in 2018.

Base Distribution Revenues:
•
CL&P's distribution revenues increased $34.1 million due primarily to the impact of its base distribution rate increases effective May 1, 2019 and May 1, 2018 as a result of the PURA-approved rate case settlement agreement, which includes recovery of storm costs and certain other items that do not impact earnings.

•
NSTAR Electric's distribution revenues increased $7.0 million due primarily to the impact of its base distribution rate increase effective January 1, 2019.

•
PSNH's distribution revenues decreased $1.9 million due primarily to lower demand revenues in the first half of 2019, as compared to the same period in 2018.


58


Tracked Revenues: Tracked revenues consist of certain costs that are recovered from customers in rates through regulatory commission-approved cost tracking mechanisms and therefore, recovery of these costs have no impact on earnings.  Costs recovered through cost tracking mechanisms include, among others, energy supply procurement and other energy-related costs, retail transmission charges, energy efficiency program costs, restructuring and stranded cost recovery revenues (including securitized RRB charges), and additionally for NSTAR Electric, pension and PBOP benefits and net metering for distributed generation.  Tracked revenues also include wholesale market sales transactions, such as sales of energy and energy-related products into the ISO-NE wholesale electricity market and the sale of RECs to various counterparties. In addition, tracked revenues include certain incentives earned, certain return on rate base, and carrying charges that are billed in rates to customers, which do impact earnings. Tracked revenues increased/(decreased) for the six months ended June 30, 2019, as compared to the same period in 2018, due primarily to the following:
(Millions of Dollars)
CL&P
 
NSTAR Electric
 
PSNH
Retail Tariff Tracked Revenues
 
 
 
 
 
Energy supply procurement
$
60.2

 
$
25.3

 
$
8.1

Retail transmission
(17.5
)
 
(37.7
)
 
(18.0
)
Stranded cost recovery
(6.3
)
 
2.4

 
17.8

Other distribution tracking mechanisms
8.5

 
14.0

 
4.3

Wholesale Market Sales Revenue
4.8

 
3.4

 
(11.5
)

PSNH's energy supply procurement revenues includes the absence in 2019 of the recovery of generation rate base return due to the sales of its thermal and hydroelectric generation assets in 2018. Revenues from CL&P's other distribution tracking mechanisms include higher earnings in 2019 from its capital tracker mechanism effective July 1, 2018 due to increased electric system improvements.

Transmission Revenues: Transmission revenues increased $38.6 million at CL&P, $13.4 million at NSTAR Electric, and $15.7 million at PSNH due primarily to ongoing investments in our transmission infrastructure.

Eliminations: Eliminations are primarily related to the Eversource electric transmission revenues that are derived from ISO-NE regional transmission charges to the distribution businesses of CL&P, NSTAR Electric and PSNH that recover the costs of the wholesale transmission business. The impact of eliminations decreased revenues by $15.7 million at CL&P, $8.7 million at NSTAR Electric and $0.3 million at PSNH.

Purchased Power, Fuel and Transmission expense includes costs associated with purchasing electricity on behalf of CL&P, NSTAR Electric and PSNH's customers.  These energy supply costs are recovered from customers in commission-approved cost tracking mechanisms, which have no impact on earnings (tracked costs). Purchased Power, Fuel and Transmission expense increased/(decreased) for the six months ended June 30, 2019, as compared to the same period in 2018, due primarily to the following:
(Millions of Dollars)
CL&P
 
NSTAR Electric
 
PSNH
Purchased Power Costs
$
60.5

 
$
5.3

 
$
18.5

Transmission Costs
(15.3
)
 
(37.0
)
 
(12.2
)
Eliminations
(15.0
)
 
(8.5
)
 
(0.2
)
Total Purchased Power, Fuel and Transmission
$
30.2

 
$
(40.2
)
 
$
6.1


Purchased Power Costs: Included in purchased power costs are the costs associated with providing electric generation service supply to all customers who have not migrated to third party suppliers.

•
The increase at CL&P was due primarily to an increase in the price and volume of power procured on behalf of our customers.
•
The increase at NSTAR Electric was due primarily to an increase in the price of power procured on behalf of our customers.
•
The increase at PSNH was due primarily to higher purchased power energy expenses that are recovered as a component of the Energy Service tracking mechanism.

Transmission Costs: Included in transmission costs are charges that recover the cost of transporting electricity over high-voltage lines from generation facilities to substations, including costs allocated by ISO-NE to maintain the wholesale electric market.

•
The decrease in transmission costs at CL&P was primarily a result of a decrease in costs billed by ISO-NE that support regional grid investments, and a decrease in Local Network Service charges, which reflect the cost of transmission service provided by Eversource over our local transmission network. This was partially offset by an increase in the retail transmission cost deferral, which reflects the actual costs of transmission service compared to estimated amounts billed to customers.
•
The decrease in transmission costs at NSTAR Electric was primarily a result of a decrease in the retail transmission cost deferral, which reflects the actual costs of transmission service compared to estimated amounts billed to customers, and a decrease in costs billed by ISO-NE that support regional grid investments. This was partially offset by an increase in Local Network Service charges, which reflect the cost of transmission service provided by Eversource over our local transmission network.
•
The decrease in transmission costs at PSNH was primarily a result of a decrease in the retail transmission cost deferral, which reflects the actual costs of transmission service compared to estimated amounts billed to customers, a decrease in costs billed by ISO-NE that support regional grid investments and a decrease in Local Network Service charges, which reflect the cost of transmission service provided by Eversource over our local transmission network.


59



Operations and Maintenance expense includes tracked costs and costs that are part of base distribution rates with changes impacting earnings (non-tracked costs).  Operations and Maintenance expense increased/(decreased) for the six months ended June 30, 2019, as compared to the same period in 2018, due primarily to the following:
(Millions of Dollars)
CL&P
 
NSTAR Electric
 
PSNH
Base Electric Distribution (Non-Tracked Costs):
 
 
 
 
 
Employee-related expenses, including labor and benefits
$
(4.2
)
 
$
(7.1
)
 
$
(0.7
)
Operations-related expenses, including vegetation management, vehicles, and outside services
11.0

 
2.1

 
4.8

Storm restoration costs
(3.3
)
 
5.9

 
1.4

Other non-tracked operations and maintenance
6.8

 
(5.2
)
 
0.8

Total Base Electric Distribution (Non-Tracked Costs)
10.3

 
(4.3
)
 
6.3

Tracked Costs:
 
 
 
 
 
Absence in 2019 of PSNH generation operations expenses due to the 2018 sales of thermal and hydroelectric generation assets
—

 
—

 
(7.0
)
Transmission expenses
24.6

 
0.4

 
3.0

Other tracked operations and maintenance
2.1

 
5.0

 
5.2

Total Tracked Costs
26.7

 
5.4

 
1.2

Total Operations and Maintenance
$
37.0

 
$
1.1

 
$
7.5


Depreciation increased for the six months ended June 30, 2019, as compared to the same period in 2018, due primarily to the following:

•
The increase at CL&P was due primarily to higher net plant in service balances and the implementation of new depreciation rates effective with the CL&P distribution rate case settlement agreement.  
•
The increase at NSTAR Electric was due to higher net plant in service balances.

Amortization of Regulatory Assets, Net expense includes the deferral of energy supply and energy-related costs included in certain regulatory-approved cost tracking mechanisms, and the amortization of certain costs. This deferral adjusts expense to match the corresponding revenues. Amortization of Regulatory Assets, Net increased at CL&P for the six months ended June 30, 2019, as compared to the same period in 2018, due primarily to higher recovery of deferred storm restoration costs approved in distribution rates, and at NSTAR Electric and PSNH due primarily to the deferral adjustment of energy supply and energy-related costs, which can fluctuate from period to period based on the timing of costs incurred and related rate changes to recover these costs. Energy supply and energy-related costs are recovered from customers in rates and have no impact on earnings. The increase at PSNH is also due to higher amortization of its securitized regulatory asset related to the 2018 RRB issuance of $14.7 million.

Energy Efficiency Programs expense includes costs for various state energy policy initiatives and expanded energy efficiency programs, the majority of which are recovered from customers in rates and have no impact on earnings. Energy Efficiency Programs expense increased for the six months ended June 30, 2019, as compared to the same period in 2018, due primarily to higher spending for CL&P's, NSTAR Electric's and PSNH's energy efficiency programs.

Taxes Other Than Income Taxes increased/(decreased) for the six months ended June 30, 2019, as compared to the same period in 2018, due primarily to the following:

•
The increase at CL&P was due primarily to higher property taxes as a result of higher utility plant balances and higher gross earnings taxes (the costs of which are tracked), partially offset by a decrease related to CL&P's remittance of energy efficiency funds to the State of Connecticut of $4.0 million.
•
The decrease at NSTAR Electric was due primarily to lower property taxes as a result of a decrease in tax rates.

Interest Expense (decreased)/increased for the six months ended June 30, 2019, as compared to the same period in 2018, due primarily to the following:

•
The decrease at CL&P was due primarily to lower interest on long-term debt ($3.5 million) and an increase in AFUDC related to debt funds ($0.4 million), partially offset by an increase in interest expense on regulatory deferrals ($1.4 million).
•
The increase at NSTAR Electric was due primarily to higher interest on long-term debt ($1.6 million).
•
The increase at PSNH was due primarily to an increase in interest on the 2018 PSNH RRB issuance ($7.9 million), partially offset by lower interest on long-term debt ($3.3 million), a decrease in interest on notes payable ($1.5 million) and an increase in AFUDC related to debt funds ($0.9 million).




60


Other Income, Net (decreased)/increased for the six months ended June 30, 2019, as compared to the same period in 2018, due primarily to the following:

•
The decrease at CL&P was due primarily to a decrease related to pension, SERP and PBOP non-service income components ($6.9 million).
•
The decrease at NSTAR Electric was due primarily to a decrease related to pension, SERP and PBOP non-service income components ($5.5 million).
•
The increase at PSNH was due primarily to the recognition in the first quarter of 2019 of $5.2 million of the equity return component of the carrying charges related to storm costs incurred from December 2013 through April 2016 recorded in interest income, and an increase in AFUDC related to equity funds ($1.1 million), partially offset by a decrease related to pension, SERP and PBOP non-service income components ($2.4 million).

Income Tax Expense decreased for the six months ended June 30, 2019, as compared to the same period in 2018, due primarily to the following:

•
The decrease at CL&P was due primarily to amortization of EDIT ($1.5 million), lower state taxes ($1.2 million), and by items that impact our tax rate as a result of regulatory treatment (flow-through items) and permanent differences ($3.2 million) offset by higher pre-tax earnings ($3 million). The impact of the amortization of the EDIT regulatory liability, including the tax gross up portion, that reduced revenue is $2.0 million offset by a current tax benefit of $0.5 million and amortization of EDIT of $1.5 million, for the six months ended June 30, 2019, which results in no impact on net income.
•
The decrease at NSTAR Electric was due primarily to amortization of EDIT ($9.6 million), partially offset by higher pre-tax earnings ($2.5 million), and by items that impact our tax rate as a result of regulatory treatment (flow-through items) and permanent differences ($0.4 million). The impact of the amortization of the EDIT regulatory liability, including the tax gross up portion, that reduced revenue is $13.3 million offset by a current tax benefit of $3.7 million and amortization of EDIT of $9.6 million, for the six months ended June 30, 2019, which results in no impact on net income.
•
The decrease at PSNH was due primarily to lower pre-tax earnings ($1.2 million), amortization of EDIT ($2.1 million), and items that impact our tax rate as a result of regulatory treatment (flow-through items) and permanent differences ($1.1 million). The impact of the amortization of the EDIT regulatory liability, including the tax gross up portion, that reduced revenue is $2.8 million offset by a current tax benefit of $0.7 million and amortization of EDIT of $2.1 million, for the six months ended June 30, 2019,which results in no impact on net income.

EARNINGS SUMMARY

CL&P's earnings increased $17.0 million for the six months ended June 30, 2019, as compared to the same period in 2018, due primarily to base distribution rate increases effective May 1, 2019 and May 1, 2018, higher earnings from its capital tracker mechanism, and an increase in transmission earnings driven by a higher transmission rate base. The earnings increase was partially offset by higher operations and maintenance expense, lower non-service income from our benefit plans, higher depreciation expense and higher property and other tax expense.

NSTAR Electric's earnings increased $18.6 million for the six months ended June 30, 2019, as compared to the same period in 2018, due primarily to an increase in transmission earnings driven by a higher transmission rate base, the NSTAR Electric base distribution rate increase effective January 1, 2019, lower operations and maintenance expense, and lower property and other tax expense. The earnings increase was partially offset by higher depreciation expense.

PSNH's earnings decreased $1.3 million for the six months ended June 30, 2019, as compared to the same period in 2018, due primarily to the absence in 2019 of generation earnings as a result of the sale of its generation assets in 2018, higher operations and maintenance expense and lower demand revenues. The earnings decrease was partially offset by an increase in transmission earnings driven by a higher transmission rate base and the recognition in 2019 of carrying charges on storm costs approved for recovery.

LIQUIDITY

Cash Flows: CL&P had cash flows provided by operating activities of $345.6 million for the six months ended June 30, 2019, as compared to $268.1 million in the same period of 2018.  The increase in operating cash flows was due primarily to the absence in 2019 of approximately $71 million of storm restoration cost payments and $41.2 million in pension contributions made in the first half of 2018, and the timing of accounts payable cash payments. Partially offsetting these favorable impacts were the timing of collections for regulatory tracking mechanisms and other working capital items.
 
NSTAR Electric had cash flows provided by operating activities of $251.5 million for the six months ended June 30, 2019, as compared to $202.7 million in the same period of 2018.  The increase in operating cash flows was due primarily to the absence in 2019 of approximately $85 million of storm restoration cost payments made in the first half of 2018, a decrease of $56.1 million in pension and PBOP cash contributions, lower income tax payments made in the first half of 2019 of $47 million, and the timing of cash collections on our accounts receivables. Partially offsetting these favorable impacts were the timing of accounts payable cash payments, the timing of collections for regulatory tracking mechanisms, and the timing of other working capital items.


61


PSNH had cash flows provided by operating activities of $121.7 million for the six months ended June 30, 2019, as compared to $112.8 million in the same period of 2018.  The increase in operating cash flows was due primarily to income tax refunds of $11.8 million in the first half of 2019, as compared to income tax payments of $9.0 million in the same period in 2018, the timing of cash collections on accounts receivable, and the timing of accounts payable cash payments. Partially offsetting these favorable impacts was the timing of collections and payments of our other working capital items.

For further information on CL&P's, NSTAR Electric's and PSNH's liquidity and capital resources, see "Liquidity" and "Business Development and Capital Expenditures" included in this Management's Discussion and Analysis of Financial Condition and Results of Operations.

62


RESULTS OF OPERATIONS – THE CONNECTICUT LIGHT AND POWER COMPANY

The following provides the amounts and variances in operating revenues and expense line items in the statements of income for CL&P for the three months ended June 30, 2019 and 2018 included in this combined Quarterly Report on Form 10-Q:
 
For the Three Months Ended June 30,
(Millions of Dollars)
2019
 
2018
 
Increase/(Decrease)
Operating Revenues
$
740.8

 
$
694.9

 
$
45.9

Operating Expenses:
 

 
 

 
 

Purchased Power and Transmission
246.5

 
234.3

 
12.2

Operations and Maintenance
133.4

 
109.7

 
23.7

Depreciation
74.6

 
69.4

 
5.2

Amortization of Regulatory Assets, Net
12.4

 
15.4

 
(3.0
)
Energy Efficiency Programs
20.8

 
18.6

 
2.2

Taxes Other Than Income Taxes
86.4

 
84.4

 
2.0

Total Operating Expenses
574.1

 
531.8

 
42.3

Operating Income
166.7

 
163.1

 
3.6

Interest Expense
36.9

 
38.7

 
(1.8
)
Other Income, Net
2.9

 
7.1

 
(4.2
)
Income Before Income Tax Expense
132.7

 
131.5

 
1.2

Income Tax Expense
27.9

 
31.8

 
(3.9
)
Net Income
$
104.8

 
$
99.7

 
$
5.1


Operating Revenues
Sales Volumes: CL&P's retail electric GWh sales volumes were 4,602 and 4,846 for the three months ended June 30, 2019 and 2018, respectively, resulting in a decrease of 5.0 percent. Fluctuations in retail electric sales volumes do not impact earnings due to its PURA-approved distribution revenue decoupling mechanism.

Operating Revenues: Operating Revenues, which consist of base distribution revenues and tracked revenues further described below, increased $45.9 million for the three months ended June 30, 2019, as compared to the same period in 2018.

Base Distribution Revenues: CL&P's distribution revenues increased $14.5 million due primarily to the impact of its base distribution rate increases effective May 1, 2019 and May 1, 2018 as a result of the PURA-approved rate case settlement agreement, which includes recovery of storm costs and certain other items that do not impact earnings.

Tracked Revenues: Tracked revenues increased/(decreased) for the three months ended June 30, 2019, as compared to the same period in 2018, due primarily to the following:
(Millions of Dollars)
 
Retail Tariff Tracked Revenues
 
Energy supply procurement
$
23.9

Retail transmission
(8.1
)
Other distribution tracking mechanisms
0.2

Wholesale Market Sales Revenue
1.5


Revenues from CL&P's other distribution tracking mechanisms include higher earnings from its capital tracker mechanism effective July 1, 2018 due to increased electric system improvements.

Transmission Revenues: Transmission revenues increased $21.2 million due primarily to ongoing investments in our transmission infrastructure.

Eliminations: Eliminations are primarily related to transmission revenues derived from ISO-NE regional transmission charges to the distribution business that recovers the costs of the wholesale transmission business. The impact of eliminations decreased revenues by $8.0 million.

Purchased Power and Transmission expense includes costs associated with purchasing electricity on behalf of CL&P's customers. These energy supply costs are recovered from customers in PURA-approved cost tracking mechanisms, which have no impact on earnings (tracked costs). Purchased Power and Transmission expense increased/(decreased) for the three months ended June 30, 2019, as compared to the same period in 2018, due primarily to the following:
(Millions of Dollars)
 
Purchased Power Costs
$
26.3

Transmission Costs
(6.8
)
Eliminations
(7.3
)
Total Purchased Power and Transmission
$
12.2


63



The increase in purchased power costs was due primarily to an increase in both the price and volume of power procured on behalf of our customers. The decrease in transmission costs was primarily a result of a decrease in Local Network Service charges, which reflect the cost of transmission service provided over the local transmission network, and a decrease in costs billed by ISO-NE that support regional grid investments. This was partially offset by an increase in the retail transmission cost deferral, which reflects the actual costs of transmission service compared to estimated amounts billed to customers network.

Operations and Maintenance expense includes tracked costs and costs that are part of base distribution rates with changes impacting earnings (non-tracked costs).  Operations and Maintenance expense increased/(decreased) for the three months ended June 30, 2019, as compared to the same period in 2018, due primarily to the following:
(Millions of Dollars)
 
Base Electric Distribution (Non-Tracked Costs):
 
Employee-related expenses, including labor and benefits
$
(2.0
)
Operations-related expenses, including vegetation management, vehicles, and outside services
5.8

Other non-tracked operations and maintenance
4.1

Total Base Electric Distribution (Non-Tracked Costs)
7.9

Total Tracked Costs
15.8

Total Operations and Maintenance
$
23.7


Depreciation expense increased for the three months ended June 30, 2019, as compared to the same period in 2018, due primarily to higher net plant in service balances and the implementation of new depreciation rates effective with the CL&P distribution rate case settlement agreement. 

Amortization of Regulatory Assets, Net expense includes the deferral of energy supply and energy-related costs included in certain regulatory-approved cost tracking mechanisms, and the amortization of certain costs. This deferral adjusts expenses to match the corresponding revenues. Amortization of Regulatory Assets, Net decreased at CL&P for the three months ended June 30, 2019, as compared to the same period in 2018, due primarily to the deferral adjustment of energy supply and energy-related costs, which can fluctuate from period to period based on the timing of costs incurred and related rate changes to recover these costs. Energy supply and energy-related costs, which are the primary drivers of amortization, are recovered from customers in rates and have no impact on earnings.  

Energy Efficiency Programs expense includes costs for various state energy policy initiatives and expanded energy efficiency programs, the majority of which are recovered from customers in rates and have no impact on earnings. Energy Efficiency Programs expense increased for the three months ended June 30, 2019, as compared to the same period in 2018, due primarily to higher spending for energy efficiency programs.

Taxes Other Than Income Taxes increased for the three months ended June 30, 2019, as compared to the same period in 2018, due primarily to higher property taxes as a result of higher utility plant balances and higher gross earnings taxes (the costs of which are tracked), partially offset by a decrease related to CL&P's remittance of energy efficiency funds to the State of Connecticut of $2.0 million.

Interest Expense decreased at CL&P for the three months ended June 30, 2019, as compared to the same period in 2018, due primarily to lower interest on long-term debt ($1.9 million) and an increase in AFUDC related to debt funds ($0.3 million), partially offset by an increase in interest expense on regulatory deferrals ($0.4 million).

Other Income, Net decreased for the three months ended June 30, 2019, as compared to the same period in 2018, due primarily to a decrease related to pension, SERP and PBOP non-service income components ($3.3 million).

Income Tax Expense decreased for the three months ended June 30, 2019, as compared to the same period in 2018, due primarily to amortization of EDIT ($1.5 million), lower state taxes ($1.9 million) and by items that impact our tax rate as a result of regulatory treatment (flow-through items) and permanent differences ($0.5 million). The impact of the amortization of the EDIT regulatory liability, including the tax gross up portion, that reduced revenue is $2.0 million offset by a current tax benefit of $0.5 million and amortization of EDIT of $1.5 million, for the three months ended June 30, 2019, which results in no impact on net income.

EARNINGS SUMMARY

CL&P's earnings increased $5.1 million for the three months ended June 30, 2019, as compared to the same period in 2018, due primarily to base distribution rate increases effective May 1, 2019 and May 1, 2018 and higher earnings from its capital tracker mechanism. The earnings increase was partially offset by higher operations and maintenance expense, lower non-service income from our benefit plans, higher depreciation expense and higher property and other tax expense.

64



ITEM 3.
QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Market Risk Information

Commodity Price Risk Management:  Our regulated companies enter into energy contracts to serve our customers and the economic impacts of those contracts are passed on to our customers. Accordingly, the regulated companies have no exposure to loss of future earnings or fair values due to these market risk-sensitive instruments.  Eversource's Energy Supply Risk Committee, comprised of senior officers, reviews and approves all large-scale energy related transactions entered into by its regulated companies.

Other Risk Management Activities

Interest Rate Risk Management:  We manage our interest rate risk exposure in accordance with our written policies and procedures.

Credit Risk Management:  Credit risk relates to the risk of loss that we would incur as a result of non-performance by counterparties pursuant to the terms of our contractual obligations.  We serve a wide variety of customers and transact with suppliers that include IPPs, industrial companies, natural gas and electric utilities, oil and gas producers, financial institutions, and other energy marketers.  Margin accounts exist within this diverse group, and we realize interest receipts and payments related to balances outstanding in these margin accounts.  This wide customer and supplier mix generates a need for a variety of contractual structures, products and terms that, in turn, require us to manage the portfolio of market risk inherent in those transactions in a manner consistent with the parameters established by our risk management process.

Our regulated companies are subject to credit risk from certain long-term or high-volume supply contracts with energy marketing companies.  Our regulated companies manage the credit risk with these counterparties in accordance with established credit risk practices and monitor contracting risks, including credit risk.  As of June 30, 2019, our regulated companies held collateral in the form of letters of credit of $8.0 million from counterparties related to our standard service contracts.  As of June 30, 2019, Eversource had $19.1 million of cash posted with ISO-NE related to energy transactions.

We have provided additional disclosures regarding interest rate risk management and credit risk management in Part II, Item 7A, "Quantitative and Qualitative Disclosures about Market Risk," in Eversource's 2018 Form 10-K, which is incorporated herein by reference. There have been no additional risks identified and no material changes with regard to the items previously disclosed in the Eversource 2018 Form 10-K.

ITEM 4.
CONTROLS AND PROCEDURES

Management, on behalf of Eversource, CL&P, NSTAR Electric and PSNH, evaluated the design and operation of the disclosure controls and procedures as of June 30, 2019 to determine whether they are effective in ensuring that the disclosure of required information is made timely and in accordance with the Securities Exchange Act of 1934 and the rules and regulations of the SEC.  This evaluation was made under management's supervision and with management's participation, including the principal executive officer and principal financial officer as of the end of the period covered by this Quarterly Report on Form 10-Q.  There are inherent limitations of disclosure controls and procedures, including the possibility of human error and the circumventing or overriding of the controls and procedures.  Accordingly, even effective disclosure controls and procedures can only provide reasonable assurance of achieving their control objectives.  The principal executive officer and principal financial officer have concluded, based on their review, that the disclosure controls and procedures of Eversource, CL&P, NSTAR Electric and PSNH are effective to ensure that information required to be disclosed by us in reports filed under the Securities Exchange Act of 1934 (i) is recorded, processed, summarized, and reported within the time periods specified in SEC rules and regulations and (ii) is accumulated and communicated to management, including the principal executive officer and principal financial officer, as appropriate to allow timely decisions regarding required disclosures.

There have been no changes in internal controls over financial reporting for Eversource, CL&P, NSTAR Electric and PSNH during the quarter ended June 30, 2019 that have materially affected, or are reasonably likely to materially affect, internal controls over financial reporting.



65


PART II. OTHER INFORMATION

ITEM 1.
LEGAL PROCEEDINGS

We are parties to various legal proceedings.  We have disclosed these legal proceedings in Part I, Item 3, "Legal Proceedings," and elsewhere in our 2018 Form 10-K.  These disclosures are incorporated herein by reference.  

As previously disclosed, on May 22, 2017, each of the Yankee Companies filed subsequent lawsuits against the DOE in the Court of Federal Claims. The Yankee Companies sought monetary damages totaling $104.4 million for CYAPC, YAEC and MYAPC, resulting from the DOE's failure to begin accepting spent nuclear fuel for disposal covering the years from 2013 to 2016 (“DOE Phase IV”). On February 21, 2019, the Yankee Companies received a partial summary judgment and partial final judgment in their favor for the undisputed amount of monetary damages of $103.2 million. The court awarded CYAPC, YAEC and MYAPC damages of $40.7 million, $28.1 million and $34.4 million, respectively. The DOE did not appeal the court's judgment and the decision became final on April 23, 2019. On June 12, 2019, the court accepted an offer of judgment in the amount of $0.5 million to settle the disputed amount of approximately $1 million in Phase IV contested damages. The Yankee Companies received the $0.5 million payment in July 2019. For a further discussion of the Yankee Companies v. U.S. Department of Energy, see Part I, Item 3, “Legal Proceedings” of our 2018 Form 10-K.

Other than as set forth above, there have been no additional material legal proceedings identified and no further material changes with regard to the legal proceedings previously disclosed in our 2018 Form 10-K.

ITEM 1A.
RISK FACTORS

We are subject to a variety of significant risks in addition to the matters set forth under our forward-looking statements section in Item 2, "Management's Discussion and Analysis of Financial Condition and Results of Operations," of this Quarterly Report on Form 10-Q.  We have identified a number of these risk factors in Part I, Item 1A, "Risk Factors," in our 2018 Form 10-K, which risk factors are incorporated herein by reference.  These risk factors should be considered carefully in evaluating our risk profile.  There have been no additional risk factors identified and no material changes with regard to the risk factors previously disclosed in our 2018 Form 10-K.

ITEM 2.
UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

The following table discloses purchases of our common shares made by us or on our behalf for the periods shown below.  The common shares purchased consist of open market purchases made by the Company or an independent agent.  These share transactions related to matching contributions under the Eversource 401k Plan.
Period
Total Number of
Shares Purchased
Average Price
Paid per Share
Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs
Approximate Dollar Value of Shares that May Yet Be Purchased Under the Plans and Programs (at month end)
April 1 - April 30, 2019
—

$
—

—

—

May 1 - May 31, 2019
—

—

—

—

June 1 - June 30, 2019
2,709

75.76

—

—

Total
2,709

$
75.76

—

—



66


ITEM 6.
EXHIBITS

Each document described below is filed herewith, unless designated with an asterisk (*), which exhibits are incorporated by reference by the registrant under whose name the exhibit appears.
 
Exhibit No.
 
Description
 
 
 
 
 
Listing of Exhibits (Eversource)
*
10.1
 
Forward Sale Agreement between Eversource Energy and Goldman Sachs & Co. LLC, dated as of May 30, 2019 (Exhibit 10.1, Eversource Energy Current Report on Form 8-K filed on June 5, 2019, File No. 001-05324)
 
 
 
 
 
31
 
Certification by the Chief Executive Officer of Eversource Energy pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
 
 
 
 
 
31.1
 
Certification by the Chief Financial Officer of Eversource Energy pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
 
 
 
 
 
32
 
Certification by the Chief Executive Officer and Chief Financial Officer of Eversource Energy pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
 
 
 
 
 
Listing of Exhibits (CL&P)
 
31
 
Certification by the Chairman of The Connecticut Light and Power Company pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
 
 
 
 
 
31.1
 
Certification by the Chief Financial Officer of The Connecticut Light and Power Company pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
 
 
 
 
 
32
 
Certification by the Chairman and the Chief Financial Officer of The Connecticut Light and Power Company pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
 
 
 
 
 
Listing of Exhibits (NSTAR Electric Company)
*
4.1
 
Form of 3.25% Debenture due May 15, 2029 (Exhibit 4, NSTAR Electric Company Current Report on Form 8-K filed on May 23, 2019, File No. 001-02301)
 
 
 
 
 
31
 
Certification by the Chairman of NSTAR Electric Company pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
 
 
 
 
 
31.1
 
Certification by the Chief Financial Officer of NSTAR Electric Company pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
 
 
 
 
 
32
 
Certification by the Chairman and the Chief Financial Officer of NSTAR Electric Company pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
 
 
 
 
 
Listing of Exhibits (PSNH)
*
4.1
 
Twenty-Second Supplemental Indenture, between PSNH and U.S. Bank National Association, as Trustee dated as of June 1, 2019 (Exhibit 4.1, PSNH Current Report on Form 8-K filed July 3, 2019, File No. 001-06392)
 
 
 
 
 
31
 
Certification by the Chairman of Public Service Company of New Hampshire pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
 
 
 
 
 
31.1
 
Certification by the Chief Financial Officer of Public Service Company of New Hampshire pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
 
 
 
 
 
32
 
Certification by the Chairman and the Chief Financial Officer of Public Service Company of New Hampshire pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
 
 
 
 
 
Listing of Exhibits (Eversource, CL&P, NSTAR Electric, PSNH)
 
101.INS
 
Inline XBRL Instance Document - the instance document does not appear in the interactive data file because its XBRL tags are embedded within the inline XBRL document
 
 
 
 
 
101.SCH
 
Inline XBRL Taxonomy Extension Schema
 
 
 
 
 
101.CAL
 
Inline XBRL Taxonomy Extension Calculation
 
 
 
 

67


 
101.DEF
 
Inline XBRL Taxonomy Extension Definition
 
 
 
 
 
101.LAB
 
Inline XBRL Taxonomy Extension Labels
 
 
 
 
 
101.PRE
 
Inline XBRL Taxonomy Extension Presentation
 
 
 
 
 
104
 
The cover page from the Quarterly Report on Form 10-Q for the quarter ended June 30, 2019, formatted in Inline XBRL


68


SIGNATURE


Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

 
 
EVERSOURCE ENERGY
 
 
 
 
August 6, 2019
 
By:
/s/ Jay S. Buth
 
 
 
Jay S. Buth
 
 
 
Vice President, Controller and Chief Accounting Officer

 
 
 
 
 


SIGNATURE


Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

 
 
THE CONNECTICUT LIGHT AND POWER COMPANY
 
 
 
 
August 6, 2019
 
By:
/s/ Jay S. Buth
 
 
 
Jay S. Buth
 
 
 
Vice President, Controller and Chief Accounting Officer

 
 
 
 
 


SIGNATURE


Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

 
 
NSTAR ELECTRIC COMPANY
 
 
 
 
August 6, 2019
 
By:
/s/ Jay S. Buth
 
 
 
Jay S. Buth
 
 
 
Vice President, Controller and Chief Accounting Officer

 
 
 
 
 


SIGNATURE


Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

 
 
PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE
 
 
 
 
August 6, 2019
 
By:
/s/ Jay S. Buth
 
 
 
Jay S. Buth
 
 
 
Vice President, Controller and Chief Accounting Officer

69

What is the market capitalization of a company?

The market capitalization sometimes referred as Marketcap, is the value of a publicly listed company.
In most cases it can be easily calculated by multiplying the share price with the amount of outstanding shares.

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