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EVERSOURCE ENERGY - Quarter Report: 2016 September (Form 10-Q)




 
eversourcea01.jpg
 

UNITED STATES SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549

FORM 10-Q

x
QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE
SECURITIES EXCHANGE ACT OF 1934
 
For the Quarterly Period Ended September 30, 2016
 
or
¨

TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE     
SECURITIES EXCHANGE ACT OF 1934
 

For the transition period from ____________ to ____________


Commission
File Number
Registrant; State of Incorporation;
Address; and Telephone Number
I.R.S. Employer
Identification No.
 
 
 
1-5324
EVERSOURCE ENERGY
(a Massachusetts voluntary association)
300 Cadwell Drive
Springfield, Massachusetts 01104
Telephone:  (800) 286-5000
04-2147929
 
 
 
0-00404
THE CONNECTICUT LIGHT AND POWER COMPANY
(a Connecticut corporation)
107 Selden Street
Berlin, Connecticut 06037-1616
Telephone:  (800) 286-5000
06-0303850
 
 
 
1-02301
NSTAR ELECTRIC COMPANY
(a Massachusetts corporation)
800 Boylston Street
Boston, Massachusetts 02199
Telephone:  (800) 286-5000
04-1278810
 
 
 
1-6392
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
02-0181050
 
 
 
0-7624
WESTERN MASSACHUSETTS ELECTRIC COMPANY
(a Massachusetts corporation)
300 Cadwell Drive
Springfield, Massachusetts 01104
Telephone:  (800) 286-5000
04-1961130
 
 
 


 
 


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
 
x
¨

Indicate by check mark whether the registrants have submitted electronically and posted on its corporate Web sites, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrants were required to submit and post such files).
 
Yes
No
 
x
¨

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, or a non-accelerated filer.  See definition of “accelerated filer” and “large accelerated filer” in Rule 12b-2 of the Exchange Act.  (Check one):
 
Large
Accelerated Filer
 
Accelerated
Filer
 
Non-accelerated
Filer
 
 
 
 
 
 
Eversource Energy
x
 
¨
 
¨
The Connecticut Light and Power Company
¨
 
¨
 
x
NSTAR Electric Company
¨
 
¨
 
x
Public Service Company of New Hampshire
¨
 
¨
 
x
Western Massachusetts Electric Company
¨
 
¨
 
x

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

Indicate the number of shares outstanding of each of the issuers’ classes of common stock, as of the latest practicable date:
Company - Class of Stock
Outstanding as of October 31, 2016
Eversource Energy
Common shares, $5.00 par value
316,885,808 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
100 shares
 
 
Public Service Company of New Hampshire
Common stock, $1.00 par value
301 shares
 
 
Western Massachusetts Electric Company
Common stock, $25.00 par value
434,653 shares

Eversource Energy holds all of the 6,035,205 shares, 100 shares, 301 shares, and 434,653 shares of the outstanding common stock of The Connecticut Light and Power Company, NSTAR Electric Company, Public Service Company of New Hampshire and Western Massachusetts Electric Company, respectively.

NSTAR Electric Company, Public Service Company of New Hampshire and Western Massachusetts Electric Company 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, Public Service Company of New Hampshire, and Western Massachusetts Electric Company 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 or 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 and other subsidiaries, which primarily includes our unregulated businesses, HWP Company, The Rocky River Realty Company (a real estate subsidiary), and the consolidated operations of CYAPC and YAEC
CL&P
The Connecticut Light and Power Company
NSTAR Electric
NSTAR Electric Company
PSNH
Public Service Company of New Hampshire
WMECO
Western Massachusetts Electric Company
NSTAR Gas
NSTAR Gas Company
Yankee Gas
Yankee Gas Services Company
NPT
Northern Pass Transmission LLC
Eversource Service
Eversource Energy Service Company
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, PSNH, and WMECO, the natural gas distribution businesses of Yankee Gas and NSTAR Gas, the generation activities of PSNH and WMECO, and NPT
 
 
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/(Loss)
ARO
Asset Retirement Obligation
C&LM
Conservation and Load Management
CfD
Contract for Differences
Clean Air Project
The construction of a wet flue gas desulphurization system, known as “scrubber technology,” to reduce mercury emissions of the Merrimack coal-fired generation station in Bow, New Hampshire
Clean Energy Connect Project
The Clean Energy Connect project is a planned transmission, wind and hydro generation project that Eversource plans to co-develop with experienced renewable generation companies.
CO2
Carbon dioxide
CPSL
Capital Projects Scheduling List
CTA
Competitive Transition Assessment
CWIP
Construction Work in Progress
EDC
Electric distribution company
EPS
Earnings Per Share
ERISA
Employee Retirement Income Security Act of 1974
ESOP
Employee Stock Ownership Plan
ESPP
Employee Share Purchase Plan

i



Eversource 2015 Form 10-K
The Eversource Energy and Subsidiaries 2015 combined Annual Report on Form 10-K as filed with the SEC
FERC ALJ
FERC Administrative Law Judge
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
McF
Million cubic feet
MGP
Manufactured Gas Plant
MMBtu
One million British thermal units
Moody’s
Moody’s Investors Services, Inc.
MW
Megawatt
MWh
Megawatt-Hours
NEEWS
New England East-West Solution
Northern Pass
The high voltage direct current transmission line project from Canada into New Hampshire
NOx
Nitrogen oxides
PAM
Pension and PBOP Rate Adjustment Mechanism
PBOP
Postretirement Benefits Other Than Pension
PBOP Plan
Postretirement Benefits Other Than Pension Plan that provides certain retiree benefits, primarily medical, dental and life insurance
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 and generation business segment excluding the wholesale transmission segment
RNS
Regional Network Service
ROE
Return on Equity
RRB
Rate Reduction Bond or Rate Reduction Certificate
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
SIP
Simplified Incentive Plan
SO2
Sulfur dioxide
SS
Standard service
TCAM
Transmission Cost Adjustment Mechanism
TSA
Transmission Service Agreement
UI
The United Illuminating Company



ii



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

TABLE OF CONTENTS
 
Page
PART I – FINANCIAL INFORMATION
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
PART II – OTHER INFORMATION
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 

iii




EVERSOURCE ENERGY AND SUBSIDIARIES
CONDENSED CONSOLIDATED BALANCE SHEETS
(Unaudited)
(Thousands of Dollars)
September 30, 2016
 
December 31, 2015
 
 
 
 
ASSETS
 

 
 
Current Assets:
 

 
 
Cash and Cash Equivalents
$
40,056

 
$
23,947

Receivables, Net
963,279

 
775,480

Unbilled Revenues
187,749

 
202,647

Taxes Receivable
4,527

 
305,359

Fuel, Materials, Supplies and Inventory
311,051

 
336,476

Regulatory Assets
752,378

 
845,843

Prepayments and Other Current Assets
155,612

 
129,034

Total Current Assets
2,414,652

 
2,618,786

 
 
 
 
Property, Plant and Equipment, Net
20,807,943

 
19,892,441

 
 
 
 
Deferred Debits and Other Assets:
 

 
 

Regulatory Assets
3,469,879

 
3,737,960

Goodwill
3,519,401

 
3,519,401

Marketable Securities
525,809

 
516,478

Other Long-Term Assets
344,653

 
295,243

Total Deferred Debits and Other Assets
7,859,742

 
8,069,082

 
 
 
 
Total Assets
$
31,082,337

 
$
30,580,309

 
 
 
 
LIABILITIES AND CAPITALIZATION
 
 
 
Current Liabilities:
 
 
 
Notes Payable
$
734,500

 
$
1,160,953

Long-Term Debt - Current Portion
373,883

 
228,883

Accounts Payable
679,505

 
813,646

Obligations to Third Party Suppliers
166,845

 
128,564

Regulatory Liabilities
160,442

 
107,759

Other Current Liabilities
526,853

 
549,985

Total Current Liabilities
2,642,028

 
2,989,790

 
 
 
 
Deferred Credits and Other Liabilities:
 
 
 
Accumulated Deferred Income Taxes
5,442,856

 
5,147,678

Regulatory Liabilities
550,162

 
513,595

Derivative Liabilities
427,382

 
337,102

Accrued Pension, SERP and PBOP
1,116,240

 
1,407,288

Other Long-Term Liabilities
875,589

 
871,499

Total Deferred Credits and Other Liabilities
8,412,229

 
8,277,162

 
 
 
 
Capitalization:
 
 
 
Long-Term Debt
9,235,128

 
8,805,574

 
 
 
 
Noncontrolling Interest - Preferred Stock of Subsidiaries
155,568

 
155,568

 
 
 
 
Equity:
 
 
 
Common Shareholders’ Equity:
 
 
 
Common Shares
1,669,392

 
1,669,313

Capital Surplus, Paid In
6,256,580

 
6,262,368

Retained Earnings
3,087,006

 
2,797,355

Accumulated Other Comprehensive Loss
(65,617
)
 
(66,844
)
Treasury Stock
(309,977
)
 
(309,977
)
Common Shareholders’ Equity
10,637,384

 
10,352,215

Total Capitalization
20,028,080

 
19,313,357

 
 
 
 
Total Liabilities and Capitalization
$
31,082,337

 
$
30,580,309


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 September 30,
 
For the Nine Months Ended September 30,
(Thousands of Dollars, Except Share Information)
2016
 
2015
 
2016
 
2015
 
 
 
 
 
 
 
 
Operating Revenues
$
2,039,706

 
$
1,933,105

 
$
5,862,525

 
$
6,263,597

 
 
 
 
 
 
 
 
Operating Expenses:
 
 
 
 
 
 
 
Purchased Power, Fuel and Transmission
665,810

 
702,640

 
2,001,929

 
2,549,807

Operations and Maintenance
324,734

 
327,283

 
965,584

 
977,306

Depreciation
181,288

 
167,884

 
531,781

 
495,389

Amortization of Regulatory Assets/(Liabilities), Net
43,942

 
(16,851
)
 
56,223

 
42,587

Energy Efficiency Programs
149,121

 
132,107

 
405,962

 
380,559

Taxes Other Than Income Taxes
164,942

 
150,804

 
479,219

 
439,221

Total Operating Expenses
1,529,837

 
1,463,867

 
4,440,698

 
4,884,869

Operating Income
509,869

 
469,238

 
1,421,827

 
1,378,728

Interest Expense
99,865

 
92,534

 
298,568

 
279,635

Other Income, Net
13,641

 
5,241

 
23,689

 
23,866

Income Before Income Tax Expense
423,645

 
381,945

 
1,146,948

 
1,122,959

Income Tax Expense
156,446

 
144,146

 
428,186

 
420,640

Net Income
267,199

 
237,799

 
718,762

 
702,319

Net Income Attributable to Noncontrolling Interests
1,880

 
1,879

 
5,639

 
5,639

Net Income Attributable to Common Shareholders
$
265,319

 
$
235,920

 
$
713,123

 
$
696,680

 
 
 
 
 
 
 
 
Basic Earnings Per Common Share
$
0.83

 
$
0.74

 
$
2.24

 
$
2.20

 
 
 
 
 
 
 
 
Diluted Earnings Per Common Share
$
0.83

 
$
0.74

 
$
2.24

 
$
2.19

 
 
 
 
 
 
 
 
Dividends Declared Per Common Share
$
0.45

 
$
0.42

 
$
1.34

 
$
1.25

 
 
 
 
 
 
 
 
Weighted Average Common Shares Outstanding:
 
 
 
 
 
 
 
Basic
317,787,836

 
317,452,212

 
317,696,823

 
317,296,107

Diluted
318,577,079

 
318,405,269

 
318,511,609

 
318,396,042


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 September 30,
 
For the Nine Months Ended September 30,
(Thousands of Dollars)
2016
 
2015
 
2016
 
2015
 
 
 
 
 
 
 
 
Net Income
$
267,199

 
$
237,799

 
$
718,762

 
$
702,319

Other Comprehensive (Loss)/Income, Net of Tax:
 
 
 
 
 
 
 
Qualified Cash Flow Hedging Instruments
534

 
526

 
1,602

 
1,544

Changes in Unrealized Gains/(Losses) on
Marketable Securities
946

 
(2,803
)
 
2,271

 
(3,919
)
Changes in Funded Status of Pension,
SERP and PBOP Benefit Plans
(1,733
)
 
764

 
(2,646
)
 
2,838

Other Comprehensive (Loss)/Income, Net of Tax
(253
)
 
(1,513
)
 
1,227

 
463

Comprehensive Income Attributable to
Noncontrolling Interests
(1,880
)
 
(1,879
)
 
(5,639
)
 
(5,639
)
Comprehensive Income Attributable to
Common Shareholders
$
265,066

 
$
234,407

 
$
714,350

 
$
697,143


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

2



EVERSOURCE ENERGY AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)
 
For the Nine Months Ended September 30,
(Thousands of Dollars)
2016
 
2015




Operating Activities:
 

 
Net Income
$
718,762


$
702,319

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

 
Depreciation
531,781


495,389

Deferred Income Taxes
301,413


153,353

Pension, SERP and PBOP Expense
31,627


71,802

Pension and PBOP Contributions
(121,854
)

(162,880
)
Regulatory Overrecoveries, Net
152,808


31,874

Amortization of Regulatory Assets, Net
56,223


42,587

Other
(27,671
)

(39,822
)
Changes in Current Assets and Liabilities:
 

 
Receivables and Unbilled Revenues, Net
(191,454
)

(148,442
)
Fuel, Materials, Supplies and Inventory
25,425


47,380

Taxes Receivable/Accrued, Net
347,898


383,047

Accounts Payable
(121,513
)

(233,660
)
Other Current Assets and Liabilities, Net
(53,077
)

8,370

Net Cash Flows Provided by Operating Activities
1,650,368


1,351,317





Investing Activities:
 

 
Investments in Property, Plant and Equipment
(1,359,171
)

(1,177,285
)
Proceeds from Sales of Marketable Securities
444,209


556,582

Purchases of Marketable Securities
(437,197
)

(535,044
)
Other Investing Activities
(9,463
)

(2,769
)
Net Cash Flows Used in Investing Activities
(1,361,622
)

(1,158,516
)




Financing Activities:
 

 
Cash Dividends on Common Shares
(423,471
)

(397,363
)
Cash Dividends on Preferred Stock
(5,639
)

(5,639
)
Decrease in Notes Payable
(426,453
)

(387,575
)
Issuance of Long-Term Debt
800,000


825,000

Retirements of Long-Term Debt
(200,000
)

(216,700
)
Other Financing Activities
(17,074
)

(13,446
)
Net Cash Flows Used in Financing Activities
(272,637
)

(195,723
)
Net Increase/(Decrease) in Cash and Cash Equivalents
16,109


(2,922
)
Cash and Cash Equivalents - Beginning of Period
23,947


38,703

Cash and Cash Equivalents - End of Period
$
40,056


$
35,781


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



3




THE CONNECTICUT LIGHT AND POWER COMPANY
CONDENSED BALANCE SHEETS
(Unaudited)
(Thousands of Dollars)
September 30, 2016
 
December 31, 2015
 
 
 
 
ASSETS
 
 
 
Current Assets:
 
 
 
Cash
$
8,607

 
$
1,057

Receivables, Net
425,421

 
352,536

Accounts Receivable from Affiliated Companies
24,012

 
21,214

Unbilled Revenues
87,771

 
99,879

Taxes Receivable

 
137,643

Materials and Supplies
51,598

 
43,124

Regulatory Assets
267,733

 
268,318

Prepaid Property Taxes
54,619

 
18,019

Prepayments and Other Current Assets
15,439

 
14,215

Total Current Assets
935,200

 
956,005

 
 
 
 
Property, Plant and Equipment, Net
7,453,200

 
7,156,809

 
 
 
 
Deferred Debits and Other Assets:
 
 
 
Regulatory Assets
1,398,610

 
1,369,028

Other Long-Term Assets
131,049

 
111,115

Total Deferred Debits and Other Assets
1,529,659

 
1,480,143

 
 
 
 
Total Assets
$
9,918,059

 
$
9,592,957

 
 
 
 
LIABILITIES AND CAPITALIZATION
 
 
 
Current Liabilities:
 
 
 
Notes Payable to Eversource Parent
$
108,500

 
$
277,400

Long-Term Debt - Current Portion
250,000

 

Accounts Payable
228,744

 
267,764

Accounts Payable to Affiliated Companies
63,718

 
66,456

Obligations to Third Party Suppliers
66,952

 
60,746

Accrued Taxes
71,238

 
12,068

Regulatory Liabilities
75,654

 
61,155

Derivative Liabilities
85,342

 
91,820

Other Current Liabilities
94,762

 
98,563

Total Current Liabilities
1,044,910

 
935,972

 
 
 
 
Deferred Credits and Other Liabilities:
 
 
 
Accumulated Deferred Income Taxes
1,931,369

 
1,820,865

Regulatory Liabilities
89,599

 
74,830

Derivative Liabilities
426,053

 
336,189

Accrued Pension, SERP and PBOP
274,456

 
271,056

Other Long-Term Liabilities
130,477

 
133,446

Total Deferred Credits and Other Liabilities
2,851,954

 
2,636,386

 
 
 
 
Capitalization:
 
 
 
Long-Term Debt
2,515,444

 
2,763,682

 
 
 
 
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
2,056,402

 
1,910,663

Retained Earnings
1,272,962

 
1,170,278

Accumulated Other Comprehensive Loss
(165
)
 
(576
)
Common Stockholder’s Equity
3,389,551

 
3,140,717

Total Capitalization
6,021,195

 
6,020,599

 
 
 
 
Total Liabilities and Capitalization
$
9,918,059

 
$
9,592,957


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

4



THE CONNECTICUT LIGHT AND POWER COMPANY
CONDENSED STATEMENTS OF INCOME
(Unaudited)
 
For the Three Months Ended September 30,
 
For the Nine Months Ended September 30,
(Thousands of Dollars)
2016
 
2015
 
2016
 
2015
 
 
 
 
 
 
 
 
Operating Revenues
$
760,037

 
$
704,262

 
$
2,175,141

 
$
2,175,733

 
 
 
 
 
 
 
 
Operating Expenses:
 
 
 
 
 
 
 
Purchased Power and Transmission
253,509

 
274,762

 
760,613

 
861,562

Operations and Maintenance
123,034

 
122,280

 
356,409

 
358,324

Depreciation
57,675

 
54,809

 
172,175

 
159,903

Amortization of Regulatory Assets/(Liabilities), Net
23,418

 
(22,859
)
 
30,308

 
17,917

Energy Efficiency Programs
44,381

 
42,590

 
117,969

 
119,360

Taxes Other Than Income Taxes
81,948

 
71,563

 
227,981

 
201,743

Total Operating Expenses
583,965

 
543,145

 
1,665,455

 
1,718,809

Operating Income
176,072

 
161,117

 
509,686

 
456,924

Interest Expense
36,083

 
36,716

 
108,561

 
109,463

Other Income, Net
3,669

 
2,356

 
10,881

 
8,576

Income Before Income Tax Expense
143,658

 
126,757

 
412,006

 
356,037

Income Tax Expense
57,026

 
46,569

 
155,453

 
127,845

Net Income
$
86,632

 
$
80,188

 
$
256,553

 
$
228,192


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


CONDENSED STATEMENTS OF COMPREHENSIVE INCOME
(Unaudited)
 
For the Three Months Ended September 30,
 
For the Nine Months Ended September 30,
(Thousands of Dollars)
2016
 
2015
 
2016
 
2015
 
 
 
 
 
 
 
 
Net Income
$
86,632

 
$
80,188

 
$
256,553

 
$
228,192

Other Comprehensive Income, Net of Tax:
 
 
 
 
 
 
 
Qualified Cash Flow Hedging Instruments
111

 
111

 
333

 
333

Changes in Unrealized Gains/(Losses)
  on Marketable Securities
33

 
(98
)
 
78

 
(137
)
Other Comprehensive Income, Net of Tax
144

 
13

 
411

 
196

Comprehensive Income
$
86,776

 
$
80,201

 
$
256,964

 
$
228,388


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


5



THE CONNECTICUT LIGHT AND POWER COMPANY
CONDENSED STATEMENTS OF CASH FLOWS
(Unaudited)
 
For the Nine Months Ended September 30,
(Thousands of Dollars)
2016
 
2015
 
 
 
 
Operating Activities:
 
 
 
Net Income
$
256,553

 
$
228,192

Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
 
 
 
Depreciation
172,175

 
159,903

Deferred Income Taxes
109,637

 
(11,011
)
Pension, SERP, and PBOP Expense, Net of PBOP Contributions
4,825

 
10,654

Regulatory Overrecoveries, Net
33,492

 
12,504

Amortization of Regulatory Assets, Net
30,308

 
17,917

Other
(14,873
)
 
(13,048
)
Changes in Current Assets and Liabilities:
 
 
 
Receivables and Unbilled Revenues, Net
(100,074
)
 
(91,842
)
Taxes Receivable/Accrued, Net
197,422

 
160,031

Accounts Payable
(30,168
)
 
(20,485
)
Other Current Assets and Liabilities, Net
(44,908
)
 
(31,044
)
Net Cash Flows Provided by Operating Activities
614,389

 
421,771

 
 
 
 
Investing Activities:
 
 
 
Investments in Property, Plant and Equipment
(438,518
)
 
(359,339
)
Proceeds from the Sale of  Property, Plant and Equipment
9,047

 

Other Investing Activities
310

 
(740
)
Net Cash Flows Used in Investing Activities
(429,161
)
 
(360,079
)
 
 
 
 
Financing Activities:
 
 
 
Cash Dividends on Common Stock
(149,700
)
 
(147,000
)
Cash Dividends on Preferred Stock
(4,169
)
 
(4,169
)
Capital Contributions from Eversource Parent
145,700

 
105,000

Issuance of Long-Term Debt

 
300,000

Retirement of Long-Term Debt

 
(162,000
)
Decrease in Notes Payable to Eversource Parent
(168,900
)
 
(133,400
)
Other Financing Activities
(609
)
 
(9,072
)
Net Cash Flows Used in Financing Activities
(177,678
)
 
(50,641
)
Net Increase in Cash
7,550

 
11,051

Cash - Beginning of Period
1,057

 
2,356

Cash - End of Period
$
8,607

 
$
13,407


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




6




NSTAR ELECTRIC COMPANY AND SUBSIDIARY
CONDENSED CONSOLIDATED BALANCE SHEETS
(Unaudited)
(Thousands of Dollars)
September 30, 2016
 
December 31, 2015
 
 
 
 
ASSETS
 

 
 

Current Assets:
 
 
 
Cash and Cash Equivalents
$
6,154

 
$
3,346

Receivables, Net
300,692

 
229,936

Accounts Receivable from Affiliated Companies
8,891

 
4,034

Unbilled Revenues
40,370

 
29,464

Taxes Receivable

 
70,236

Materials, Supplies and Inventory
44,827

 
75,487

Regulatory Assets
259,213

 
348,408

Prepayments and Other Current Assets
11,025

 
11,448

Total Current Assets
671,172

 
772,359

 
 
 
 
Property, Plant and Equipment, Net
5,875,874

 
5,655,458

 
 
 
 
Deferred Debits and Other Assets:
 
 
 
Regulatory Assets
1,043,237

 
1,112,977

Other Long-Term Assets
118,924

 
62,467

Total Deferred Debits and Other Assets
1,162,161

 
1,175,444

 
 
 
 
Total Assets
$
7,709,207

 
$
7,603,261

 
 
 
 
LIABILITIES AND CAPITALIZATION
 
 
 
Current Liabilities:
 
 
 
Notes Payable
$
36,000

 
$
62,500

Long-Term Debt - Current Portion

 
200,000

Accounts Payable
194,894

 
228,250

Accounts Payable to Affiliated Companies
64,912

 
38,648

Obligations to Third Party Suppliers
87,183

 
56,718

Renewable Portfolio Standards Compliance Obligations
56,741

 
104,847

Accrued Taxes
78,429

 
6,585

Regulatory Liabilities
48,842

 
3,281

Other Current Liabilities
56,879

 
65,422

Total Current Liabilities
623,880

 
766,251

 
 
 
 
Deferred Credits and Other Liabilities:
 
 
 
Accumulated Deferred Income Taxes
1,795,763

 
1,760,339

Regulatory Liabilities
357,168

 
264,352

Accrued Pension, SERP and PBOP
91,788

 
209,153

Other Long-Term Liabilities
125,137

 
120,939

Total Deferred Credits and Other Liabilities
2,369,856

 
2,354,783

 
 
 
 
Capitalization:
 
 
 
Long-Term Debt
2,077,955

 
1,829,766

 
 
 
 
Preferred Stock Not Subject to Mandatory Redemption
43,000

 
43,000

 
 
 
 
Common Stockholder’s Equity:
 
 
 
Common Stock

 

Capital Surplus, Paid In
1,020,378

 
995,378

Retained Earnings
1,573,624

 
1,613,538

Accumulated Other Comprehensive Income
514

 
545

Common Stockholder’s Equity
2,594,516

 
2,609,461

Total Capitalization
4,715,471

 
4,482,227

 
 
 
 
Total Liabilities and Capitalization
$
7,709,207


$
7,603,261


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

7



NSTAR ELECTRIC COMPANY AND SUBSIDIARY
CONDENSED CONSOLIDATED STATEMENTS OF INCOME
(Unaudited)
 
For the Three Months Ended September 30,
 
For the Nine Months Ended September 30,
(Thousands of Dollars)
2016
 
2015
 
2016
 
2015
 
 
 
 
 
 
 
 
Operating Revenues
$
780,462

 
$
750,724

 
$
1,985,979

 
$
2,134,728

 
 
 
 
 
 
 
 
Operating Expenses:
 

 
 

 
 

 
 

Purchased Power and Transmission
291,382

 
299,040

 
764,907

 
984,035

Operations and Maintenance
96,282

 
83,486

 
279,932

 
228,740

Depreciation
54,695

 
49,101

 
159,151

 
146,818

Amortization of Regulatory Assets/(Liabilities), Net
9,621

 
2,257

 
18,275

 
(10,643
)
Energy Efficiency Programs
84,717

 
67,693

 
212,882

 
164,843

Taxes Other Than Income Taxes
35,050

 
34,982

 
101,800

 
95,821

Total Operating Expenses
571,747

 
536,559

 
1,536,947

 
1,609,614

Operating Income
208,715

 
214,165

 
449,032

 
525,114

Interest Expense
21,101

 
18,992

 
62,206

 
57,218

Other Income, Net
5,022

 
513

 
7,524

 
3,649

Income Before Income Tax Expense
192,636

 
195,686

 
394,350

 
471,545

Income Tax Expense
75,440

 
77,062

 
154,493

 
187,397

Net Income
$
117,196

 
$
118,624

 
$
239,857

 
$
284,148


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 September 30,
 
For the Nine Months Ended September 30,
(Thousands of Dollars)
2016
 
2015
 
2016
 
2015
 
 
 
 
 
 
 
 
Net Income
$
117,196

 
$
118,624

 
$
239,857

 
$
284,148

Other Comprehensive Loss, Net of Tax:
 
 
 
 
 
 
 
  Changes in Funded Status of SERP Benefit Plan
(10
)
 
(2
)
 
(31
)
 
(184
)
Other Comprehensive Loss, Net of Tax
(10
)
 
(2
)
 
(31
)
 
(184
)
Comprehensive Income
$
117,186

 
$
118,622

 
$
239,826

 
$
283,964


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


8



NSTAR ELECTRIC COMPANY AND SUBSIDIARY
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)
 
For the Nine Months Ended September 30,
(Thousands of Dollars)
2016
 
2015
 
 
 
 
Operating Activities:
 

 
 

Net Income
$
239,857

 
$
284,148

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

 
 

Depreciation
159,151

 
146,818

Deferred Income Taxes
40,960

 
54,188

Pension and PBOP Contributions, Net of Pension, SERP and PBOP Expense
(25,364
)
 
(1,138
)
Regulatory Over/(Under) Recoveries, Net
131,774

 
(48,903
)
Amortization of Regulatory Assets/(Liabilities), Net
18,275

 
(10,643
)
Other
(20,088
)
 
(34,223
)
Changes in Current Assets and Liabilities:
 

 
 

Receivables and Unbilled Revenues, Net
(103,444
)
 
(84,587
)
Materials, Supplies and Inventory
30,659

 
21,863

Taxes Receivable/Accrued, Net
141,379

 
207,516

Accounts Payable
(22,913
)
 
(79,449
)
Other Current Assets and Liabilities, Net
(25,942
)
 
46,671

Net Cash Flows Provided by Operating Activities
564,304

 
502,261

 
 
 
 
Investing Activities:
 

 
 

Investments in Property, Plant and Equipment
(327,731
)
 
(314,055
)
Net Cash Flows Used in Investing Activities
(327,731
)
 
(314,055
)
 
 
 
 
Financing Activities:
 

 
 

Cash Dividends on Common Stock
(278,300
)
 
(148,500
)
Cash Dividends on Preferred Stock
(1,470
)
 
(1,470
)
Decrease in Notes Payable
(26,500
)
 
(43,500
)
Issuance of Long-Term Debt
250,000

 

Retirements of Long-Term Debt
(200,000
)
 
(4,700
)
Capital Contributions from Eversource Parent
25,000

 

Other Financing Activities
(2,495
)
 

Net Cash Flows Used in Financing Activities
(233,765
)
 
(198,170
)
Increase/(Decrease) in Cash and Cash Equivalents
2,808

 
(9,964
)
Cash and Cash Equivalents - Beginning of Period
3,346

 
12,773

Cash and Cash Equivalents - End of Period
$
6,154

 
$
2,809


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


9




PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARY
CONDENSED CONSOLIDATED BALANCE SHEETS
(Unaudited)
(Thousands of Dollars)
September 30, 2016
 
December 31, 2015
 
 
 
 
ASSETS
 
 
 
Current Assets:
 
 
 
Cash
$
4,436

 
$
1,733

Receivables, Net
97,613

 
77,546

Accounts Receivable from Affiliated Companies
4,190

 
2,352

Unbilled Revenues
39,168

 
38,207

Taxes Receivable
7,913

 
43,128

Fuel, Materials, Supplies and Inventory
160,882

 
156,868

Regulatory Assets
100,598

 
104,971

Prepayments and Other Current Assets
4,271

 
24,302

Total Current Assets
419,071

 
449,107

 
 
 
 
Property, Plant and Equipment, Net
2,973,057

 
2,855,363

 
 
 
 
Deferred Debits and Other Assets:
 
 
 
Regulatory Assets
252,609

 
257,873

Other Long-Term Assets
35,793

 
34,176

Total Deferred Debits and Other Assets
288,402

 
292,049

 
 
 
 
Total Assets
$
3,680,530

 
$
3,596,519

 
 
 
 
LIABILITIES AND CAPITALIZATION
 
 
 
Current Liabilities:
 
 
 
Notes Payable to Eversource Parent
$
107,500

 
$
231,300

Long-Term Debt - Current Portion
70,000

 

Accounts Payable
76,762

 
87,925

Accounts Payable to Affiliated Companies
34,350

 
24,214

Regulatory Liabilities
5,519

 
6,898

Other Current Liabilities
48,339

 
43,921

Total Current Liabilities
342,470

 
394,258

 
 
 
 
Deferred Credits and Other Liabilities:
 
 
 
Accumulated Deferred Income Taxes
774,737

 
705,894

Regulatory Liabilities
46,428

 
47,851

Accrued Pension, SERP and PBOP
84,547

 
89,579

Other Long-Term Liabilities
50,249

 
50,746

Total Deferred Credits and Other Liabilities
955,961

 
894,070

 
 
 
 
Capitalization:
 
 
 
Long-Term Debt
1,001,790

 
1,071,017

 
 
 
 
Common Stockholder’s Equity:
 
 
 
Common Stock

 

Capital Surplus, Paid In
843,134

 
748,634

Retained Earnings
542,530

 
494,901

Accumulated Other Comprehensive Loss
(5,355
)
 
(6,361
)
Common Stockholder’s Equity
1,380,309

 
1,237,174

Total Capitalization
2,382,099

 
2,308,191

 
 
 
 
Total Liabilities and Capitalization
$
3,680,530

 
$
3,596,519


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


10



PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARY
CONDENSED CONSOLIDATED STATEMENTS OF INCOME
(Unaudited)
 
For the Three Months Ended September 30,
 
For the Nine Months Ended September 30,
(Thousands of Dollars)
2016
 
2015
 
2016
 
2015
 
 
 
 
 
 
 
 
Operating Revenues
$
266,946

 
$
234,364

 
$
727,753

 
$
761,086

 
 
 
 
 
 
 
 
Operating Expenses:
 
 
 
 
 
 
 
Purchased Power, Fuel and Transmission
59,833

 
53,017

 
155,700

 
200,533

Operations and Maintenance
64,183

 
65,190

 
187,184

 
200,085

Depreciation
29,646

 
26,592

 
86,524

 
77,989

Amortization of Regulatory Assets, Net
14,158

 
1,967

 
14,490

 
29,148

Energy Efficiency Programs
3,983

 
3,873

 
10,862

 
11,001

Taxes Other Than Income Taxes
20,460

 
20,104

 
64,543

 
61,435

Total Operating Expenses
192,263

 
170,743

 
519,303

 
580,191

Operating Income
74,683

 
63,621

 
208,450

 
180,895

Interest Expense
12,397

 
11,647

 
37,386

 
34,582

Other Income, Net
574

 
685

 
1,007

 
2,313

Income Before Income Tax Expense
62,860

 
52,659

 
172,071

 
148,626

Income Tax Expense
24,345

 
20,158

 
66,242

 
56,135

Net Income
$
38,515

 
$
32,501

 
$
105,829

 
$
92,491


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 September 30,
 
For the Nine Months Ended September 30,
(Thousands of Dollars)
2016
 
2015
 
2016
 
2015
 
 
 
 
 
 
 
 
Net Income
$
38,515

 
$
32,501

 
$
105,829

 
$
92,491

Other Comprehensive Income, Net of Tax:
 
 
 
 
 
 
 
Qualified Cash Flow Hedging Instruments
290

 
291

 
871

 
872

Changes in Unrealized Gains/(Losses)
   on Marketable Securities
56

 
(169
)
 
135

 
(236
)
Other Comprehensive Income, Net of Tax
346

 
122

 
1,006

 
636

Comprehensive Income
$
38,861

 
$
32,623

 
$
106,835

 
$
93,127


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


11



PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARY
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)
 
For the Nine Months Ended September 30,
(Thousands of Dollars)
2016
 
2015
 
 
 
 
Operating Activities:
 
 
 
Net Income
$
105,829

 
$
92,491

Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
 
 
 
Depreciation
86,524

 
77,989

Deferred Income Taxes
74,522

 
42,563

Regulatory (Under)/Over Recoveries, Net
(4,289
)
 
2,639

Amortization of Regulatory Assets, Net
14,490

 
29,148

Other
(12,660
)
 
10,894

Changes in Current Assets and Liabilities:
 
 
 
Receivables and Unbilled Revenues, Net
(28,754
)
 
(25,126
)
Fuel, Materials, Supplies and Inventory
(4,014
)
 
4,156

Taxes Receivable/Accrued, Net
33,589

 
9,026

Accounts Payable
14,508

 
(20,058
)
Other Current Assets and Liabilities, Net
26,207

 
20,141

Net Cash Flows Provided by Operating Activities
305,952

 
243,863

 
 
 
 
Investing Activities:
 
 
 
Investments in Property, Plant and Equipment
(215,804
)
 
(209,522
)
Other Investing Activities
272

 
241

Net Cash Flows Used in Investing Activities
(215,532
)
 
(209,281
)
 
 
 
 
Financing Activities:
 
 
 
Cash Dividends on Common Stock
(58,200
)
 
(79,500
)
Capital Contributions from Eversource Parent
94,500

 

(Decrease)/Increase in Notes Payable to Eversource Parent
(123,800
)
 
46,800

Other Financing Activities
(217
)
 
(268
)
Net Cash Flows Used in Financing Activities
(87,717
)
 
(32,968
)
Net Increase in Cash
2,703

 
1,614

Cash - Beginning of Period
1,733

 
489

Cash - End of Period
$
4,436

 
$
2,103


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


12




WESTERN MASSACHUSETTS ELECTRIC COMPANY
CONDENSED BALANCE SHEETS
(Unaudited)
(Thousands of Dollars)
September 30, 2016
 
December 31, 2015
 
 
 
 
ASSETS
 
 
 
Current Assets:
 
 
 
Cash
$

 
$
834

Receivables, Net
59,685

 
50,912

Accounts Receivable from Affiliated Companies
11,962

 
18,633

Unbilled Revenues
12,169

 
15,065

Taxes Receivable
1

 
33,407

Materials, Supplies and Inventory
8,068

 
5,992

Regulatory Assets
54,081

 
56,166

Prepayments and Other Current Assets
1,374

 
1,890

Total Current Assets
147,340

 
182,899

 
 
 
 
Property, Plant and Equipment, Net
1,643,335

 
1,575,306

 
 
 
 
Deferred Debits and Other Assets:
 
 
 
Regulatory Assets
128,308

 
135,010

Other Long-Term Assets
28,165

 
24,875

Total Deferred Debits and Other Assets
156,473

 
159,885

 
 
 
 
Total Assets
$
1,947,148

 
$
1,918,090

 
 
 
 
LIABILITIES AND CAPITALIZATION
 
 
 
Current Liabilities:
 
 
 
Notes Payable to Eversource Parent
$
48,200

 
$
143,400

Accounts Payable
38,191

 
58,364

Accounts Payable to Affiliated Companies
14,501

 
19,896

Obligations to Third Party Suppliers
11,444

 
9,654

Renewable Portfolio Standards Compliance Obligations
16,314

 
6,395

Regulatory Liabilities
12,384

 
13,122

Other Current Liabilities
12,258

 
13,878

Total Current Liabilities
153,292

 
264,709

 
 
 
 
Deferred Credits and Other Liabilities:
 

 
 
Accumulated Deferred Income Taxes
486,137

 
470,539

Regulatory Liabilities
14,422

 
11,597

Accrued Pension, SERP and PBOP
16,032

 
19,515

Other Long-Term Liabilities
42,072

 
36,819

Total Deferred Credits and Other Liabilities
558,663

 
538,470

 
 
 
 
Capitalization:
 

 
 
Long-Term Debt
566,657

 
517,329

 
 
 
 
Common Stockholder’s Equity:
 

 
 
Common Stock
10,866

 
10,866

Capital Surplus, Paid In
444,399

 
391,398

Retained Earnings
215,743

 
198,140

Accumulated Other Comprehensive Loss
(2,472
)
 
(2,822
)
Common Stockholder’s Equity
668,536

 
597,582

Total Capitalization
1,235,193

 
1,114,911

 
 
 
 
Total Liabilities and Capitalization
$
1,947,148

 
$
1,918,090


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


13



WESTERN MASSACHUSETTS ELECTRIC COMPANY
CONDENSED STATEMENTS OF INCOME
(Unaudited)
 
For the Three Months Ended September 30,
 
For the Nine Months Ended September 30,
(Thousands of Dollars)
2016
 
2015
 
2016
 
2015
 
 
 
 
 
 
 
 
Operating Revenues
$
124,042

 
$
125,093

 
$
368,533

 
$
403,151

 
 
 
 
 
 
 
 
Operating Expenses:
 
 
 
 
 
 
 
Purchased Power and Transmission
32,178

 
36,465

 
104,406

 
149,182

Operations and Maintenance
24,125

 
21,762

 
68,018

 
61,651

Depreciation
11,567

 
11,196

 
34,414

 
32,420

Amortization of Regulatory Assets, Net
1,102

 
3,930

 
3,305

 
11,194

Energy Efficiency Programs
12,389

 
12,107

 
33,593

 
32,701

Taxes Other Than Income Taxes
10,609

 
9,599

 
30,440

 
28,430

Total Operating Expenses
91,970

 
95,059

 
274,176

 
315,578

Operating Income
32,072

 
30,034

 
94,357

 
87,573

Interest Expense
6,222

 
5,901

 
18,298

 
19,014

Other Income, Net
179

 
587

 
133

 
2,406

Income Before Income Tax Expense
26,029

 
24,720

 
76,192

 
70,965

Income Tax Expense
10,018

 
9,749

 
30,089

 
28,555

Net Income
$
16,011

 
$
14,971

 
$
46,103

 
$
42,410


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


CONDENSED STATEMENTS OF COMPREHENSIVE INCOME
(Unaudited)
 
For the Three Months Ended September 30,
 
For the Nine Months Ended September 30,
(Thousands of Dollars)
2016
 
2015
 
2016
 
2015
 
 
 
 
 
 
 
 
Net Income
$
16,011

 
$
14,971

 
$
46,103

 
$
42,410

Other Comprehensive Income, Net of Tax:
 

 
 
 
 

 
 
Qualified Cash Flow Hedging Instruments
109

 
101

 
328

 
270

Changes in Unrealized Gains/(Losses)
  on Marketable Securities
9

 
(27
)
 
22

 
(38
)
Other Comprehensive Income, Net of Tax
118

 
74

 
350

 
232

Comprehensive Income
$
16,129

 
$
15,045

 
$
46,453

 
$
42,642


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

14



WESTERN MASSACHUSETTS ELECTRIC COMPANY
CONDENSED STATEMENTS OF CASH FLOWS
(Unaudited)
 
For the Nine Months Ended September 30,
(Thousands of Dollars)
2016
 
2015
 
 
 
 
Operating Activities:
 
 
 
Net Income
$
46,103

 
$
42,410

Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
 
 
 
Depreciation
34,414

 
32,420

Deferred Income Taxes
15,587

 
5,531

Regulatory Overrecoveries, Net
323

 
4,024

Amortization of Regulatory Assets, Net
3,305

 
11,194

Other
(2,532
)
 
(4,500
)
Changes in Current Assets and Liabilities:
 
 
 
Receivables and Unbilled Revenues, Net
1,933

 
(32,664
)
Taxes Receivable/Accrued, Net
36,658

 
24,064

Accounts Payable
(16,240
)
 
(14,018
)
Other Current Assets and Liabilities, Net
5,277

 
(463
)
Net Cash Flows Provided by Operating Activities
124,828

 
67,998

 
 
 
 
Investing Activities:
 
 
 
Investments in Property, Plant and Equipment
(104,811
)
 
(93,705
)
Proceeds from Sales of Marketable Securities
1,934

 
71,110

Purchases of Marketable Securities
(1,894
)
 
(71,625
)
Net Cash Flows Used in Investing Activities
(104,771
)
 
(94,220
)
 
 
 
 
Financing Activities:
 
 
 
Cash Dividends on Common Stock
(28,500
)
 
(27,900
)
Capital Contribution from Eversource Parent
53,000

 

(Decrease)/Increase in Notes Payable to Eversource Parent
(95,200
)
 
104,800

Issuance/(Retirement) of Long-Term Debt
50,000

 
(50,000
)
Other Financing Activities
(191
)
 
(20
)
Net Cash Flows (Used in)/Provided by Financing Activities
(20,891
)
 
26,880

Net (Decrease)/Increase in Cash
(834
)
 
658

Cash - Beginning of Period
834

 

Cash - End of Period
$

 
$
658


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


15



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

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, PSNH, WMECO, Yankee Gas and NSTAR Gas.  Eversource provides energy delivery service to approximately 3.6 million electric and natural gas customers through these six 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 and WMECO 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 2015 Form 10-K, which was filed with the SEC.  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, PSNH’s and WMECO’s financial position as of September 30, 2016 and December 31, 2015, the results of operations and comprehensive income for the three and nine months ended September 30, 2016 and 2015, and the cash flows for the nine months ended September 30, 2016 and 2015.  The results of operations and comprehensive income for the three and nine months ended September 30, 2016 and 2015 and the cash flows for the nine months ended September 30, 2016 and 2015 are not necessarily indicative of the results expected for a full year.  

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

Access Northeast is a natural gas pipeline and storage project (the Project) being developed jointly by Eversource, Spectra Energy Partners, LP (Spectra), and National Grid plc (National Grid) through Algonquin Gas Transmission, LLC (AGT). The Project will enhance the Algonquin and Maritimes & Northeast pipeline systems using existing routes and will include two new LNG storage tanks and liquefaction and vaporization facilities in Acushnet, Massachusetts that will be connected to the Algonquin natural gas pipeline.  Eversource and Spectra each own a 40 percent interest in the Project, with the remaining 20 percent interest owned by National Grid.  The total projected cost for both the pipeline and the LNG storage facilities will be funded in proportion to the respective ownership interest.  Eversource’s cumulative equity investment in the Project as of September 30, 2016 of $28.6 million is presented in Other Long-Term Assets.  

Eversource’s utility subsidiaries’ distribution (including generation) 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 and as a result of the adoption of new accounting guidance.  See Note 1B, “Summary of Significant Accounting Policies – Accounting Standards,” for further information.


16



B.    Accounting Standards
Accounting Standards Issued but not Yet Effective:  In May 2014, the Financial Accounting Standards Board (FASB) issued an Accounting Standards Update (ASU) 2014-9, Revenue from Contracts with Customers, which amends existing revenue recognition guidance and is required to be applied retrospectively (either to each reporting period presented or cumulatively at the date of initial application).  In August 2015, the FASB issued ASU 2015-14, Revenue from Contracts with Customers – Deferral of the Effective Date, which defers the effective date of ASU 2014-9 to the first quarter of 2018, with 2017 application permitted.  The guidance continues to be interpreted on an industry specific level.  The Company is evaluating the requirements and potential impacts of ASU 2014-9 and will implement the standard in the first quarter of 2018.  The ASU is not currently expected to have a material impact on the financial statements of Eversource, CL&P, NSTAR Electric, PSNH or WMECO.

In January 2016, the FASB issued ASU 2016-1, Financial Instruments - Overall: Recognition and Measurement of Financial Assets and Liabilities, which is required to be implemented in the first quarter of 2018.  The Company is reviewing the requirements of the ASU.  The ASU will remove the available-for-sale designation for equity securities, whereby changes in fair value are recorded in accumulated other comprehensive income within shareholders’ equity, and will require changes in fair value of all equity securities to be recorded in earnings beginning on January 1, 2018, with the unrealized gain or loss on available-for-sale equity securities as of that date reclassified to retained earnings as a cumulative effect of adoption.  The fair value of available-for-sale equity securities subject to this guidance as of September 30, 2016 was approximately $50 million.  The remaining available-for-sale equity securities included in marketable securities on the balance sheet are held in nuclear decommissioning trusts and are subject to regulatory accounting treatment and will not be impacted by this guidance.  Implementation of the ASU for other financial instruments is not expected to have a material impact on the financial statements of Eversource, CL&P, NSTAR Electric, PSNH or WMECO.

In February 2016, the FASB issued ASU 2016-2, Leases, which changes existing lease accounting guidance and is required to be applied in the first quarter of 2019, with earlier application permitted.  The ASU is required to be implemented for leases beginning on the date of initial application. For prior periods presented, leases are required to be recognized and measured using a modified retrospective approach.  The Company is reviewing the requirements of ASU 2016-2, including balance sheet recognition of leases previously deemed operating leases, and expects to implement the ASU in the first quarter of 2019.  

Recently Adopted Accounting Standards:  In March 2016, the FASB issued ASU 2016-9, Compensation - Stock Compensation: Improvements to Employee Share-Based Payment Accounting. The ASU is intended to simplify some aspects of the accounting for share-based payment transactions.  The Company implemented this guidance in the first quarter of 2016, as permitted by early adoption.  Beginning in the first quarter of 2016, the excess tax benefits associated with the distribution of stock compensation awards, previously recognized in Capital Surplus, Paid In within Common Shareholders’ Equity on the balance sheet, are recognized in income tax expense in the income statement.  The implementation reduced income tax expense by $2.9 million for the nine months ended September 30, 2016.  Also, beginning in 2016, in the statement of cash flows, the excess tax benefits are presented as an operating activity rather than a financing activity, and in both periods presented, cash paid to satisfy the statutory income tax withholding obligation previously reflected within operating activities in 2015 is now treated as a financing activity.  The cash payments to satisfy this obligation for the nine months ended September 30, 2016 and 2015 were $9.1 million and $9.7 million, respectively, and are included in Other Financing Activities on the statements of cash flows.  

C.    Provision for Uncollectible Accounts
Eversource, including CL&P, NSTAR Electric, PSNH and WMECO, 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 WMECO and NSTAR Gas to also recover in rates amounts associated with certain uncollectible hardship accounts receivable.  Certain of NSTAR Electric’s uncollectible hardship accounts receivable are expected to be recovered in future rates, similar to WMECO and NSTAR Gas. These uncollectible customer account balances are included in Regulatory Assets or Other Long-Term Assets on the balance sheets.

The total provisions for uncollectible accounts and for uncollectible hardship accounts, which is included in the total provision, are included in Receivables, Net on the balance sheets, and were as follows:
 
Total Provision for Uncollectible Accounts
 
Uncollectible Hardship
(Millions of Dollars)
As of September 30, 2016
 
As of December 31, 2015
 
As of September 30, 2016
 
As of December 31, 2015
Eversource
$
208.1

 
$
190.7

 
$
126.5

 
$
118.5

CL&P
85.3

 
79.5

 
66.9

 
68.1

NSTAR Electric
59.9

 
52.6

 
30.3

 
25.3

PSNH
9.9

 
8.7

 

 

WMECO
16.8

 
14.0

 
10.7

 
7.4



17



D.    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 and long-term debt.

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.  

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 10, “Fair Value of Financial Instruments,” to the financial statements.

E.    Other Income, Net
Items included within Other Income, Net on the statements of income primarily consist of investment income/(loss), interest income, AFUDC related to equity funds, and equity in earnings of equity method investees.  Investment income/(loss) primarily relates to debt and equity securities held in trust.  For further information, see Note 5, “Marketable Securities,” to the financial statements.  

F.    Other Taxes
Gross receipts taxes levied by the state of Connecticut are collected by CL&P and Yankee Gas from their respective customers.  These gross receipts taxes are shown 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 Nine Months Ended
(Millions of Dollars)
September 30, 2016
 
September 30, 2015
 
September 30, 2016
 
September 30, 2015
Eversource
$
45.1

 
$
37.8

 
$
124.8

 
$
112.9

CL&P
42.6

 
35.5

 
112.2

 
98.0


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.     

G.    Supplemental Cash Flow Information
Non-cash investing activities include plant additions included in Accounts Payable as follows:
(Millions of Dollars)
As of September 30, 2016
 
As of September 30, 2015
Eversource
$
203.6

 
$
160.7

CL&P
64.5

 
46.0

NSTAR Electric
39.4

 
31.2

PSNH
31.0

 
33.8

WMECO
17.6

 
15.5




18



2.    REGULATORY ACCOUNTING

Eversource’s Regulated 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 their 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 September 30, 2016
 
As of December 31, 2015
(Millions of Dollars)
Eversource
 
Eversource
Benefit Costs
$
1,618.7

 
$
1,828.2

Derivative Liabilities
443.7

 
388.0

Income Taxes, Net
641.7

 
650.9

Storm Restoration Costs
407.7

 
436.9

Goodwill-related
469.5

 
484.9

Regulatory Tracker Mechanisms
454.1

 
526.5

Contractual Obligations - Yankee Companies
66.0

 
134.4

Other Regulatory Assets
120.9

 
134.0

Total Regulatory Assets
4,222.3

 
4,583.8

Less:  Current Portion
752.4

 
845.8

Total Long-Term Regulatory Assets
$
3,469.9

 
$
3,738.0

 
As of September 30, 2016
 
As of December 31, 2015
(Millions of Dollars)
CL&P
 
NSTAR
Electric
 
PSNH
 
WMECO
 
CL&P
 
NSTAR
Electric
 
PSNH
 
WMECO
Benefit Costs
$
407.1

 
$
414.6

 
$
174.7

 
$
82.1

 
$
413.6

 
$
479.9

 
$
164.2

 
$
84.9

Derivative Liabilities
441.0

 
2.7

 

 

 
380.8

 
1.3

 

 

Income Taxes, Net
438.5

 
88.3

 
27.0

 
31.2

 
444.4

 
85.7

 
34.5

 
31.8

Storm Restoration Costs
253.7

 
115.1

 
20.8

 
18.1

 
271.4

 
110.9

 
31.5

 
23.1

Goodwill-related

 
403.1

 

 

 

 
416.3

 

 

Regulatory Tracker Mechanisms
50.6

 
230.4

 
99.9

 
37.8

 
45.1

 
311.0

 
101.2

 
40.1

Other Regulatory Assets
75.4

 
48.2

 
30.8

 
13.2

 
82.0

 
56.3

 
31.5

 
11.3

Total Regulatory Assets
1,666.3


1,302.4


353.2


182.4


1,637.3


1,461.4


362.9


191.2

Less:  Current Portion
267.7

 
259.2

 
100.6

 
54.1

 
268.3

 
348.4

 
105.0

 
56.2

Total Long-Term Regulatory Assets
$
1,398.6


$
1,043.2


$
252.6


$
128.3


$
1,369.0


$
1,113.0


$
257.9


$
135.0


Regulatory Costs in Other Long-Term Assets:  The Regulated companies had $87.9 million (including $4.0 million for CL&P, $40.2 million for NSTAR Electric, $6.1 million for PSNH and $20.1 million for WMECO) and $75.3 million (including $3.1 million for CL&P, $35.4 million for NSTAR Electric, $4.8 million for PSNH, and $16.7 million for WMECO) of additional regulatory costs as of September 30, 2016 and December 31, 2015, respectively, that were included in Other 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 September 30, 2016
 
As of December 31, 2015
(Millions of Dollars)
Eversource
 
Eversource
Cost of Removal
$
457.7

 
$
437.1

Regulatory Tracker Mechanisms
153.4

 
99.7

AFUDC - Transmission
65.8

 
66.1

Other Regulatory Liabilities
33.7

 
18.5

Total Regulatory Liabilities
710.6

 
621.4

Less:  Current Portion
160.4

 
107.8

Total Long-Term Regulatory Liabilities
$
550.2

 
$
513.6


19



 
As of September 30, 2016
 
As of December 31, 2015
(Millions of Dollars)
CL&P
 
NSTAR
Electric
 
PSNH
 
WMECO
 
CL&P
 
NSTAR
Electric
 
PSNH
 
WMECO
Cost of Removal
$
39.7

 
$
269.5

 
$
45.8

 
$
5.8

 
$
24.1

 
$
257.4

 
$
47.2

 
$
2.8

Benefit Costs

 
81.7

 

 

 

 

 

 

Regulatory Tracker Mechanisms
62.2

 
48.4

 
2.6

 
12.2

 
56.2

 
3.3

 
3.4

 
12.9

AFUDC - Transmission
50.6

 
6.4

 

 
8.8

 
51.5

 
5.7

 

 
8.9

Other Regulatory Liabilities
12.8

 

 
3.5

 

 
4.2

 
1.3

 
4.2

 
0.1

Total Regulatory Liabilities
165.3


406.0


51.9


26.8


136.0


267.7


54.8


24.7

Less:  Current Portion
75.7

 
48.8

 
5.5

 
12.4

 
61.2

 
3.3

 
6.9

 
13.1

Total Long-Term Regulatory Liabilities
$
89.6


$
357.2


$
46.4


$
14.4


$
74.8


$
264.4


$
47.9


$
11.6


3.    PROPERTY, PLANT AND EQUIPMENT AND ACCUMULATED DEPRECIATION

The following tables summarize the investments in utility property, plant and equipment by asset category:
 
As of September 30, 2016
 
As of December 31, 2015
(Millions of Dollars)
Eversource
 
Eversource
Distribution - Electric
$
13,536.1

 
$
13,054.8

Distribution - Natural Gas
2,865.8

 
2,727.2

Transmission - Electric
8,033.0

 
7,691.9

Generation
1,218.9

 
1,194.1

Electric and Natural Gas Utility
25,653.8

 
24,668.0

Other (1)
635.3

 
558.6

Property, Plant and Equipment, Gross
26,289.1

 
25,226.6

Less:  Accumulated Depreciation
 
 
 
Electric and Natural Gas Utility   
(6,442.3
)
 
(6,141.1
)
Other
(285.8
)
 
(255.6
)
Total Accumulated Depreciation
(6,728.1
)
 
(6,396.7
)
Property, Plant and Equipment, Net
19,561.0

 
18,829.9

Construction Work in Progress
1,246.9

 
1,062.5

Total Property, Plant and Equipment, Net
$
20,807.9

 
$
19,892.4


(1) These assets are primarily comprised of building improvements, computer software, hardware and equipment at Eversource Service.
 
As of September 30, 2016
 
As of December 31, 2015
(Millions of Dollars)
CL&P
 
NSTAR
Electric
 
PSNH
 
WMECO
 
CL&P
 
NSTAR Electric
 
PSNH
 
WMECO
Distribution
$
5,513.9

 
$
5,309.2

 
$
1,918.3

 
$
834.6

 
$
5,377.2

 
$
5,100.5

 
$
1,804.8

 
$
812.3

Transmission
3,752.7

 
2,211.7

 
1,005.5

 
1,014.9

 
3,618.0

 
2,131.3

 
928.2

 
964.9

Generation

 

 
1,182.9

 
36.0

 

 

 
1,158.1

 
36.0

Property, Plant and Equipment, Gross
9,266.6

 
7,520.9

 
4,106.7

 
1,885.5

 
8,995.2

 
7,231.8

 
3,891.1

 
1,813.2

Less:  Accumulated Depreciation
(2,102.3
)
 
(1,996.8
)
 
(1,243.8
)
 
(330.6
)
 
(2,041.9
)
 
(1,886.8
)
 
(1,171.0
)
 
(307.0
)
Property, Plant and Equipment, Net
7,164.3

 
5,524.1

 
2,862.9

 
1,554.9

 
6,953.3

 
5,345.0

 
2,720.1

 
1,506.2

Construction Work in Progress
288.9

 
351.8

 
110.2

 
88.4

 
203.5

 
310.5

 
135.3

 
69.1

Total Property, Plant and Equipment, Net
$
7,453.2

 
$
5,875.9

 
$
2,973.1

 
$
1,643.3

 
$
7,156.8

 
$
5,655.5

 
$
2,855.4

 
$
1,575.3


4.    DERIVATIVE INSTRUMENTS

The Regulated 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.  The Regulated companies manage the risks associated with the price volatility of energy and energy-related products through the use of derivative and nonderivative 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 or Operating Revenues 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 Regulated 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.  


20



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 September 30, 2016
 
As of December 31, 2015
(Millions of Dollars)
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:
 
 
 
 
 
 
 
 
 
 
 
Level 2:
 
 
 
 
 
 
 
 
 
 
 
Eversource
$
2.6

 
$
(0.2
)
 
$
2.4

 
$

 
$

 
$

Level 3:
 
 
 
 
 
 
 
 
 
 
 
Eversource
15.7

 
(10.4
)
 
5.3

 
16.7

 
(10.9
)
 
5.8

CL&P
15.3

 
(10.4
)
 
4.9

 
16.7

 
(10.9
)
 
5.8

NSTAR Electric
0.4

 

 
0.4

 

 

 

Long-Term Derivative Assets:
 
 
 
 
 
 
 
 
 
 
 
Level 2:
 
 
 
 
 
 
 
 
 
 
 
Eversource
$

 
$

 
$

 
$
0.1

 
$

 
$
0.1

Level 3:
 
 
 
 
 
 
 
 
 
 
 
Eversource
79.3

 
(13.8
)
 
65.5

 
62.0

 
(19.3
)
 
42.7

CL&P
79.3

 
(13.8
)
 
65.5

 
60.7

 
(19.3
)
 
41.4

NSTAR Electric

 

 

 
1.3

 

 
1.3

Current Derivative Liabilities:
 
 
 
 
 
 
 
 
 
 
 
Level 2:
 
 
 
 
 
 
 
 
 
 
 
Eversource
$

 
$

 
$

 
$
(5.8
)
 
$

 
$
(5.8
)
Level 3:
 
 
 
 
 
 
 
 
 
 
 
Eversource
(87.1
)
 

 
(87.1
)
 
(92.3
)
 

 
(92.3
)
CL&P
(85.3
)
 

 
(85.3
)
 
(91.8
)
 

 
(91.8
)
NSTAR Electric
(1.8
)
 

 
(1.8
)
 
(0.5
)
 

 
(0.5
)
Long-Term Derivative Liabilities:
 
 
 
 
 
 
 
 
 
 
 
Level 3:
 
 
 
 
 
 
 
 
 
 
 
Eversource
$
(427.4
)
 
$

 
$
(427.4
)
 
$
(337.1
)
 
$

 
$
(337.1
)
CL&P
(426.1
)
 

 
(426.1
)
 
(336.2
)
 

 
(336.2
)
NSTAR Electric
(1.3
)
 

 
(1.3
)
 
(0.9
)
 

 
(0.9
)

(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 1D, “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 capacity of these contracts is 787 MW.  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.   

NSTAR Electric has a renewable energy contract to purchase 0.1 million MWh of energy per year through 2018 and a capacity-related contract to purchase up to 35 MW per year through 2019.

As of September 30, 2016 and December 31, 2015, Eversource had NYMEX financial contracts for natural gas futures in order to reduce variability associated with the purchase price of approximately 10.2 million and 9.1 million MMBtu of natural gas, respectively.

For the three months ended September 30, 2016 and 2015, there were losses of $53.4 million and $8.8 million, respectively, deferred as regulatory costs, which reflect the change in fair value associated with Eversource’s derivative contracts. For the nine months ended September 30, 2016 and 2015, these losses were $127.8 million and $58.9 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.  

21




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 relating 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 time period 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.  

The following is a summary of Eversource’s, including CL&P’s and NSTAR Electric’s, Level 3 derivative contracts and the range of the significant unobservable inputs utilized in the valuations over the duration of the contracts:
 
As of September 30, 2016
 
As of December 31, 2015
 
Range
 
Period Covered
 
Range
 
Period Covered
Capacity Prices:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Eversource
$
5.50

 
 
9.75

 
per kW-Month
 
2020 - 2026
 
$
10.81

 
 
15.82

 
per kW-Month
 
2016 - 2026
CL&P
$
5.50

 
 
9.75

 
per kW-Month
 
2020 - 2026
 
$
10.81

 
 
12.60

 
per kW-Month
 
2019 - 2026
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Forward Reserve:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Eversource, CL&P
$
1.40

 
 
2.00

 
per kW-Month
 
2016 - 2024
 
$2.00
 
per kW-Month
 
2016 - 2024
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
REC Prices:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Eversource, NSTAR Electric
$
29

 
 
37

 
per REC
 
2016 - 2018
 
$
45

 
 
51

 
per REC
 
2016 - 2018

Exit price premiums of 4 percent through 21 percent are also applied on these contracts and reflect the uncertainty and liquidity premiums that would be required based on the most recent market activity available for similar type contracts.

Significant increases or decreases in future energy or capacity 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.
 
For the Three Months Ended September 30,
 
2016
 
2015
(Millions of Dollars)
Eversource
 
CL&P
 
NSTAR  
Electric
 
Eversource
 
CL&P
 
NSTAR  
Electric
Derivatives, Net:
 
 
 
 
 
 
 
 
 
 
 
Fair Value as of Beginning of Period
$
(412.6
)
 
$
(411.3
)
 
$
(1.3
)
 
$
(422.4
)
 
$
(420.2
)
 
$
(2.2
)
Net Realized/Unrealized Gains/(Losses) Included in Regulatory Assets and Liabilities
(52.3
)
 
(49.8
)
 
(2.5
)
 
(6.0
)
 
(7.6
)
 
1.6

Settlements
21.2

 
20.1

 
1.1

 
21.4

 
20.9

 
0.5

Fair Value as of End of Period
$
(443.7
)
 
$
(441.0
)
 
$
(2.7
)
 
$
(407.0
)
 
$
(406.9
)
 
$
(0.1
)
 
 
 
 
 
 
 
 
 
 
 
 
 
For the Nine Months Ended September 30,
 
2016
 
2015
(Millions of Dollars)
Eversource
 
CL&P
 
NSTAR  
Electric
 
Eversource
 
CL&P
 
NSTAR  
Electric
Derivatives, Net:
 
 
 
 
 
 
 
 
 
 
 
Fair Value as of Beginning of Period
$
(380.9
)
 
$
(380.8
)
 
$
(0.1
)
 
$
(415.4
)
 
$
(410.9
)
 
$
(4.5
)
Net Realized/Unrealized Gains/(Losses) Included in Regulatory Assets and Liabilities
(128.9
)
 
(122.0
)
 
(6.9
)
 
(55.3
)
 
(56.6
)
 
1.3

Settlements
66.1

 
61.8

 
4.3

 
63.7

 
60.6

 
3.1

Fair Value as of End of Period
$
(443.7
)
 
$
(441.0
)
 
$
(2.7
)
 
$
(407.0
)
 
$
(406.9
)
 
$
(0.1
)


22



5.    MARKETABLE SECURITIES

Eversource maintains trusts that hold marketable securities to fund certain non-qualified executive benefits.  These trusts 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 decommissioning and spent nuclear fuel removal obligations of their nuclear fuel storage facilities.

Trading Securities:  Eversource has elected to record certain equity securities as trading securities, with the changes in fair values recorded in Other Income, Net on the statements of income.  As of September 30, 2016 and December 31, 2015, these securities were classified as Level 1 in the fair value hierarchy and totaled $10.3 million and $14.2 million, respectively.  For the three months ended September 30, 2016 and 2015, net gains on these securities of $0.1 million and net losses of $0.5 million, respectively, and for the nine months ended September 30, 2016 and 2015, net gains of $0.6 million and $1.6 million, respectively, were recorded in Other Income, Net on the statements of income.   Dividend income is recorded in Other Income, Net when dividends are declared.  

Available-for-Sale Securities:  The following is a summary of available-for-sale securities, which are recorded at fair value and are included in current and long-term Marketable Securities on the balance sheets.
 
As of September 30, 2016
 
As of December 31, 2015
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
$
261.2

 
$
10.7

 
$

 
$
271.9

 
$
256.5

 
$
4.5

 
$
(0.6
)
 
$
260.4

Equity Securities
206.7

 
63.7

 
(1.0
)
 
269.4

 
215.3

 
59.2

 
(3.4
)
 
271.1


Eversource’s debt and equity securities include CYAPC’s and YAEC’s marketable securities held in nuclear decommissioning trusts of $446.9 million and $436.9 million as of September 30, 2016 and December 31, 2015, respectively.  Unrealized gains and losses for these nuclear decommissioning trusts 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.  

Unrealized Losses and Other-than-Temporary Impairment:  There have been no significant unrealized losses, other-than-temporary impairments or credit losses for the three and nine months ended September 30, 2016 and 2015.  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.

Realized Gains and Losses:  Realized gains and losses on available-for-sale securities 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 benefit trust, and the average cost basis method for the CYAPC and YAEC nuclear decommissioning trusts to compute the realized gains and losses on the sale of available-for-sale securities.

Contractual Maturities:  As of September 30, 2016, 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)
$
29.3

 
$
29.1

One to five years
58.0

 
59.1

Six to ten years
47.0

 
49.5

Greater than ten years
126.9

 
134.2

Total Debt Securities
$
261.2

 
$
271.9


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


23



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 September 30, 2016
 
As of December 31, 2015
Level 1:  
 
 
 
Mutual Funds and Equities
$
279.7

 
$
285.3

Money Market Funds
24.5

 
26.9

Total Level 1
$
304.2

 
$
312.2

Level 2:
 
 
 
U.S. Government Issued Debt Securities (Agency and Treasury)
$
65.5

 
$
46.6

Corporate Debt Securities
43.3

 
43.9

Asset-Backed Debt Securities
18.0

 
20.0

Municipal Bonds
110.3

 
111.4

Other Fixed Income Securities
10.3

 
11.6

Total Level 2
$
247.4

 
$
233.5

Total Marketable Securities
$
551.6

 
$
545.7


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 instrument 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

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.  As of September 30, 2016 and December 31, 2015, Eversource parent had $698.5 million and approximately $1.1 billion, respectively, in short-term borrowings outstanding under the Eversource parent commercial paper program, leaving $751.5 million and $351.5 million of available borrowing capacity as of September 30, 2016 and December 31, 2015, respectively. The weighted-average interest rate on these borrowings as of September 30, 2016 and December 31, 2015 was 0.66 percent and 0.72 percent, respectively.   As of September 30, 2016, there were intercompany loans from Eversource parent of $108.5 million to CL&P, $107.5 million to PSNH, and $48.2 million to WMECO.  As of December 31, 2015, there were intercompany loans from Eversource parent of $277.4 million to CL&P, $231.3 million to PSNH and $143.4 million to WMECO.  Eversource parent, CL&P, PSNH, WMECO, NSTAR Gas and Yankee Gas are parties to a five-year $1.45 billion revolving credit facility. Effective September 26, 2016, the revolving credit facility’s termination date was extended for one additional year to September 4, 2021.  The revolving credit facility serves to backstop Eversource parent’s $1.45 billion commercial paper program.  There were no borrowings outstanding on the revolving credit facility as of September 30, 2016 or December 31, 2015.

NSTAR Electric has a $450 million commercial paper program allowing NSTAR Electric to issue commercial paper as a form of short-term debt. As of September 30, 2016 and December 31, 2015, NSTAR Electric had $36.0 million and $62.5 million, respectively, in short-term borrowings outstanding under its commercial paper program, leaving $414.0 million and $387.5 million of available borrowing capacity as of September 30, 2016 and December 31, 2015, respectively.  The weighted-average interest rate on these borrowings as of September 30, 2016 and December 31, 2015 was 0.42 percent and 0.40 percent, respectively.  NSTAR Electric is a party to a five-year $450 million revolving credit facility. Effective September 26, 2016, the revolving credit facility’s termination date was extended for one additional year to September 4, 2021.  The revolving credit facility serves to backstop NSTAR Electric’s $450 million commercial paper program.  There were no borrowings outstanding on the revolving credit facility as of September 30, 2016 or December 31, 2015.

Amounts outstanding under the commercial paper programs are included in Notes Payable for Eversource and NSTAR Electric and are classified in current liabilities on the balance sheets as all borrowings are outstanding for no more than 364 days at one time.  Intercompany loans from Eversource parent to CL&P, PSNH and WMECO are included in Notes Payable to Eversource Parent and are classified in current liabilities on their respective balance sheets.  Intercompany loans from Eversource parent to CL&P, PSNH and WMECO are eliminated in consolidation on Eversource’s balance sheets.

Short-Term Borrowing Limits: The amount of short-term borrowings that may be incurred by NSTAR Electric is subject to periodic approval by the FERC. On August 8, 2016, the FERC granted authorization to allow NSTAR Electric to issue total short-term debt securities in an aggregate principal amount not to exceed $655 million outstanding at any one time, through October 23, 2018.

Long-Term Debt Issuances:  In March 2016, Eversource parent issued $250 million of 2.50 percent Series I Senior Notes due to mature in 2021 and $250 million of 3.35 percent Series J Senior Notes due to mature in 2026.  The proceeds, net of issuance costs, were used to repay short-term borrowings under the Eversource parent commercial paper program.

24




In May 2016, NSTAR Electric issued $250 million of 2.70 percent debentures, due to mature in 2026.  The proceeds, net of issuance costs, were used to repay short-term borrowings under the NSTAR Electric commercial paper program and fund capital expenditures and working capital.

In June 2016, WMECO issued $50 million of 2.75 percent Series H Senior Notes, due to mature in 2026.  The proceeds, net of issuance costs, were used to repay short-term borrowings.

Long-Term Debt Repayments:  In May 2016, NSTAR Electric repaid at maturity $200 million variable rate debentures, using short-term borrowings.

7.    PENSION BENEFITS AND POSTRETIREMENT BENEFITS OTHER THAN PENSIONS

Eversource Service sponsors a defined benefit retirement plan (Pension Plan) that covers eligible employees, including, among others, employees of CL&P, NSTAR Electric, PSNH and WMECO.  In addition to the Pension Plan, Eversource maintains non-qualified defined benefit retirement plans sponsored by Eversource Service (SERP Plans), which provide benefits in excess of Internal Revenue Code limitations to eligible participants consisting of current and retired employees.  Eversource Service also sponsors defined benefit postretirement plans that provide certain benefits, primarily medical, dental and life insurance, to retired employees that met certain age and service eligibility requirements, including, among others, employees of CL&P, NSTAR Electric, PSNH and WMECO (PBOP Plan).

Effective January 1, 2016, the Company refined its method of estimating the discount rate for the service and interest cost components of Pension and PBOP expense from the yield-curve approach to the spot rate methodology, which provides a more precise measurement by matching projected cash flows to the corresponding spot rates on the yield curve. Historically, these components were estimated using the same weighted-average discount rate as for the funded status. The discount rates used to estimate the 2016 service cost were 4.89 percent and 4.09 percent for the Pension and PBOP plans, respectively. The discount rates used to estimate the 2016 interest cost were 3.80 percent and 2.88 percent for the Pension and PBOP plans, respectively. The total pre-tax benefit of this change on Pension and PBOP expense, prior to the capitalized portion and amounts deferred and recovered through rate reconciliation mechanisms, for the three months ended September 30, 2016 was $11.5 million and $2.5 million for the Pension and PBOP plans, respectively, and $35 million and $7.5 million for the nine months ended September 30, 2016, respectively.

In August 2016, the Company amended its PBOP Plan, which standardized separate benefit structures that existed within the plan and made other benefit changes. The amendment required a remeasurement of the benefit obligation using current assumptions, including updated discount rates and asset values. The discount rate used to remeasure the benefit obligation was 3.62 percent. The remeasurement resulted in a reduction to the benefit liability of approximately $244 million, offset by an increase to the unamortized actuarial losses of approximately $142 million driven primarily by the decrease in the discount rate.  Overall, the impact of the remeasurement reduced the PBOP plan’s accumulated projected benefit obligation and regulatory assets by approximately $102 million and $106 million, respectively, and increased accumulated other comprehensive losses by $4.0 million. The remeasurement resulted in a decrease in the net periodic benefit costs for PBOP benefits, prior to the capitalized portion and amounts deferred and recovered through rate reconciliation mechanisms, of approximately $10 million, which will be recorded in the period August 1, 2016 through December 31, 2016, and most of this amount will be deferred for future refund to customers.


25



The components of net periodic benefit expense for the Pension, SERP and PBOP Plans are shown below.  The net periodic benefit expense and the intercompany allocations, less the capitalized portions of pension, SERP and PBOP amounts, are included in Operations and Maintenance expense on the statements of income.  Capitalized pension and PBOP amounts relate to employees working on capital projects and are included in Property, Plant and Equipment, Net on the balance sheets.  Pension, SERP and PBOP expense reflected in the statements of cash flows for CL&P, NSTAR Electric, PSNH and WMECO does not include the intercompany allocations or the corresponding capitalized portion, as these amounts are cash settled on a short-term basis.
 
Pension and SERP
Eversource
For the Three Months Ended
 
For the Nine Months Ended
(Millions of Dollars)
September 30, 2016
 
September 30, 2015 (1)
 
September 30, 2016
 
September 30, 2015 (1)
Service Cost
$
18.6

 
$
22.7

 
$
56.6

 
$
68.7

Interest Cost
46.4

 
56.9

 
139.2

 
170.3

Expected Return on Plan Assets
(79.4
)
 
(83.9
)
 
(238.5
)
 
(252.1
)
Actuarial Loss
31.4

 
36.5

 
94.2

 
111.9

Prior Service Cost
0.9

 
0.9

 
2.6

 
2.7

Total Net Periodic Benefit Expense
$
17.9

 
$
33.1

 
$
54.1

 
$
101.5

Capitalized Pension Expense
$
5.4

 
$
9.8

 
$
16.8

 
$
31.3

 
 
 
 
 
 
 
 
 
PBOP
Eversource
For the Three Months Ended
 
For the Nine Months Ended
(Millions of Dollars)
September 30, 2016
 
September 30, 2015 (1)
 
September 30, 2016
 
September 30, 2015 (1)
Service Cost
$
3.0

 
$
4.1

 
$
9.2

 
$
10.3

Interest Cost
7.5

 
11.8

 
26.5

 
30.4

Expected Return on Plan Assets
(15.9
)
 
(16.9
)
 
(47.3
)
 
(43.2
)
Actuarial Loss
3.0

 
1.7

 
5.0

 
4.5

Prior Service Credit
(3.6
)
 
(0.1
)
 
(3.7
)
 
(0.3
)
Total Net Periodic Benefit Expense/(Income)
$
(6.0
)
 
$
0.6

 
$
(10.3
)
 
$
1.7

Capitalized PBOP Expense/(Income)
$
(2.6
)
 
$

 
$
(4.6
)
 
$
0.1

 
Pension and SERP
 
For the Three Months Ended September 30, 2016
 
For the Three Months Ended September 30, 2015
(Millions of Dollars)
CL&P
 
NSTAR Electric
 
PSNH
 
WMECO
 
CL&P
 
NSTAR Electric
 
PSNH (1)
 
WMECO
Service Cost
$
4.6

 
$
3.3

 
$
2.5

 
$
0.8

 
$
6.2

 
$
3.7

 
$
3.1

 
$
1.0

Interest Cost
10.2

 
8.5

 
5.1

 
2.1

 
12.9

 
10.0

 
6.1

 
2.6

Expected Return on Plan Assets
(18.0
)
 
(16.9
)
 
(9.6
)
 
(4.4
)
 
(19.8
)
 
(17.5
)
 
(10.1
)
 
(4.7
)
Actuarial Loss
6.3

 
8.7

 
2.5

 
1.3

 
8.0

 
8.7

 
2.9

 
1.6

Prior Service Cost
0.4

 

 
0.1

 
0.1

 
0.4

 

 
0.1

 
0.1

Total Net Periodic Benefit Expense/(Income)
$
3.5

 
$
3.6

 
$
0.6

 
$
(0.1
)
 
$
7.7

 
$
4.9

 
$
2.1

 
$
0.6

Intercompany Allocations
$
3.5

 
$
2.2

 
$
1.0

 
$
0.6

 
$
5.8

 
$
3.4

 
$
1.6

 
$
1.1

Capitalized Pension Expense
$
2.2

 
$
2.0

 
$
0.4

 
$
0.1

 
$
4.7

 
$
2.7

 
$
0.8

 
$
0.5

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Pension and SERP
 
For the Nine Months Ended September 30, 2016
 
For the Nine Months Ended September 30, 2015
(Millions of Dollars)
CL&P
 
NSTAR
Electric
 
PSNH
 
WMECO
 
CL&P
 
NSTAR
Electric
 
PSNH (1)
 
WMECO
Service Cost
$
14.3

 
$
9.9

 
$
7.5

 
$
2.4

 
$
18.4

 
$
11.2

 
$
9.0

 
$
3.2

Interest Cost
31.2

 
25.3

 
15.4

 
6.3

 
38.4

 
30.2

 
18.1

 
7.8

Expected Return on Plan Assets
(54.2
)
 
(50.7
)
 
(28.9
)
 
(13.1
)
 
(59.1
)
 
(52.5
)
 
(30.3
)
 
(14.2
)
Actuarial Loss
19.2

 
25.8

 
7.5

 
4.1

 
24.2

 
27.0

 
8.8

 
4.8

Prior Service Cost
1.1

 

 
0.3

 
0.2

 
1.1

 
0.1

 
0.4

 
0.2

Total Net Periodic Benefit Expense/(Income)
$
11.6

 
$
10.3

 
$
1.8

 
$
(0.1
)
 
$
23.0

 
$
16.0

 
$
6.0

 
$
1.8

Intercompany Allocations
$
10.3

 
$
6.7

 
$
3.0

 
$
1.9

 
$
18.0

 
$
10.3

 
$
5.0

 
$
3.3

Capitalized Pension Expense
$
7.1

 
$
5.7

 
$
1.0

 
$
0.3

 
$
14.1

 
$
8.6

 
$
2.6

 
$
1.4



26



 
PBOP
 
For the Three Months Ended September 30, 2016
 
For the Three Months Ended September 30, 2015
(Millions of Dollars)
CL&P
 
NSTAR
Electric
 
PSNH
 
WMECO
 
CL&P
 
NSTAR
Electric
 
PSNH (1)
 
WMECO
Service Cost
$
0.6

 
$
0.6

 
$
0.4

 
$
0.1

 
$
0.5

 
$
1.3

 
$
0.3

 
$
0.1

Interest Cost
1.3

 
2.5

 
0.7

 
0.3

 
1.8

 
4.8

 
1.0

 
0.3

Expected Return on Plan Assets
(2.5
)
 
(6.4
)
 
(1.4
)
 
(0.6
)
 
(2.8
)
 
(6.8
)
 
(1.5
)
 
(0.6
)
Actuarial Loss
0.5

 
1.2

 
0.2

 

 
0.2

 
0.6

 
0.1

 

Prior Service Cost/(Credit)
0.2

 
(2.9
)
 
0.1

 

 

 
(0.1
)
 

 

Total Net Periodic Benefit Expense/(Income)
$
0.1

 
$
(5.0
)
 
$

 
$
(0.2
)
 
$
(0.3
)
 
$
(0.2
)
 
$
(0.1
)
 
$
(0.2
)
Intercompany Allocations
$

 
$
(0.1
)
 
$

 
$

 
$
0.4

 
$
0.2

 
$
0.1

 
$
0.1

Capitalized PBOP Expense/(Income)
$

 
$
(2.2
)
 
$

 
$
(0.1
)
 
$
(0.1
)
 
$

 
$
0.1

 
$

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
PBOP
 
For the Nine Months Ended September 30, 2016
 
For the Nine Months Ended September 30, 2015
(Millions of Dollars)
CL&P
 
NSTAR
Electric
 
PSNH
 
WMECO
 
CL&P
 
NSTAR Electric
 
PSNH (1)
 
WMECO
Service Cost
$
1.4

 
$
2.5

 
$
0.9

 
$
0.3

 
$
1.6

 
$
4.0

 
$
1.0

 
$
0.3

Interest Cost
4.0

 
10.3

 
2.2

 
0.8

 
5.4

 
14.2

 
2.9

 
1.1

Expected Return on Plan Assets
(7.6
)
 
(19.2
)
 
(4.2
)
 
(1.7
)
 
(8.3
)
 
(20.5
)
 
(4.4
)
 
(1.9
)
Actuarial Loss
0.9

 
1.7

 
0.5

 

 
0.5

 
1.8

 
0.4

 

Prior Service Cost/(Credit)
0.2

 
(2.9
)
 
0.1

 

 

 
(0.1
)
 

 

Total Net Periodic Benefit Income
$
(1.1
)
 
$
(7.6
)
 
$
(0.5
)
 
$
(0.6
)
 
$
(0.8
)
 
$
(0.6
)
 
$
(0.1
)
 
$
(0.5
)
Intercompany Allocations
$
0.3

 
$

 
$

 
$

 
$
1.4

 
$
0.7

 
$
0.3

 
$
0.3

Capitalized PBOP Expense/(Income)
$
(0.5
)
 
$
(3.3
)
 
$

 
$
(0.3
)
 
$
(0.2
)
 
$
(0.1
)
 
$
0.2

 
$
(0.1
)

(1) 
Amounts excluded approximately $0.8 million and $2.4 million for the three and nine months ended September 30, 2015, respectively, that represented amounts included in other deferred debits.

8.    COMMITMENTS AND CONTINGENCIES

A.    Environmental Matters
Eversource, CL&P, NSTAR Electric, PSNH and WMECO 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, PSNH and WMECO 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 September 30, 2016
 
As of December 31, 2015
 
Number of Sites
 
Reserve
(in millions)
 
Number of Sites
 
Reserve
(in millions)
Eversource
63

 
$
59.7

 
64

 
$
51.1

CL&P
14

 
4.7

 
14

 
4.6

NSTAR Electric
14

 
2.3

 
15

 
2.4

PSNH
12

 
4.3

 
12

 
4.5

WMECO
4

 
0.7

 
4

 
0.6


Included in the Eversource 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 $53.9 million and $45.5 million as of September 30, 2016 and December 31, 2015, 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, PSNH’s, and WMECO’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 related environmental matters.  As this information becomes available, management will continue to assess the potential exposure and adjust the reserves accordingly.


27



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

Eversource parent issued a declining balance guaranty on behalf of Eversource Gas Transmission LLC, a wholly-owned subsidiary, to guarantee the payment of the subsidiary’s capital contributions for its investment in the Access Northeast project. The guaranty will not exceed $206 million and decreases as capital contributions are made.  The guaranty will expire upon the earlier of the full performance of the guaranteed obligations or December 31, 2021.  

Eversource parent issued a guaranty on behalf of its subsidiary, NPT, under which, beginning at the time the Northern Pass Transmission line goes into commercial operation, Eversource parent will 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 has also entered into a guaranty on behalf of NPT under which Eversource parent will guarantee NPT’s obligations under its letter of credit facility with a financial institution pursuant to which NPT may request letters of credit in an aggregate amount of up to approximately $14 million.

Eversource parent has also guaranteed certain indemnification and other obligations as a result of the sales of former unregulated subsidiaries and the termination of an unregulated business, with maximum exposures either not specified or not material.  

Management does not anticipate a material impact to Net Income 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 September 30, 2016:  
Company
 
Description
 
Maximum
 Exposure
(in millions)
 
Expiration Dates
On behalf of subsidiaries:
 
 
 
 
 
 
Eversource Gas Transmission LLC
 
Access Northeast Project Capital Contributions Guaranty
 
$
186.5

 
2021
Various
 
Surety Bonds (1)
 
$
37.1

 
2016 - 2018
Eversource Service and Rocky River Realty Company
 
Lease Payments for Vehicles and Real Estate
 
$
9.8

 
2019 - 2024

(1)
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.  

C.    Spent Nuclear Fuel Litigation - Yankee Companies
The Yankee Companies have filed separate 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 and Phase II of litigation resulting from the DOE’s failure to meet its contractual obligations.  Phase I covered damages incurred in the years 1998 through 2002 and Phase II covered damages incurred in the years 2001 through 2008 for CYAPC and YAEC and from 2002 through 2008 for MYAPC.

DOE Phase III Damages - In August 2013, the Yankee Companies each filed subsequent lawsuits against the DOE seeking recovery of actual damages incurred in the years 2009 through 2012.  The DOE Phase III trial concluded on July 1, 2015, followed by a post-trial briefing that concluded on October 14, 2015.  On March 25, 2016, the court issued its decision and awarded CYAPC, YAEC and MYAPC damages of $32.6 million, $19.6 million and $24.6 million, respectively.  In total, the Yankee Companies were awarded $76.8 million of the $77.9 million in damages sought in Phase III. The decision became final on July 18, 2016, and the Yankee Companies received the awards from the DOE on October 14, 2016.  The Yankee Companies have filed a request with FERC seeking approval of the proposed distribution of certain amounts of the awarded damages proceeds to member companies, including CL&P, NSTAR Electric, PSNH, and WMECO. Subject to receipt of FERC approval, CYAPC and MYAPC expect to be able to make distributions in December 2016. MYAPC also anticipates refunding approximately $57 million from its spent nuclear fuel trust, a portion of which will be refunded to the Eversource utility subsidiaries. In total, Eversource expects to receive approximately $26 million, of which CL&P expects to receive $13.6 million, NSTAR Electric expects to receive $5 million, PSNH expects to receive $3.9 million, and WMECO expects to receive $3.6 million. These anticipated amounts will be refunded to the customers of the respective Eversource utility subsidiaries.


28



D.    FERC ROE Complaints
Four separate complaints have been filed at 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 the first three complaints, the Complainants challenged the NETOs’ base ROE of 11.14 percent that had been utilized since 2006 and sought an order to reduce it prospectively from the date of the final FERC order and for the 15-month complaint refund periods stipulated in the separate complaints.  

The FERC ordered a 10.57 percent base ROE for the first complaint refund period and prospectively from October 16, 2014, and that a utility’s total or maximum ROE for any incentive project shall not exceed the top of the new zone of reasonableness, which was set at 11.74 percent.  In late 2014, the NETOs made a compliance filing, and CL&P, NSTAR Electric, PSNH and WMECO have refunded all amounts associated with the first complaint period.  The NETOs and Complainants have appealed the decision in the first complaint to the D.C. Circuit Court of Appeals.  A court decision is expected in late 2016 or early 2017.

The Company has recorded reserves across the complaint periods at its electric subsidiaries. In the first nine months of 2015, the Company recognized a pre-tax charge to earnings (excluding interest) of $20 million, of which $12.5 million was recorded at CL&P, $2.4 million at NSTAR Electric, $1 million at PSNH, and $4.1 million at WMECO.  The pre-tax charge was recorded as a regulatory liability and as a reduction to Operating Revenues.  

For the second and third complaints, the state parties, municipal utilities and FERC trial staff each believe that the base ROE should be reduced to an amount lower than 11.14 percent.  FERC’s determination to set these cases for hearing was appealed to the D.C. Circuit Court of Appeals, and is being held in abeyance pending a final FERC order. On March 22, 2016, the FERC ALJ issued an initial decision on the second and third complaints.  For the second complaint period, the FERC ALJ recommended a zone of reasonableness of 7.12 percent to 10.42 percent and a base ROE of 9.59 percent.  For the third complaint period, the FERC ALJ recommended a zone of reasonableness of 7.04 percent to 12.19 percent and a base ROE of 10.90 percent.  The FERC ALJ also affirmed that the maximum ROE for transmission incentive projects should be the top of the zone of reasonableness.  The NETOs filed briefs on April 21, 2016, in which the NETOs identified corrections and requested changes that should be made to the FERC ALJ’s recommendations.  A final FERC order is expected in late 2016 or early 2017.

The Company believes that the range of potential loss for the second complaint period (the 15-month period beginning December 27, 2012) is from a base ROE of 10.57 percent to a base ROE of 9.59 percent.  As the FERC ALJ initial decision on the third complaint recommended a base ROE of 10.90 percent, the Company concluded there is currently no range of potential loss for that complaint period (the 15-month period beginning July 31, 2014).  Given the differences between the recommended base ROEs in the FERC ALJ’s initial decision on the second and third complaints, as well as other factors, the Company is unable to predict the outcome of the final FERC order on these two complaints.  The Company does not believe any base ROE outcome within the 10.57 percent to 9.59 percent range is more likely than the base ROEs used to record the current revenues and reserves, and therefore the Company believes that the current reserves for the second complaint period are appropriate at this time.

The impact of a 10 basis point change to the existing base ROE of 10.57 percent would affect Eversource’s after-tax earnings by approximately $3 million for each of the 15-month second and third complaint periods.  If the Company adjusted its reserves based on the recommendations in the FERC ALJ initial decision (for both the base ROE and maximum ROE for transmission incentive projects) for the second and third complaints, then it would result in an after-tax increase of approximately $34 million and an after-tax decrease of approximately $8 million, respectively, to the existing reserves.

For the fourth complaint, filed April 29, 2016, certain municipal utilities claimed the current base ROE of 10.57 percent and the incentive cap of 11.74 percent are unjust and unreasonable.  The NETOs answered on June 3, 2016 and requested that FERC dismiss the complaint.  On September 20, 2016, the FERC issued an order establishing hearing and settlement judge procedures and set a 15-month complaint period beginning April 29, 2016. Management cannot at this time predict the ultimate outcome of this proceeding or the estimated impacts on the financial position, results of operations or cash flows of Eversource, CL&P, NSTAR Electric, PSNH and WMECO. A FERC ALJ initial decision could be received in 2017.

E.    Eversource and NSTAR Electric Boston Harbor Civil Action
On July 15, 2016, 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, Harbor Electric Energy Company, a wholly-owned subsidiary of NSTAR Electric (“HEEC”), and the Massachusetts Water Resources Authority (together with NSTAR Electric and HEEC, the “Defendants”).  The action alleges that the Defendants failed to comply with certain permitting requirements relating to the placement of the HEEC-owned electric distribution cable beneath Boston Harbor.  The action seeks an order to force HEEC to comply with cable depth requirements in the U.S. Army Corps of Engineers’ permit or alternatively to remove the electric distribution cable and cease unauthorized work in U.S. waterways.  The action also seeks civil penalties and other costs.  Management believes there are valid defenses to the claims and intends to defend NSTAR Electric and HEEC vigorously. Concurrently, NSTAR Electric and HEEC are seeking to work collaboratively with all parties for a mutually beneficial resolution.  At this time, management is unable to predict the outcome of this action or the impact on Eversource’s and NSTAR Electric’s financial position, results of operations, or cash flows.


29



9.    PSNH GENERATION ASSET SALE

On June 10, 2015, Eversource and PSNH entered into the 2015 Public Service Company of New Hampshire Restructuring and Rate Stabilization Agreement (the Agreement) with the New Hampshire Office of Energy and Planning, certain members of the NHPUC staff, the Office of Consumer Advocate, two State Senators, and several other parties.  Under the terms of the Agreement, PSNH agreed to divest its generation assets, subject to NHPUC approval.  The Agreement provided for a resolution of issues pertaining to PSNH’s generation assets in pending regulatory proceedings before the NHPUC.  The Agreement provided for the Clean Air Project prudence proceeding to be resolved and all remaining Clean Air Project costs to be included in rates effective January 1, 2016.  In addition, PSNH will not seek a general distribution rate increase effective before July 1, 2017 and will contribute $5 million to create a clean energy fund, which will not be recoverable from its customers.  In the first nine months of 2015, PSNH recorded the $5 million contribution as a long-term liability and an increase to Operations and Maintenance expense on the statements of income.

On July 1, 2016, the NHPUC approved the Agreement in an order that, among other things, instructs PSNH to begin the process to divest its generation assets.  The NHPUC selected an auction adviser to assist with the divestiture, and a final plan and auction process will be determined by the NHPUC in the fourth quarter of 2016.  Upon completion of the divestiture process, all remaining stranded costs will be recovered via bonds that will be secured by a non-bypassable charge or through recoveries in rates billed to PSNH’s customers.

If the NHPUC approves the sale of the assets, the Company expects the assets will be sold prior to the end of 2017.  The sales price of the generating assets could be less than the carrying value, but the Company believes that full recovery of PSNH’s generation assets is probable through a combination of cash flows during the remaining operating period, sales proceeds upon divestiture, and recovery of stranded costs in future rates.

As of September 30, 2016, PSNH’s generation assets were as follows:
(Millions of Dollars)
 
Gross Plant
$
1,191.0

Accumulated Depreciation
(552.1
)
Net Plant
638.9

Fuel, Materials, Supplies and Allowances
161.9


10.    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 and Long-Term Debt:  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 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 tables below are classified as Level 2 within the fair value hierarchy.  Carrying amounts and estimated fair values are as follows:
 
As of September 30, 2016
 
As of December 31, 2015
Eversource
(Millions of Dollars)
Carrying
Amount
 
Fair
Value
 
Carrying
Amount
 
Fair
Value
Preferred Stock Not Subject to Mandatory Redemption
$
155.6

 
$
166.6

 
$
155.6

 
$
157.9

Long-Term Debt
9,609.0

 
10,454.8

 
9,034.5

 
9,425.9

 
CL&P
 
NSTAR Electric
 
PSNH
 
WMECO
(Millions of Dollars)
Carrying
Amount
 
Fair
Value
 
Carrying
Amount
 
Fair
Value
 
Carrying
Amount
 
Fair
Value
 
Carrying
Amount
 
Fair
Value
As of September 30, 2016:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Preferred Stock Not Subject to Mandatory Redemption
$
116.2

 
$
122.2

 
$
43.0

 
$
44.4

 
$

 
$

 
$

 
$

Long-Term Debt
2,765.4

 
3,216.8

 
2,078.0

 
2,338.8

 
1,071.8

 
1,142.9

 
566.7

 
616.9

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
As of December 31, 2015:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Preferred Stock Not Subject to Mandatory Redemption
$
116.2

 
$
114.9

 
$
43.0

 
$
43.0

 
$

 
$

 
$

 
$

Long-Term Debt
2,763.7

 
3,031.6

 
2,029.8

 
2,182.4

 
1,071.0

 
1,121.2

 
517.3

 
551.8


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 1D, “Summary of Significant Accounting Policies - Fair Value Measurements,” for the fair value measurement policy and the fair value hierarchy.


30



11.    ACCUMULATED OTHER COMPREHENSIVE INCOME/(LOSS)

The changes in accumulated other comprehensive income/(loss) by component, net of tax, is as follows:
 
For the Nine Months Ended September 30, 2016
 
For the Nine Months Ended September 30, 2015
 
Qualified  
Cash Flow Hedging Instruments
 
Unrealized
Gains/(Losses) on Marketable Securities
 
Defined Benefit Plans
 
 Total
 
Qualified  
Cash Flow Hedging Instruments
 
Unrealized
Gains/(Losses) on Marketable Securities
 
Defined Benefit Plans
 
Total 
Eversource
(Millions of Dollars)
 
 
 
 
 
 
 
Balance as of Beginning of Period
$
(10.3
)
 
$
(1.9
)
 
$
(54.6
)
 
$
(66.8
)
 
$
(12.4
)
 
$
0.7

 
$
(62.3
)
 
$
(74.0
)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
OCI Before Reclassifications

 
2.3

 
(5.3
)
 
(3.0
)
 

 
(3.9
)
 
(0.4
)
 
(4.3
)
Amounts Reclassified from AOCI
1.6

 

 
2.6

 
4.2

 
1.5

 

 
3.3

 
4.8

Net OCI
1.6

 
2.3

 
(2.7
)
 
1.2

 
1.5

 
(3.9
)
 
2.9

 
0.5

Balance as of End of Period
$
(8.7
)
 
$
0.4

 
$
(57.3
)
 
$
(65.6
)
 
$
(10.9
)
 
$
(3.2
)
 
$
(59.4
)
 
$
(73.5
)

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, PSNH and WMECO 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 and prior service costs that arose during the year and were recognized in AOCI. For further information see Note 7, “Pension Benefits and Postretirement Benefits Other Than Pensions.” The unamortized actuarial gains and losses and prior service costs on the defined benefit plans are amortized from AOCI into Operations and Maintenance expense over the average future employee service period, and are reflected in amounts reclassified from AOCI.  

12.    COMMON SHARES

The following table sets forth the Eversource parent common shares and the shares of common stock of CL&P, NSTAR Electric, PSNH and WMECO that were authorized and issued as well as the respective per share par values:  
 
Shares
 
 
 
Authorized as of September 30, 2016 and
 
Issued as of
 
Par Value
 
December 31, 2015
 
September 30, 2016
 
December 31, 2015
Eversource
$
5

 
380,000,000

 
333,878,402

 
333,862,615

CL&P
$
10

 
24,500,000

 
6,035,205

 
6,035,205

NSTAR Electric
$
1

 
100,000,000

 
100

 
100

PSNH
$
1

 
100,000,000

 
301

 
301

WMECO
$
25

 
1,072,471

 
434,653

 
434,653


As of both September 30, 2016 and December 31, 2015, there were 16,671,366 Eversource common shares held as treasury shares.  As of September 30, 2016 and December 31, 2015, Eversource common shares outstanding were 317,207,036 and 317,191,249, respectively.  

13.    COMMON SHAREHOLDERS’ EQUITY AND NONCONTROLLING INTERESTS

Dividends on the preferred stock of CL&P and NSTAR Electric totaled $1.9 million for the three months ended September 30, 2016 and 2015, and $5.6 million for the nine months ended September 30, 2016 and 2015.  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 September 30, 2016 and December 31, 2015.  On the Eversource balance sheets, Common Shareholders’ Equity was fully attributable to the parent and Noncontrolling Interest – Preferred Stock of Subsidiaries was fully attributable to the noncontrolling interest.



31



14.    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 as if they were converted into common shares.  The dilutive effect of unvested RSU and performance share awards and unexercised stock options 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.  For the three and nine months ended September 30, 2016 and 2015, there were no antidilutive share awards excluded from the computation.

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 Nine Months Ended
September 30, 2016
 
September 30, 2015
 
September 30, 2016
 
September 30, 2015
Net Income Attributable to Common Shareholders
$
265.3

 
$
235.9

 
$
713.1

 
$
696.7

 
 
 
 
 
 
 
 
Weighted Average Common Shares Outstanding:
 
 
 
 
 
 
 
Basic
317,787,836

 
317,452,212

 
317,696,823

 
317,296,107

Dilutive Effect
789,243

 
953,057

 
814,786

 
1,099,935

Diluted
318,577,079

 
318,405,269

 
318,511,609

 
318,396,042

Basic EPS
$
0.83

 
$
0.74

 
$
2.24

 
$
2.20

Diluted EPS
$
0.83

 
$
0.74

 
$
2.24

 
$
2.19


15.    SEGMENT INFORMATION

Presentation:  Eversource is organized into the Electric Distribution, Electric Transmission and Natural Gas 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 and natural gas primarily are derived from residential, commercial and industrial customers and are not dependent on any single customer.  The Electric Distribution reportable segment includes the generation activities of PSNH and WMECO.  

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) the results of Eversource Gas Transmission LLC and 5) the results of other unregulated subsidiaries, which are not part of its core business.

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 expense.   

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.  Each of Eversource’s subsidiaries, including CL&P, NSTAR Electric, PSNH and WMECO, has one reportable segment.  Eversource’s operating segments and reporting units are consistent with its reportable business segments.


32



Eversource’s segment information is as follows:
 
For the Three Months Ended September 30, 2016
Eversource
(Millions of Dollars)
Electric
Distribution
 
Natural Gas
Distribution
 
Electric
Transmission
 
Other
 
Eliminations
 
Total
Operating Revenues
$
1,623.4

 
$
99.2

 
$
306.8

 
$
211.5

 
$
(201.2
)
 
$
2,039.7

Depreciation and Amortization
(154.8
)
 
(15.2
)
 
(47.1
)
 
(8.6
)
 
0.5

 
(225.2
)
Other Operating Expenses
(1,146.8
)
 
(87.8
)
 
(90.2
)
 
(179.3
)
 
199.5

 
(1,304.6
)
Operating Income/(Loss)
321.8

 
(3.8
)
 
169.5

 
23.6

 
(1.2
)
 
509.9

Interest Expense
(49.0
)
 
(10.2
)
 
(26.9
)
 
(15.1
)
 
1.3

 
(99.9
)
Other Income, Net
5.3

 
0.6

 
6.3

 
256.9

 
(255.5
)
 
13.6

Net Income Attributable to Common Shareholders
$
170.1

 
$
(7.0
)
 
$
88.4

 
$
268.5

 
$
(254.7
)
 
$
265.3

 
 
 
 
 
 
 
 
 
 
 
 
 
For the Nine Months Ended September 30, 2016
Eversource
(Millions of Dollars)
Electric Distribution
 
Natural Gas Distribution
 
Electric Transmission
 
Other
 
Eliminations
 
Total
Operating Revenues
$
4,362.6

 
$
622.3

 
$
892.5

 
$
636.8

 
$
(651.7
)
 
$
5,862.5

Depreciation and Amortization
(380.9
)
 
(47.9
)
 
(137.7
)
 
(23.1
)
 
1.6

 
(588.0
)
Other Operating Expenses
(3,230.1
)
 
(462.4
)
 
(245.7
)
 
(564.7
)
 
650.2

 
(3,852.7
)
Operating Income
751.6

 
112.0

 
509.1

 
49.0

 
0.1

 
1,421.8

Interest Expense
(144.6
)
 
(30.8
)
 
(82.2
)
 
(45.8
)
 
4.8

 
(298.6
)
Other Income, Net
11.6

 
0.5

 
14.2

 
781.4

 
(784.0
)
 
23.7

Net Income Attributable to Common Shareholders
$
381.3

 
$
51.9

 
$
266.6

 
$
791.7

 
$
(778.4
)
 
$
713.1

Cash Flows Used for Investments in Plant
$
570.9

 
$
170.3

 
$
536.2

 
$
81.8

 
$

 
$
1,359.2

 
For the Three Months Ended September 30, 2015
Eversource
(Millions of Dollars)
Electric
Distribution
 
Natural Gas
Distribution
 
Electric
Transmission
 
Other
 
Eliminations
 
Total
Operating Revenues
$
1,543.7

 
$
106.2

 
$
270.4

 
$
211.6

 
$
(198.8
)
 
$
1,933.1

Depreciation and Amortization
(84.5
)
 
(17.5
)
 
(42.4
)
 
(7.1
)
 
0.5

 
(151.0
)
Other Operating Expenses
(1,140.8
)
 
(92.7
)
 
(78.3
)
 
(199.6
)
 
198.5

 
(1,312.9
)
Operating Income/(Loss)
318.4

 
(4.0
)
 
149.7

 
4.9

 
0.2

 
469.2

Interest Expense
(47.4
)
 
(9.2
)
 
(25.9
)
 
(11.2
)
 
1.2

 
(92.5
)
Other Income/(Loss), Net
1.9

 
(0.2
)
 
3.8

 
241.9

 
(242.2
)
 
5.2

Net Income Attributable to Common Shareholders
$
167.5

 
$
(3.7
)
 
$
78.0

 
$
234.9

 
$
(240.8
)
 
$
235.9

 
 
 
 
 
 
 
 
 
 
 
 
 
For the Nine Months Ended September 30, 2015
Eversource
(Millions of Dollars)
Electric
Distribution
 
Natural Gas
Distribution
 
Electric
Transmission
 
Other
 
Eliminations
 
Total
Operating Revenues
$
4,686.5

 
$
799.6

 
$
787.2

 
$
655.2

 
$
(664.9
)
 
$
6,263.6

Depreciation and Amortization
(342.1
)
 
(53.4
)
 
(122.6
)
 
(21.5
)
 
1.6

 
(538.0
)
Other Operating Expenses
(3,535.7
)
 
(631.5
)
 
(225.5
)
 
(619.4
)
 
665.2

 
(4,346.9
)
Operating Income
808.7

 
114.7

 
439.1

 
14.3

 
1.9

 
1,378.7

Interest Expense
(140.6
)
 
(27.2
)
 
(79.8
)
 
(35.4
)
 
3.4

 
(279.6
)
Other Income/(Loss), Net
9.6

 
(0.1
)
 
11.9

 
777.0

 
(774.5
)
 
23.9

Net Income Attributable to Common Shareholders
$
418.9

 
$
57.3

 
$
225.0

 
$
764.7

 
$
(769.2
)
 
$
696.7

Cash Flows Used for Investments in Plant
$
506.5

 
$
120.0

 
$
493.9

 
$
56.9

 
$

 
$
1,177.3


The following table summarizes Eversource’s segmented total assets:
Eversource
(Millions of Dollars)
Electric
Distribution
 
Natural Gas
Distribution
 
Electric
Transmission
 
Other
 
Eliminations
 
Total
As of September 30, 2016
$
18,140.0

 
$
3,149.9

 
$
8,454.4

 
$
13,624.8

 
$
(12,286.8
)
 
$
31,082.3

As of December 31, 2015
17,981.3

 
3,104.5

 
8,019.3

 
13,256.7

 
(11,781.5
)
 
30,580.3



33



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 reports on Form 10-Q for the quarters ended March 31, 2016 and June 30, 2016, as well as the Eversource 2015 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 and WMECO 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.  The tabular presentations below also include non-GAAP financial measures referencing our third quarter and first nine months of 2016 and 2015 earnings and EPS excluding certain integration costs.  We use these non-GAAP financial measures to evaluate and to provide details of earnings by business and to more fully compare and explain our third quarter and first nine months of 2015 results without including the impact of these items.  Due to the nature and significance of these items on Net Income Attributable to Common Shareholders, we believe that the non-GAAP presentation provides additional and useful information to readers of this report in analyzing historical and future performance by 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.

Reconciliations of the above non-GAAP financial measures to the most directly comparable GAAP measures of consolidated diluted EPS and Net Income Attributable to Common Shareholders are included under “Financial Condition and Business Analysis – Overview – Consolidated” and “Financial Condition and Business Analysis – Overview – Regulated Companies” in this Management’s Discussion and Analysis of Financial Condition and Results of Operations, herein.  

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:

cyber breaches, acts of war or terrorism, or grid disturbances,
actions or inaction of local, state and federal regulatory, public policy and taxing bodies,
changes in business conditions, which could include disruptive technology related to our current or future business model,
changes in economic conditions, including impact on interest rates, tax policies, and customer demand and payment ability,
fluctuations in weather patterns,
changes in laws, regulations or regulatory policy,
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,
developments in legal or public policy doctrines,
technological developments,
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, contain uncertainties that may materially affect our actual results and are beyond our control.  You should not place undue reliance on the forward-looking statements, each speaks only as of the date on which such statement is made, and 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 2015 combined Annual Report on Form 10-K.  This combined Quarterly Report on Form 10-Q and Eversource’s 2015 combined 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.

34




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:

Results:  

We earned $265.3 million, or $0.83 per share, in the third quarter of 2016, and $713.1 million, or $2.24 per share, in the first nine months of 2016, compared with $235.9 million, or $0.74 per share, in the third quarter of 2015, and $696.7 million, or $2.19 per share, in the first nine months of 2015.  

Our electric distribution segment, which includes generation, earned $170.1 million, or $0.53 per share, in the third quarter of 2016, and $381.3 million, or $1.20 per share, in the first nine months of 2016, compared with earnings of $167.3 million, or $0.53 per share, in the third quarter of 2015, and $418.7 million, or $1.32 per share, in the first nine months of 2015.  

Our transmission segment earned $88.4 million, or $0.28 per share, in the third quarter of 2016, and $266.6 million, or $0.84 per share, in the first nine months of 2016, compared with $78.0 million, or $0.24 per share, in the third quarter of 2015, and $225.0 million, or $0.70 per share, in the first nine months of 2015.  

Our natural gas distribution segment had a net loss of $7.0 million, or $0.02 per share, in the third quarter of 2016, and earnings of $51.9 million, or $0.16 per share, in the first nine months of 2016, compared with a net loss of $3.5 million, or $0.01 per share, in the third quarter of 2015, and earnings of $57.5 million, or $0.18 per share, in the first nine months of 2015.  

Eversource parent and other companies earned $13.8 million in the third quarter of 2016 and $13.3 million in the first nine months of 2016, compared with a net loss of $5.9 million in the third quarter of 2015 and $4.5 million in the first nine months of 2015.  

Liquidity:

Cash flows provided by operating activities totaled $1.65 billion in the first nine months of 2016, compared with $1.35 billion in the first nine months of 2015.  Investments in property, plant and equipment totaled $1.36 billion in the first nine months of 2016, compared with $1.18 billion in the first nine months of 2015.  Cash and cash equivalents totaled $40.1 million as of September 30, 2016, compared with $23.9 million as of December 31, 2015.

On September 7, 2016, our Board of Trustees approved a common share dividend payment of $0.445 per share, which was paid on September 30, 2016 to shareholders of record as of September 19, 2016.

Strategic, Legislative, Regulatory, Policy and Other Items:

In late 2015 and early 2016, NSTAR Electric, WMECO and a subsidiary of National Grid filed with the Massachusetts DPU seeking approval of contracts with Access Northeast for natural gas pipeline capacity and storage. The DPU had determined in 2015 that it had authority to approve such contracts if they were found to be in the public interest. On August 17, 2016, the Massachusetts Supreme Judicial Court vacated the DPU’s 2015 order, holding that the state’s electric utility restructuring statutes precluded the DPU from approving contracts by EDCs for natural gas capacity. In early 2016, PSNH filed with the NHPUC seeking approval of its contract with Access Northeast for natural gas pipeline capacity and storage. On October 6, 2016, contrary to a 2015 recommendation from its staff, the NHPUC ruled that it did not have authority to approve such contracts under the state’s electric utility restructuring statutes. On October 25, 2016, the Connecticut DEEP issued a notice of cancellation, without prejudice, of its natural gas capacity review process. We are currently reviewing options surrounding Access Northeast and, depending on the outcome of the potential options selected, the timing, configuration and cost of Access Northeast could change.

On October 14, 2016, in an important foundational order for NPT, the NHPUC granted NPT public utility status, conditioned on project approval.  

On October 24, 2016, Eversource was notified that neither the NPT project nor the Clean Energy Connect project were selected in the three-state Clean Energy RFP bidding process.  The Company is currently placing efforts on the next round of contracting opportunities, specifically in Massachusetts, where new legislation requires electric distribution companies to jointly solicit RFPs and enter into long-term contracts for large-scale hydro projects.



35



 
Overview

Consolidated:  Below is a summary of our earnings by business, which also reconciles the non-GAAP financial measure of EPS by business to the most directly comparable GAAP measure of diluted EPS, for the third quarter and first nine months of 2016 and 2015.  Also included in the summary for the third quarter and first nine months of 2015 is a reconciliation of the non-GAAP financial measure of consolidated non-GAAP earnings to the most directly comparable GAAP measure of consolidated Net Income Attributable to Common Shareholders.
 
For the Three Months Ended September 30,
 
For the Nine Months Ended September 30,
 
2016
 
2015
 
2016
 
2015
(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)
$
265.3

 
$
0.83

 
$
235.9

 
$
0.74

 
$
713.1

 
$
2.24

 
$
696.7

 
$
2.19

Regulated Companies
$
251.5

 
$
0.79

 
$
242.2

 
$
0.76

 
$
699.8

 
$
2.20

 
$
702.3

 
$
2.20

Eversource Parent and Other Companies
13.8

 
0.04

 
(4.6
)
 
(0.01
)
 
13.3

 
0.04

 
2.2

 
0.01

Non-GAAP Earnings
N/A

 
N/A

 
237.6

 
0.75

 
N/A

 
N/A

 
704.5

 
2.21

Integration Costs (after-tax)  (1)
N/A

 
N/A

 
(1.7
)
 
(0.01
)
 
N/A

 
N/A

 
(7.8
)
 
(0.02
)
Net Income Attributable to
Common Shareholders (GAAP)
$
265.3

 
$
0.83

 
$
235.9

 
$
0.74

 
$
713.1

 
$
2.24

 
$
696.7

 
$
2.19


(1) 
The 2015 integration costs were associated with our branding efforts and severance costs.

Regulated Companies:  Our Regulated companies consist of the electric distribution, electric transmission, and natural gas distribution segments. Generation activities of PSNH and WMECO are included in our electric distribution segment.  A summary of our segment earnings and EPS for the third quarter and first nine months of 2016 and 2015 is as follows:   
 
For the Three Months Ended September 30,
 
For the Nine Months Ended September 30,
 
2016
 
2015
 
2016
 
2015
(Millions of Dollars, Except Per Share Amounts)
Amount
 
Per Share
 
Amount
 
Per Share
 
Amount
 
Per Share
 
Amount
 
Per Share
Electric Distribution
$
170.1

 
$
0.53

 
$
167.7

 
$
0.53

 
$
381.3

 
$
1.20

 
$
419.8

 
$
1.32

Electric Transmission
88.4

 
0.28

 
78.0

 
0.24

 
266.6

 
0.84

 
225.0

 
0.70

Natural Gas Distribution
(7.0
)
 
(0.02
)
 
(3.5
)
 
(0.01
)
 
51.9

 
0.16

 
57.5

 
0.18

Non-GAAP Earnings
N/A

 
N/A

 
242.2

 
0.76

 
N/A

 
N/A

 
702.3

 
2.20

Integration Costs (after-tax)
N/A

 
N/A

 
(0.4
)
 

 
N/A

 
N/A

 
(1.1
)
 

Net Income - Regulated Companies
$
251.5

 
$
0.79

 
$
241.8

 
$
0.76

 
$
699.8

 
$
2.20

 
$
701.2

 
$
2.20


Our electric distribution segment earnings increased $2.8 million in the third quarter of 2016, as compared to the third quarter of 2015, due primarily to increased CL&P distribution revenues primarily as a result of higher rate base, and higher generation earnings. These favorable earnings impacts were partially offset by higher depreciation expense and higher property tax and other tax expense.

Our electric distribution segment earnings decreased $37.4 million in the first nine months of 2016, as compared to the first nine months of 2015, due primarily to the absence in 2016 of the resolution of NSTAR Electric’s basic service bad debt adder mechanism recorded in the first quarter of 2015 ($14.5 million), the absence in 2016 of the favorable impact associated with the NSTAR Electric and NSTAR Gas Comprehensive Settlement Agreement recorded in the first quarter of 2015 ($13 million), lower non-decoupled retail electric sales volumes due primarily to increased customer energy conservation efforts and warmer than normal weather in the first quarter of 2016, as compared to the much colder than normal temperatures in the first quarter of 2015, higher depreciation expense, and higher property tax and other tax expense.  These unfavorable earnings impacts were partially offset by increased CL&P distribution revenues primarily as a result of higher rate base and the absence of an authorized ROE reduction, as stipulated in the PURA 2014 rate case decision, and higher generation earnings.

Our electric transmission segment earnings increased $10.4 million in the third quarter of 2016, as compared to the third quarter of 2015, due primarily to a higher transmission rate base as a result of increased investments in our transmission infrastructure.

Our electric transmission segment earnings increased $41.6 million in the first nine months of 2016, as compared to the first nine months of 2015, due primarily to a higher transmission rate base as a result of increased investments in our transmission infrastructure and the absence in 2016 of reserve charges of $12.4 million recorded in the first quarter of 2015 associated with the FERC ROE complaint proceedings.

Our natural gas distribution segment earnings decreased $3.5 million in the third quarter of 2016, as compared to the third quarter of 2015, due primarily to a higher effective tax rate in 2016, partially offset by the higher return earned on the NSTAR Gas System Enhancement Program (GSEP) capital tracker mechanism effective in 2016.


36



Our natural gas distribution segment earnings decreased $5.6 million in the first nine months of 2016, as compared to the first nine months of 2015, due primarily to lower non-decoupled firm natural gas sales volumes driven by the warmer than normal weather in the first quarter of 2016, as compared to the much colder than normal temperatures in the first quarter of 2015, higher property tax expense and higher interest expense. Partially offsetting these unfavorable earnings impacts were lower operations and maintenance expense, the impact of the NSTAR Gas base distribution rate increase effective January 1, 2016, and the higher return earned on the NSTAR Gas GSEP capital tracker mechanism effective in 2016.

Eversource Parent and Other Companies:  Eversource parent and other companies had earnings of $13.8 million and $13.3 million in the third quarter and first nine months of 2016, respectively, compared with a net loss of $5.9 million and $4.5 million in the third quarter and first nine months of 2015, respectively.  The earnings increase in the third quarter and first nine months of 2016 was due primarily to a lower effective tax rate, the absence in 2016 of integration costs, and the absence in 2016 of a bad debt reserve recorded in the third quarter of 2015 at Eversource’s unregulated business, partially offset by higher interest expense.

Electric and Natural Gas Sales Volumes:  Weather, fluctuations in energy supply costs, conservation measures (including utility-sponsored energy efficiency programs), and economic conditions affect customer energy usage.  Industrial sales volumes are less sensitive to temperature variations than residential and commercial sales volumes.  In our service territories, weather impacts electric 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 are 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 NSTAR Electric and PSNH impact earnings (“Traditional” in the table below).  For CL&P and WMECO, fluctuations in retail electric 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.  CL&P and WMECO reconcile their annual base distribution rate recovery amounts to their respective pre-established levels of baseline distribution delivery service revenues of $1.059 billion and $132.4 million, respectively.  Any difference between the allowed level of distribution revenue and the actual amount incurred during a 12-month period is adjusted through rates in the following period.

Fluctuations in natural gas sales volumes in Massachusetts do not impact earnings due to the DPU-approved natural gas distribution revenue decoupling mechanism approved in the last rate case decision (“Decoupled” in the table below).  Natural gas distribution revenues are decoupled from their customer sales volumes, where applicable, which breaks the relationship between sales volumes and revenues recognized.

A summary of our retail electric GWh sales volumes and our firm natural gas sales volumes in million cubic feet (Mcf) and percentage changes is as follows:  
 
For the Three Months Ended September 30, 2016 Compared to 2015
 
For the Nine Months Ended September 30, 2016 Compared to 2015
 
Sales Volumes (GWh)
 
Percentage
 
Sales Volumes (GWh)
 
Percentage
Electric
2016
 
2015
 
Increase/(Decrease)
 
2016
 
2015
 
Increase/(Decrease)
Traditional:
 
 
 
 
 
 
 
 
 
 
 
Residential
2,910

 
2,832

 
2.8
 %
 
7,407

 
7,706

 
(3.9
)%
Commercial
4,525

 
4,583

 
(1.3
)%
 
12,376

 
12,615

 
(1.9
)%
Industrial
696

 
721

 
(3.5
)%
 
1,948

 
1,988

 
(2.0
)%
Total – Traditional
8,131

 
8,136

 
(0.1
)%
 
21,731

 
22,309

 
(2.6
)%
 
 
 
 
 
 
 
 
 
 
 
 
Decoupled:
 
 
 
 
 
 
 
 
 
 
 
Residential
3,398

 
3,245

 
4.7
 %
 
8,750

 
9,108

 
(3.9
)%
Commercial
3,039

 
3,030

 
0.3
 %
 
8,315

 
8,524

 
(2.5
)%
Industrial
776

 
795

 
(2.4
)%
 
2,170

 
2,233

 
(2.8
)%
Total – Decoupled
7,213

 
7,070

 
2.0
 %
 
19,235

 
19,865

 
(3.2
)%
Total Sales Volumes
15,344

 
15,206

 
0.9
 %
 
40,966

 
42,174

 
(2.9
)%


37



 
For the Three Months Ended September 30, 2016 Compared to 2015
 
For the Nine Months Ended September 30, 2016 Compared to 2015
 
Sales Volumes (Mcf)
 
Percentage
 
Sales Volumes (Mcf)
 
Percentage
Firm Natural Gas
2016
 
2015
 
Increase/(Decrease)
 
2016
 
2015
 
Increase/(Decrease)
Traditional:
 
 
 
 
 
 
 
 
 
 
 
Residential
956

 
955

 
0.1
 %
 
10,109

 
12,022

 
(15.9
)%
Commercial
2,350

 
2,310

 
1.7
 %
 
13,864

 
15,578

 
(11.0
)%
Industrial
1,964

 
2,184

 
(10.1
)%
 
7,597

 
8,755

 
(13.2
)%
Total – Traditional
5,270

 
5,449

 
(3.3
)%
 
31,570

 
36,355

 
(13.2
)%
 
 
 
 
 
 
 
 
 
 
 
 
Decoupled:
 
 
 
 
 
 
 
 
 
 
 
Residential
1,308

 
1,531

 
(14.6
)%
 
13,848

 
17,078

 
(18.9
)%
Commercial
2,147

 
2,065

 
4.0
 %
 
15,019

 
17,002

 
(11.7
)%
Industrial
990

 
977

 
1.3
 %
 
4,163

 
4,670

 
(10.9
)%
Total – Decoupled
4,445

 
4,573

 
(2.8
)%
 
33,030

 
38,750

 
(14.8
)%
Special Contracts (1)
1,208

 
1,115

 
8.3
 %
 
3,507

 
3,384

 
3.6
 %
Total – Decoupled and Special Contracts
5,653

 
5,688

 
(0.6
)%
 
36,537

 
42,134

 
(13.3
)%
Total Sales Volumes
10,923

 
11,137

 
(1.9
)%
 
68,107

 
78,489

 
(13.2
)%

(1) 
Special contracts are unique to the 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.

For the third quarter of 2016, retail electric sales volumes at our electric utilities with a traditional rate structure (NSTAR Electric and PSNH) remained relatively unchanged, as compared to the third quarter of 2015.  Favorable results due to weather in the third quarter of 2016 were offset by lower customer usage driven by the impact of increased customer energy conservation efforts, including those resulting from company-sponsored energy efficiency programs, which resulted in flat traditional retail electric sales volumes. For the first nine months of 2016, retail electric sales volumes at our electric utilities with a traditional rate structure were lower, as compared to the first nine months of 2015, due primarily to lower customer usage driven by the impact of increased customer energy conservation efforts, including those resulting from company-sponsored energy efficiency programs, and the impact of warmer than normal weather in the first quarter of 2016 throughout those service territories, as compared to the much colder than normal temperatures in the first quarter of 2015.  Heating degree days for the first nine months 2016 were 18.4 percent lower in the Boston metropolitan area and 17.9 percent lower in New Hampshire, as compared to the same period in 2015.  

On January 28, 2016, Eversource received approval of a three-year energy efficiency plan in Massachusetts, which includes recovery of LBR at NSTAR Electric until it is operating under a decoupled rate structure.  NSTAR Electric earns LBR related to reductions in sales volume as a result of successful energy efficiency programs.  LBR is recovered from retail customers through current rates.  NSTAR Electric recognized LBR of $17.4 million and $44.1 million in the third quarter and first nine months of 2016, respectively, compared to $19 million and $46.7 million in the third quarter and first nine months of 2015, respectively.

Our firm natural gas sales volumes are subject to many of the same influences as our retail electric sales volumes.  In addition, they have benefited from customer growth in both of our natural gas distribution companies.  In the third quarter of 2016, our consolidated firm natural gas sales volumes were lower, as compared to the third quarter of 2015.  Consolidated firm natural gas sales volumes were much lower in the first nine months of 2016, as compared to the first nine months of 2015.  The first nine months of 2016 firm natural gas sales volumes were negatively impacted by warmer than normal weather in the first quarter of 2016, as compared to the much colder than normal temperatures in the first quarter of 2015, throughout our natural gas service territories.  Heating degree days for the first nine months of 2016 were 16.7 percent lower in Connecticut, as compared to the same period in 2015.

Liquidity

Consolidated:  Cash and cash equivalents totaled $40.1 million as of September 30, 2016, compared with $23.9 million as of December 31, 2015.

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.  As of September 30, 2016 and December 31, 2015, Eversource parent had $698.5 million and approximately $1.1 billion, respectively, in short-term borrowings outstanding under the Eversource parent commercial paper program, leaving $751.5 million and $351.5 million of available borrowing capacity as of September 30, 2016 and December 31, 2015, respectively. The weighted-average interest rate on these borrowings as of September 30, 2016 and December 31, 2015 was 0.66 percent and 0.72 percent, respectively.   As of September 30, 2016, there were intercompany loans from Eversource parent of $108.5 million to CL&P, $107.5 million to PSNH, and $48.2 million to WMECO.  As of December 31, 2015, there were intercompany loans from Eversource parent of $277.4 million to CL&P, $231.3 million to PSNH and $143.4 million to WMECO.  Eversource parent, CL&P, PSNH, WMECO, NSTAR Gas and Yankee Gas are parties to a five-year $1.45 billion revolving credit facility. Effective September 26, 2016, the revolving credit facility’s termination date was extended for one additional year to September 4, 2021.  The revolving credit facility serves to backstop Eversource parent’s $1.45 billion commercial paper program.  There were no borrowings outstanding on the revolving credit facility as of September 30, 2016 or December 31, 2015.


38



NSTAR Electric has a $450 million commercial paper program allowing NSTAR Electric to issue commercial paper as a form of short-term debt.  As of September 30, 2016 and December 31, 2015, NSTAR Electric had $36.0 million and $62.5 million, respectively, in short-term borrowings outstanding under its commercial paper program, leaving $414.0 million and $387.5 million of available borrowing capacity as of September 30, 2016 and December 31, 2015, respectively.  The weighted-average interest rate on these borrowings as of September 30, 2016 and December 31, 2015 was 0.42 percent and 0.40 percent, respectively.  NSTAR Electric is a party to a five-year $450 million revolving credit facility. Effective September 26, 2016, the revolving credit facility’s termination date was extended for one additional year to September 4, 2021. The revolving credit facility serves to backstop NSTAR Electric’s $450 million commercial paper program.   There were no borrowings outstanding on the revolving credit facility as of September 30, 2016 or December 31, 2015.

Short-Term Borrowing Limits: The amount of short-term borrowings that may be incurred by NSTAR Electric is subject to periodic approval by the FERC. On August 8, 2016, the FERC granted authorization to allow NSTAR Electric to issue total short-term debt securities in an aggregate principal amount not to exceed $655 million outstanding at any one time, through October 23, 2018.

Cash Flows:  Cash flows provided by operating activities totaled $1.65 billion in the first nine months of 2016, compared with $1.35 billion in the first nine months of 2015.  The increase in operating cash flows was due primarily to an increase in regulatory recoveries, primarily at NSTAR Electric, due to collections from customers in excess of purchased power costs, a $94.8 million net favorable impact due to the change in income tax payments made, or refunds received, a decrease of $41 million in Pension and PBOP plan cash contributions and the timing of payments related to accounts payable. Partially offsetting these favorable impacts was the timing of collections and payments related to our working capital items.
 
Credit Ratings:  On July 6, 2016, Fitch upgraded the corporate credit ratings by one level and changed the outlooks to stable from positive for CL&P, PSNH and WMECO.  Also on July 6, 2016, Fitch changed the outlook on Eversource parent from stable to positive.  On July 12, 2016, S&P changed its outlook on Eversource and its subsidiaries from stable to positive.  On July 19, 2016, Moody’s upgraded PSNH’s corporate credit rating by one level and changed the outlook from positive 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
 
Positive
 
BBB+
 
Positive
CL&P
Baa1
 
Stable
 
A
 
Positive
 
A- 
 
Stable
NSTAR Electric
A2
 
Stable
 
A
 
Positive
 
A  
 
Stable
PSNH
A3
 
Stable
 
A
 
Positive
 
A-
 
Stable
WMECO
A2
 
Stable
 
A
 
Positive
 
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, NSTAR Electric, and WMECO 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
 
A- 
 
Positive
 
BBB+ 
 
Positive
CL&P
A2
 
Stable
 
A+ 
 
Positive
 
A+
 
Stable
NSTAR Electric
A2
 
Stable
 
A   
 
Positive
 
A+
 
Stable
PSNH
A1
 
Stable
 
A+ 
 
Positive
 
A+ 
 
Stable
WMECO
A2
 
Stable
 
A   
 
Positive
 
A
 
Stable

On September 7, 2016, our Board of Trustees approved a common share dividend payment of $0.445 per share, which was paid on September 30, 2016 to shareholders of record as of September 19, 2016.  In the first nine months of 2016, we paid cash dividends on common shares of $423.5 million, compared with $397.4 million in the first nine months of 2015.

In the first nine months of 2016, CL&P, NSTAR Electric, PSNH, and WMECO paid $149.7 million, $278.3 million, $58.2 million, and $28.5 million, respectively, in common stock dividends to Eversource parent.

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 portions of pension expense.  In the first nine months of 2016, investments for Eversource, CL&P, NSTAR Electric, PSNH, and WMECO were $1.36 billion, $438.5 million, $327.7 million, $215.8 million, and $104.8 million, respectively.   



39




Business Development and Capital Expenditures

Our consolidated capital expenditures, including amounts incurred but not paid, cost of removal, AFUDC, and the capitalized portions of pension expense (all of which are non-cash factors), totaled $1.43 billion in the first nine months of 2016, compared to $1.26 billion in the first nine months of 2015.  These amounts included $87.1 million and $58.6 million in the first nine months of 2016 and 2015, respectively, related to information technology and facilities upgrades and enhancements, primarily at Eversource Service and The Rocky River Realty Company.

Natural Gas Transmission Business:  

Access Northeast: Access Northeast is a natural gas pipeline and storage project (the Project) being developed jointly by Eversource, Spectra Energy Partners, LP (Spectra) and National Grid plc (National Grid), through Algonquin Gas Transmission, LLC (AGT). The Project
will enhance the Algonquin and Maritimes & Northeast pipeline systems using existing routes and will include two new LNG storage tanks and liquefaction and vaporization facilities in Acushnet, Massachusetts that will be connected to the Algonquin natural gas pipeline. The Project is expected to be capable of delivering approximately 900 million cubic feet of additional natural gas per day to New England on peak demand days. Eversource and Spectra each own a 40 percent interest in the Project, with the remaining 20 percent interest owned by National Grid. The total projected cost for both the pipeline and the LNG storage facilities is expected to be approximately $3 billion, with projected in-service dates commencing in November 2018. The Project is subject to FERC and other federal and state regulatory approvals.

As part of the Project’s development, AGT sought to secure long-term natural gas transmission capacity contracts with many of the electric distribution companies (EDCs) of New England. In Connecticut, on June 2, 2016, the DEEP issued an RFP for natural gas pipeline capacity and storage. Proposals were submitted on June 29, 2016. On October 25, 2016, the DEEP canceled this RFP process without prejudice. The DEEP retains its authority to issue future RFPs to procure natural gas resources for the purpose of providing more reliable electric service for the benefit of the Connecticut customers and to meet the state’s energy and environmental goals and policies.

On June 30, 2016, a subsidiary of National Grid filed with the Rhode Island Public Utilities Commission (RIPUC) seeking approval of its contract with AGT for natural gas pipeline capacity and storage. The RIPUC has placed a stay on the docket and asked National Grid for a status update in January 2017. On September 14, 2016, the Maine PUC issued an order to move forward with a contract with AGT for natural gas pipeline capacity, contingent upon the participation by EDCs in other New England states.

In late 2015 and early 2016, NSTAR Electric, WMECO and a subsidiary of National Grid filed with the Massachusetts DPU seeking approval of contracts with AGT for natural gas pipeline capacity and storage. The DPU had determined in 2015 that it had authority to approve such contracts if they were found to be in the public interest. On August 17, 2016, the Massachusetts Supreme Judicial Court vacated the DPU’s 2015 order, holding that the state’s electric utility restructuring statutes precluded the DPU from approving contracts by EDCs for natural gas capacity.

On February 18, 2016, PSNH filed with the NHPUC seeking approval of its contract with AGT for natural gas pipeline capacity and storage. On October 6, 2016, contrary to a 2015 recommendation from its staff, the NHPUC ruled that it did not have authority to approve such contracts under the state’s electric utility restructuring statutes.

Eversource, Spectra and National Grid are currently reviewing options surrounding the Project, with respect to the impact of the decisions from both the Massachusetts Supreme Judicial Court and the NHPUC, in order to help bring needed additional natural gas transmission and storage capacity to New England. The timing, configuration and cost of the Project could change, depending on the outcome of the potential options selected. At this time, we cannot predict the outcome of the potential options selected. At this time, we cannot predict the outcome of the potential options selected and, as a result, the potential impacts on our financial position, results of operations, or cash flows.

Electric Transmission Business:  Our consolidated electric transmission business capital expenditures increased by $37.1 million in the first nine months of 2016, as compared to the first nine months of 2015.  A summary of electric transmission capital expenditures by company is as follows:  
 
For the Nine Months Ended September 30,
(Millions of Dollars)
2016
 
2015
CL&P
$
211.8

 
$
146.9

NSTAR Electric
162.6

 
158.9

PSNH
80.2

 
115.2

WMECO
75.7

 
72.9

NPT
28.4

 
27.7

Total Electric Transmission Segment
$
558.7

 
$
521.6


GHCC:  The Greater Hartford Central Connecticut (GHCC) solutions, which have been approved by ISO-NE, consist of 27 projects with an expected investment of approximately $350 million that are expected to be placed in service from 2016 through 2018.  Seven projects have been placed in service, and 8 projects are in active construction.  As of September 30, 2016, CL&P had capitalized $93 million in costs associated with GHCC.


40



Northern Pass:  Northern Pass is Eversource’s planned HVDC transmission line from the Québec-New Hampshire border to Franklin, New Hampshire and an associated alternating current radial transmission line between Franklin and Deerfield, New Hampshire.  Northern Pass will interconnect at the Québec-New Hampshire border with a planned HQ HVDC transmission line.  On July 21, 2015, the DOE issued the draft Environmental Impact Statement (EIS) for Northern Pass representing a key milestone in the permitting process.  The DOE completed the comment period on the draft EIS on April 4, 2016, and is expected to issue the final EIS in the first quarter of 2017.  On August 18, 2015, NPT announced the Forward NH Plan, including a commitment to allocate $200 million to projects associated with economic development, tourism, community betterment, and clean energy innovations to benefit the state of New Hampshire.  

On June 10, 2016, Northern Pass executed a settlement agreement with the NHPUC Staff regarding its petition to operate as a public utility once the project is fully permitted.  On October 14, 2016, in an important foundational order for the Northern Pass project, the NHPUC approved the settlement agreement and granted NPT public utility status, conditioned on project approval.  Additionally, on June 28, 2016, as part of the Forward NH Plan, PSNH filed a power purchase agreement (PPA) with the NHPUC.  The PPA, combined with the Forward NH Plan, is expected to deliver over $1 billion of energy cost savings and other benefits over the contract term to New Hampshire customers.  The Forward NH Plan and the PPA are both commitments that are contingent upon the Northern Pass transmission line going into commercial operation.  

The New Hampshire Site Evaluation Committee (NH SEC) is currently in process of formal siting.  The NH SEC is expected to issue an order on NPT no later than September 2017 and the project is expected to be operational by the end of 2019.  On January 28, 2016, NPT bid into the three-state Clean Energy RFP process.  For further information on the RFP process, see “Regulatory Developments and Rate Matters – General – Clean Energy RFP” in this Management’s Discussion and Analysis of Financial Condition and Results of Operations.

Greater Boston Reliability Solutions: In February 2015, ISO-NE selected Eversource’s and National Grid’s proposed Greater Boston and New Hampshire Solution (Solution) to satisfy the requirements identified in the Greater Boston study.  The Solution consists of a portfolio of some 40 electric transmission upgrades covering southern New Hampshire and northern Massachusetts in the Merrimack Valley and continuing into the greater Boston metropolitan area, of which 27 are in Eversource’s service territory. The NH SEC issued its written order approving the New Hampshire upgrades on October 4, 2016. We are currently pursuing the necessary regulatory and siting application approvals in Massachusetts.  Construction has begun on several of the smaller projects not requiring siting approval.  All upgrades are expected to be completed by the end of 2019.  We estimate our portion of the investment in the Solution will be approximately $565 million, of which approximately $91 million has been capitalized through September 30, 2016.

Seacoast Reliability Project:  On April 12, 2016, PSNH filed a siting application with the NH SEC for the Seacoast Reliability Project, a 13-mile transmission line within several New Hampshire communities, which proposes to use a combination of overhead, underground and underwater line design to help meet the growing demand for electricity in the Seacoast region.  In June 2016, the NH SEC accepted our application as complete and we expect the NH SEC decision by mid-2017.  This project is expected to be completed by the end of 2018.  We estimate our investment in this project will be approximately $77 million, of which approximately $11 million has been capitalized through September 30, 2016.

Distribution Business:  A summary of distribution capital expenditures is as follows:
 
For the Nine Months Ended September 30,
(Millions of Dollars)
 CL&P
 
 NSTAR Electric
 
 PSNH
 
 WMECO
 
 Total Electric
 
 Natural Gas
 
 Total Electric and Natural Gas Distribution Segment
2016
 
 
 
 
 
 
 
 
 
 
 
 
 
Basic Business
$
127.0

 
$
87.7

 
$
46.8

 
$
10.7

 
$
272.2

 
$
48.9

 
$
321.1

Aging Infrastructure
97.4

 
57.8

 
61.9

 
17.6

 
234.7

 
103.0

 
337.7

Load Growth
31.9

 
48.1

 
11.8

 
(2.5
)
 
89.3

 
28.3

 
117.6

Total Distribution
256.3

 
193.6

 
120.5

 
25.8

 
596.2

 
180.2

 
776.4

Generation

 

 
8.5

 

 
8.5

 

 
8.5

Total Electric and Natural Gas Distribution Segment
$
256.3

 
$
193.6

 
$
129.0

 
$
25.8

 
$
604.7

 
$
180.2

 
$
784.9

 
 
 
 
 
 
 
 
 
 
 
 
 
 
2015
 
 
 
 
 
 
 
 
 
 
 
 
 
Basic Business
$
87.8

 
$
75.2

 
$
37.8

 
$
12.2

 
$
213.0

 
$
35.1

 
$
248.1

Aging Infrastructure
120.0

 
69.8

 
33.9

 
13.5

 
237.2

 
71.8

 
309.0

Load Growth
29.6

 
30.5

 
15.8

 
4.6

 
80.5

 
25.9

 
106.4

Total Distribution
237.4

 
175.5

 
87.5

 
30.3

 
530.7

 
132.8

 
663.5

Generation

 

 
15.9

 

 
15.9

 

 
15.9

Total Electric and Natural Gas Distribuion Segment
$
237.4

 
$
175.5

 
$
103.4

 
$
30.3

 
$
546.6

 
$
132.8

 
$
679.4


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 includes requests for new business and capacity additions on distribution lines and substation additions and expansions.  For the natural gas distribution segment, 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

41



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 reflects growth in existing service territories including new developments, installation of services, and expansion.

The natural gas distribution segment’s capital spending program increased by $47.4 million in the first nine months of 2016, as compared to the first nine months of 2015, as a result of an increase in the replacement of aging pipeline, upgrades to our LNG facilities, and the favorable weather conditions in 2016 allowing for more capital spending on replacement and customer expansion.

FERC Regulatory Matters

FERC ROE Complaints: Four separate complaints have been filed at FERC by combinations of New England state attorneys general, state regulatory commissions, consumer advocates, consumer groups, municipal parties and other parties.  Each complaint challenges the NETOs’ previous base ROE of 11.14 percent or current base ROE of 10.57 percent and seeks to reduce it both for the four separate 15-month complaint periods and prospectively.  

The FERC ordered a 10.57 percent base ROE for the first complaint period and prospectively from October 16, 2014, and that a utility’s total or maximum ROE for any incentive projects shall not exceed the top of the new zone of reasonableness, which was set at 11.74 percent.  We have refunded all amounts associated with the first complaint period.  

The Company has recorded reserves across the complaint periods at its electric subsidiaries. In the first nine months of 2015, the Company recognized an after-tax charge to earnings (excluding interest) of $12.4 million, of which $7.9 million was recorded at CL&P, $1.4 million at NSTAR Electric, $0.6 million at PSNH, and $2.5 million at WMECO.

On March 22, 2016, the FERC ALJ issued an initial decision on the second and third complaints.  For the second complaint period, the FERC ALJ recommended a zone of reasonableness of 7.12 percent to 10.42 percent and a base ROE of 9.59 percent.  For the third complaint period, the FERC ALJ recommended a zone of reasonableness of 7.04 percent to 12.19 percent and a base ROE of 10.90 percent.  The FERC ALJ also affirmed that the maximum ROE for transmission incentive projects should be the top of the zone of reasonableness.  The NETOs filed briefs on April 21, 2016, in which the NETOs identified corrections and requested changes that should be made to the FERC ALJ’s recommendations.  A final FERC order is expected in late 2016 or early 2017.  The final FERC order will determine both the base ROE and the maximum ROE for transmission incentive projects for the two complaint periods.  

We have not recorded any additional reserves to reflect the ROEs recommended in the FERC ALJ initial decision.  We do not believe any ROE outcome is more likely than the ROEs used to record our current reserves (a base ROE of 10.57 percent and a maximum ROE for transmission incentive projects of 11.74 percent).  We are unable to predict the outcome of the final FERC order on the second and third complaints, and therefore, we believe that our current ROEs and reserves are appropriate at this time.

The impact of a 10 basis point change to our existing base ROE of 10.57 percent would affect Eversource’s after-tax earnings by approximately $3 million for each of the 15-month second and third complaint periods.  If we adjusted our reserves based on the recommendations in the FERC ALJ initial decision (for both the base ROE and maximum ROE for transmission incentive projects) for the second and third complaints, then it would result in an after-tax increase of approximately $34 million and an after-tax decrease of approximately $8 million, respectively, to our existing reserves.

For the fourth complaint, filed April 29, 2016, certain municipal utilities claimed the current base ROE of 10.57 percent and the incentive cap of 11.74 percent are unjust and unreasonable.  The NETOs answered on June 3, 2016 and requested that FERC dismiss the complaint. On September 20, 2016, FERC issued an order establishing hearing and settlement judge procedures and set a 15-month complaint period beginning April 29, 2016. We cannot at this time predict the ultimate outcome of this proceeding or the estimated impacts on the financial position, results of operations or cash flows of Eversource, CL&P, NSTAR Electric, PSNH and WMECO. A FERC ALJ initial decision could be received in 2017.

Regulatory Developments and Rate Matters

General:

Clean Energy RFP:  Pursuant to clean energy goals established in three New England states (Connecticut, Massachusetts and Rhode Island), in November 2015, the DEEP and the Massachusetts and Rhode Island EDCs, including NSTAR Electric and WMECO, issued an RFP for clean energy resources (including Class I renewable generation and large hydroelectric generation) to a wide range of potentially interested bidders.  The RFP solicited offers for clean energy and the transmission to deliver that energy to the three states.  In late January 2016, bidders submitted project proposals, among which were the Northern Pass and Clean Energy Connect projects. On October 24, 2016, Eversource was notified that neither project was selected.  

The Company is currently placing efforts on the next round of contracting opportunities, which it believes both NPT and the Clean Energy Connect projects would meet the legislative requirements. In August 2016, Massachusetts enacted legislation that requires electric distribution companies to jointly solicit RFPs and enter into long-term contracts for large-scale hydro projects. The law requires an RFP to take place in the spring of 2017. For further information on this legislation, see “Legislative and Policy Matters - Massachusetts” in this “Management’s Discussion and Analysis of Financial Condition and Results of Operations.


42



Electric and Natural Gas 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 nine months of 2016, 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 2015 Form 10-K.

Massachusetts:

October 2016 DPU Storm Order: On October 7, 2016, the DPU issued a final decision on WMECO’s storm cost filing that sought to recover $27 million of storm restoration costs associated with the October 2011 snowstorm and Storm Sandy in 2012. The DPU approved the majority of the costs, with the disallowed amounts and other items included in a filed motion for reconsideration.

New Hampshire:

Generation Asset Sale:  On June 10, 2015, Eversource and PSNH entered into the 2015 Public Service Company of New Hampshire Restructuring and Rate Stabilization Agreement (the Agreement) with the New Hampshire Office of Energy and Planning, certain members of the NHPUC staff, the Office of Consumer Advocate, two State Senators, and several other parties.  Under the terms of the Agreement, PSNH agreed to divest its generation assets, subject to NHPUC approval.  The Agreement provided for a resolution of issues pertaining to PSNH’s generation assets in pending regulatory proceedings before the NHPUC.  The Agreement provided for the Clean Air Project prudence proceeding to be resolved and all remaining Clean Air Project costs to be included in rates effective January 1, 2016.  As part of the Agreement, PSNH agreed to forego recovery of $25 million of the equity return related to the Clean Air Project.  In addition, PSNH will not seek a general distribution rate increase effective before July 1, 2017 and will contribute $5 million to create a clean energy fund, which will not be recoverable from its customers.  In the first nine months of 2015, PSNH recorded the $5 million contribution as a long-term liability and an increase to Operations and Maintenance expense on the statements of income.

On July 1, 2016, the NHPUC approved the Agreement in an order that, among other things, instructs PSNH to begin the process to divest its generation assets.  The NHPUC selected an auction adviser to assist with the divestiture, and a final plan and auction process will be determined by the NHPUC in the fourth quarter of 2016.  Upon completion of the divestiture process, all remaining stranded costs will be recovered via bonds that will be secured by a non-bypassable charge or through recoveries in rates billed to PSNH’s customers.

We believe that full recovery of PSNH’s generation assets is probable through a combination of cash flows during the remaining operating period, sales proceeds upon divestiture, and recovery of stranded costs in future rates.  

As of September 30, 2016, PSNH’s energy service rate base was approximately $640 million. This rate base will be reduced by the amount of generation assets that are divested.

Legislative and Policy Matters

Massachusetts:

On August 8, 2016, in conjunction with efforts to shape comprehensive energy legislation, “An Act to Promote Energy Diversity” became law in Massachusetts, which requires electric distribution companies to jointly solicit RFPs and enter into 15- to 20-year contracts for at least 1,600 MW of offshore wind and up to an additional 1,200 MW of hydropower or other renewable sources, such as land-based wind or solar, provided that reasonable proposals have been received.

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 2015 Form 10-K.  There have been no material changes with regard to these critical accounting policies.

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:  There have been no material contractual obligations identified and no material changes with regard to the contractual obligations and commercial commitments previously disclosed in the Eversource 2015 Form 10-K.


43



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, PSNH’s and WMECO’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.


44



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 nine months ended September 30, 2016 and 2015 included in this combined Quarterly Report on Form 10-Q:  
 
For the Three Months Ended September 30,
 
For the Nine Months Ended September 30,
(Millions of Dollars)
2016
 
2015
 
Increase/(Decrease)
 
Percent
 
2016
 
2015
 
Increase/(Decrease)
 
Percent
Operating Revenues
$
2,039.7

 
$
1,933.1

 
$
106.6

 
5.5
 %
 
$
5,862.5

 
$
6,263.6

 
$
(401.1
)
 
(6.4
)%
Operating Expenses:
 

 
 

 
 

 
 

 
 
 
 

 
 

 
 

Purchased Power, Fuel and Transmission
665.8

 
702.6

 
(36.8
)
 
(5.2
)
 
2,001.9

 
2,549.8

 
(547.9
)
 
(21.5
)
Operations and Maintenance
324.7

 
327.3

 
(2.6
)
 
(0.8
)
 
965.6

 
977.3

 
(11.7
)
 
(1.2
)
Depreciation
181.3

 
167.9

 
13.4

 
8.0

 
531.8

 
495.4

 
36.4

 
7.3

Amortization of Regulatory Assets/(Liabilities), Net
43.9

 
(16.8
)
 
60.7

 
(a)

 
56.2

 
42.6

 
13.6

 
31.9

Energy Efficiency Programs
149.1

 
132.1

 
17.0

 
12.9

 
406.0

 
380.6

 
25.4

 
6.7

Taxes Other Than Income Taxes
165.0

 
150.8

 
14.2

 
9.4

 
479.2

 
439.2

 
40.0

 
9.1

Total Operating Expenses
1,529.8

 
1,463.9

 
65.9

 
4.5

 
4,440.7

 
4,884.9

 
(444.2
)
 
(9.1
)
Operating Income
509.9

 
469.2

 
40.7

 
8.7

 
1,421.8

 
1,378.7

 
43.1

 
3.1

Interest Expense
99.9

 
92.5

 
7.4

 
8.0

 
298.6

 
279.6

 
19.0

 
6.8

Other Income, Net
13.6

 
5.2

 
8.4

 
(a)

 
23.7

 
23.9

 
(0.2
)
 
(0.8
)
Income Before Income Tax Expense
423.6

 
381.9

 
41.7

 
10.9

 
1,146.9

 
1,123.0

 
23.9

 
2.1

Income Tax Expense
156.4

 
144.1

 
12.3

 
8.5

 
428.2

 
420.7

 
7.5

 
1.8

Net Income
267.2

 
237.8

 
29.4

 
12.4

 
718.7

 
702.3

 
16.4

 
2.3

Net Income Attributable to Noncontrolling Interests
1.9

 
1.9

 

 

 
5.6

 
5.6

 

 

Net Income Attributable to Common Shareholders
$
265.3

 
$
235.9

 
$
29.4

 
12.5
 %
 
$
713.1

 
$
696.7

 
$
16.4

 
2.4
 %
(a)
Percent greater than 100 not shown as it is not meaningful.  

Operating Revenues
A summary of our Operating Revenues by segment is as follows:
 
For the Three Months Ended September 30,
 
For the Nine Months Ended September 30,
(Millions of Dollars)
2016
 
2015
 
Increase/(Decrease)
 
Percent
 
2016
 
2015
 
Increase/(Decrease)
 
Percent
Electric Distribution
$
1,623.4

 
$
1,543.7

 
$
79.7

 
5.2
 %
 
$
4,362.6

 
$
4,686.5

 
$
(323.9
)
 
(6.9
)%
Natural Gas Distribution
99.2

 
106.2

 
(7.0
)
 
(6.6
)
 
622.3

 
799.6

 
(177.3
)
 
(22.2
)
Electric Transmission
306.8

 
270.4

 
36.4

 
13.5

 
892.5

 
787.2

 
105.3

 
13.4

Other and Eliminations
10.3

 
12.8

 
(2.5
)
 
(19.5
)
 
(14.9
)
 
(9.7
)
 
(5.2
)
 
53.6

Total Operating Revenues
$
2,039.7

 
$
1,933.1

 
$
106.6

 
5.5
 %
 
$
5,862.5

 
$
6,263.6

 
$
(401.1
)
 
(6.4
)%

A summary of our retail electric GWh sales volumes and our firm natural gas sales volumes in Mcf were as follows:
 
For the Three Months Ended September 30,
 
For the Nine Months Ended September 30,
 
2016
 
2015
 
Increase/(Decrease)
 
Percent
 
2016
 
2015
 
Decrease
 
Percent
Electric
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Traditional
8,131

 
8,136

 
(5
)
 
(0.1
)%
 
21,731

 
22,309

 
(578
)
 
(2.6
)%
Decoupled
7,213

 
7,070

 
143

 
2.0

 
19,235

 
19,865

 
(630
)
 
(3.2
)
Total Electric
15,344

 
15,206

 
138

 
0.9

 
40,966

 
42,174

 
(1,208
)
 
(2.9
)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Firm Natural Gas
 
 
 
 
 
 
 
 
 
 
 
 
 

 
 
Traditional
5,270

 
5,449

 
(179
)
 
(3.3
)
 
31,570

 
36,355

 
(4,785
)
 
(13.2
)
Decoupled and Special Contracts
5,653

 
5,688

 
(35
)
 
(0.6
)
 
36,537

 
42,134

 
(5,597
)
 
(13.3
)
Total Firm Natural Gas
10,923

 
11,137

 
(214
)
 
(1.9
)%
 
68,107

 
78,489

 
(10,382
)
 
(13.2
)%

Three Months Ended:
Operating Revenues, which primarily consist of base electric and natural gas distribution revenues and tracked revenues further described below, increased by $106.6 million for the three months ended September 30, 2016, as compared to the same period in 2015.  

Base electric distribution revenues:  Base electric distribution segment revenues increased $7.8 million due primarily to a higher rate base resulting from the 2015 PURA ADIT settlement agreement that is being collected from customers in distribution rates at CL&P ($5.4 million) and the absence of an authorized ROE reduction in 2015, as stipulated in the PURA 2014 rate case decision, at CL&P ($1.1 million).  


45



Fluctuations in CL&P’s, WMECO’s and NSTAR Gas’ sales volumes do not impact the level of base distribution revenue realized or earnings due to their respective regulatory commission approved revenue decoupling mechanisms.  The revenue decoupling mechanisms permit recovery of a base amount of distribution revenues and break the relationship between sales volumes and revenues recognized.  Revenue decoupling mechanisms result in the recovery of our approved base distribution revenue requirements.  

Tracked distribution revenues: Tracked revenues consist of certain costs that are recovered from customers in rates through regulatory commission-approved cost tracking mechanisms and therefore have no impact on earnings.  Costs recovered through cost tracking mechanisms include energy supply procurement costs and other energy-related costs for our electric and natural gas customers, retail transmission charges, energy efficiency program costs, and restructuring and stranded cost recovery revenues.  In addition, tracked revenues include certain incentives earned and carrying charges. Tracked electric distribution segment revenues increased as a result of an increase in retail electric transmission charges ($45 million), an increase in federally mandated congestion charges ($40.5 million), an increase in energy efficiency program revenues ($17.4 million), an increase in stranded cost recovery charges ($13.6 million) and an increase in net metering for distributed generation revenues ($10.8 million), partially offset by decreases in energy supply costs ($60.4 million), driven by decreased average retail rates.  In addition, as a result of a change to the amounts collected in the system benefits charge, CL&P’s calculated rate base increased, providing an increase to distribution revenues that impacted earnings of $8.2 million.  

The third quarter 2016 tracked natural gas distribution segment revenues decreased as a result of decreases in natural gas supply costs ($5.4 million) and a decrease in energy efficiency program revenues ($2.5 million).

Electric transmission revenues:  The electric transmission segment revenues increased by $36.4 million due primarily to the recovery of higher revenue requirements associated with ongoing investments in our transmission infrastructure.

Nine Months Ended:
Operating Revenues decreased by $401.1 million for the nine months ended September 30, 2016, as compared to the same period in 2015.  

Base electric and natural gas distribution revenues:  Base electric distribution segment revenues increased by $5.6 million due primarily to a higher rate base resulting from the 2015 PURA ADIT settlement agreement that is being collected from customers in distribution rates at CL&P ($16.1 million) and the absence of an authorized ROE reduction in 2015, as stipulated in the PURA 2014 rate case decision, at CL&P ($3.3 million), partially offset by a 2.6 percent decrease in non-decoupled retail electric sales volumes due primarily to increased customer energy conservation efforts and warmer than normal weather in the first quarter of 2016, as compared to the much colder than normal temperatures in the first quarter of 2015 ($13.8 million).

Contributing to the decrease in operating revenues in the first nine months of 2016 was the absence of an $11 million benefit related to the Comprehensive Settlement Agreement associated with the recovery of LBR related to 2009 through 2011 energy efficiency programs recorded at NSTAR Electric in the first quarter of 2015.  

Firm natural gas base distribution segment revenues decreased $9.2 million due primarily to a 13.2 percent decrease in traditional firm natural gas sales volumes as a result of warmer than normal weather experienced in the first quarter of 2016, as compared to much colder than normal temperatures in the first quarter of 2015, partially offset by the impact of the NSTAR Gas base distribution rate increase effective January 1, 2016.  

Tracked distribution revenues: Tracked electric distribution segment revenues decreased as a result of decreases in energy supply costs ($570.3 million), driven by decreased average retail rates and lower sales volumes, partially offset by an increase in retail electric transmission charges ($82.9 million), an increase in federally mandated congestion charges ($70.4 million), an increase in energy efficiency program revenues ($45.2 million), an increase in stranded cost recovery charges ($29.5 million) and an increase in net metering for distributed generation revenues ($25.7 million).  In addition, as a result of a change to the amounts collected in the system benefits charge, CL&P’s calculated rate base increased, providing an increase to distribution revenues that impacted earnings of $17.5 million.

The first nine months of 2016 tracked natural gas distribution segment revenues decreased as a result of decreases in natural gas supply costs ($143.2 million) driven by decreased average rates and lower sales volumes, and a decrease in energy efficiency program revenues ($25.5 million).

Electric transmission revenues:  The electric transmission segment revenues increased by $105.3 million due primarily to the recovery of higher revenue requirements associated with ongoing investments in our transmission infrastructure and the absence in 2016 of a $20 million reserve charge recorded in the first quarter of 2015 associated with the March 2015 FERC ROE order.

Other:  Other revenues decreased due primarily to the sale of Eversource’s unregulated contracting business on April 13, 2015 ($11.4 million).


46



Purchased Power, Fuel and Transmission expense includes costs associated with purchasing electricity and natural gas on behalf of our customers.  These energy supply costs are recovered from customers in rates through cost tracking mechanisms, which have no impact on earnings (tracked costs).  Purchased Power, Fuel and Transmission expense decreased for the three and nine months ended September 30, 2016, as compared to the same periods in 2015, due primarily to the following:
(Millions of Dollars)
Three Months Ended
Increase/(Decrease)
 
Nine Months Ended
Increase/(Decrease)
Electric Distribution
$
(98.5
)
 
$
(551.3
)
Natural Gas Distribution
(6.3
)
 
(142.2
)
Transmission
68.0

 
145.6

Total Purchased Power, Fuel and Transmission
$
(36.8
)
 
$
(547.9
)

The decrease in purchased power expense at the electric distribution business was driven by lower prices associated with the procurement of energy supply and a decrease in the amount of electricity generated by PSNH facilities for both the three and nine months ended September 30, 2016, as compared to the same periods in 2015, as well as lower sales volumes for the nine months ended September 30, 2016, as compared to the same period in 2015.  The decrease in purchased power expense at the natural gas distribution business was due to lower sales volumes and lower average natural gas prices.  The increase in transmission costs was primarily the result of an increase in costs billed by ISO-NE that support regional grid investment.

Operations and Maintenance expense includes tracked costs and costs that are part of base electric and natural gas distribution rates with changes impacting earnings (non-tracked costs).  Operations and Maintenance expense decreased for the three and nine months ended September 30, 2016, as compared to the same periods in 2015, due primarily to the following:
(Millions of Dollars)
Three Months Ended
Increase/(Decrease)
 
Nine Months Ended
Increase/(Decrease)
Base Electric Distribution:
 
 
 
Absence of 2015 resolution of basic service bad debt adder mechanism at NSTAR Electric
$

 
$
24.2

Storm restoration costs
5.0

 
11.3

Vegetation management costs
1.1

 
5.7

Employee-related expenses, including labor and benefits
(8.4
)
 
(13.7
)
   Absence of 2015 contribution to create clean energy fund in connection with the generation divestiture agreement at PSNH

 
(5.0
)
Other operations and maintenance
3.5

 
1.1

Total Base Electric Distribution
1.2

 
23.6

Total Base Natural Gas Distribution:
 
 
 
Employee-related expenses, including labor and benefits
(0.1
)
 
(11.9
)
Other operations and maintenance
2.3

 
5.3

Total Base Natural Gas Distribution
2.2

 
(6.6
)
Total Tracked costs (Electric Distribution, Electric Transmission and Natural Gas Distribution)
13.9

 
21.6

Other and eliminations:
 
 
 
Integration costs
(2.9
)
 
(13.4
)
Absence of Eversource’s unregulated electrical contracting business due to sale in April 2015, net
(3.3
)
 
(13.9
)
Eversource Parent and Other Companies
(5.6
)
 
(10.1
)
   Eliminations
(8.1
)
 
(12.9
)
Total Operations and Maintenance
$
(2.6
)
 
$
(11.7
)

Depreciation expense increased for the three and nine months ended September 30, 2016, as compared to the same periods in 2015, due primarily to higher utility plant in service balances.

Amortization of Regulatory Assets/(Liabilities), Net expense (the costs of which are tracked) include the deferral of energy supply and energy-related costs included in certain regulatory-approved tracking mechanisms, and the amortization of certain costs.  The deferral adjusts expense to match the corresponding revenues.  Amortization of Regulatory Assets/(Liabilities), Net, increased for the three and nine months ended September 30, 2016, as compared to the same periods in 2015, 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 at CL&P, NSTAR Electric, PSNH and WMECO, which are the primary drivers in amortization, are recovered from customers in rates and have no impact on earnings.  The increase in Amortization of Regulatory Assets/(Liabilities), Net for the nine months ended September 30, 2016 includes the absence in 2016 of the $11.7 million benefit recorded in the first quarter of 2015 at NSTAR Electric in connection with the Comprehensive Settlement Agreement associated with the CPSL program filings.


47



Energy Efficiency Programs expense (the costs of which are tracked) increased for the three and nine months ended September 30, 2016, as compared to the same periods in 2015, due primarily to deferral adjustments at NSTAR Electric, partially offset by deferral adjustments for the natural gas businesses, which reflect the actual costs of energy efficiency programs compared to the estimated amounts billed to customers, and the timing of the recovery of energy efficiency costs incurred in accordance with the three-year program guidelines established by the DPU.  The deferrals adjust expense to match the energy efficiency programs revenue.  The costs for various 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 nine months ended September 30, 2016, as compared to the same periods in 2015, due primarily to an increase in property taxes as a result of higher utility plant balances and an increase in gross earnings taxes (the costs of which are tracked).

Interest Expense increased for the three and nine months ended September 30, 2016, as compared to the same periods in 2015, due primarily to higher interest on long-term debt ($9.5 million and $25.7 million, respectively) as a result of new debt issuances, partially offset by an increase in AFUDC borrowed funds ($1.4 million and $2.9 million, respectively).

Other Income, Net increased for the three months ended September 30, 2016, as compared to the same period in 2015, due primarily to higher AFUDC related to equity funds ($2.8 million), an increase related to officer insurance policies ($1.9 million), and an increase in net gains related to the deferred compensation plans ($0.8 million).

Income Tax Expense increased for the three months ended September 30, 2016, as compared to the same period in 2015, due primarily to higher pre-tax earnings ($14.3 million), higher state income taxes ($3.4 million), and items that impact our tax rate as a result of regulatory treatment (flow-through items) and permanent differences ($2.4 million), partially offset by the true up of the return to provision impacts and a higher tax benefit from a reduction in tax reserves ($7.6 million).

Income Tax Expense increased for the nine months ended September 30, 2016, as compared to the same period in 2015, due primarily to higher pre-tax earnings ($9 million), higher state income taxes ($5.9 million), and flow-through items and permanent differences ($3.5 million), partially offset by the true up of the return to provision impacts and a higher tax benefit from a reduction in tax reserves ($7.6 million), and the excess tax benefit due to the adoption of new accounting guidance related to share-based payment transactions ($2.9 million).


48



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 and nine months ended September 30, 2016 and 2015 included in this combined Quarterly Report on Form 10-Q:  
 
For the Three Months Ended September 30,
 
For the Nine Months Ended September 30,
(Millions of Dollars)
2016
 
2015
 
Increase/
(Decrease)
 
Percent
 
2016
 
2015
 
Increase/
(Decrease)
 
Percent
Operating Revenues
$
760.0

 
$
704.3

 
$
55.7

 
7.9
 %
 
$
2,175.1

 
$
2,175.7

 
$
(0.6
)
 
 %
Operating Expenses:
 

 
 

 
 

 
 

 
 

 
 

 
 

 
 

Purchased Power and Transmission
253.5

 
274.8

 
(21.3
)
 
(7.8
)
 
760.6

 
861.6

 
(101.0
)
 
(11.7
)
Operations and Maintenance
123.0

 
122.3

 
0.7

 
0.6

 
356.4

 
358.3

 
(1.9
)
 
(0.5
)
Depreciation
57.7

 
54.8

 
2.9

 
5.3

 
172.2

 
159.9

 
12.3

 
7.7

Amortization of Regulatory Assets/(Liabilities), Net
23.4

 
(22.9
)
 
46.3

 
(a)

 
30.3

 
17.9

 
12.4

 
69.3

Energy Efficiency Programs
44.4

 
42.6

 
1.8

 
4.2

 
118.0

 
119.4

 
(1.4
)
 
(1.2
)
Taxes Other Than Income Taxes
81.9

 
71.6

 
10.3

 
14.4

 
227.9

 
201.7

 
26.2

 
13.0

Total Operating Expenses
583.9

 
543.2

 
40.7

 
7.5

 
1,665.4

 
1,718.8

 
(53.4
)
 
(3.1
)
Operating Income
176.1

 
161.1

 
15.0

 
9.3

 
509.7

 
456.9

 
52.8

 
11.6

Interest Expense
36.1

 
36.7

 
(0.6
)
 
(1.6
)
 
108.6

 
109.5

 
(0.9
)
 
(0.8
)
Other Income, Net
3.7

 
2.4

 
1.3

 
54.2

 
10.9

 
8.6

 
2.3

 
26.7

Income Before Income Tax Expense
143.7

 
126.8

 
16.9

 
13.3

 
412.0

 
356.0

 
56.0

 
15.7

Income Tax Expense
57.1

 
46.6

 
10.5

 
22.5

 
155.4

 
127.8

 
27.6

 
21.6

Net Income
$
86.6

 
$
80.2

 
$
6.4

 
8.0
 %
 
$
256.6

 
$
228.2

 
$
28.4

 
12.4
 %

Operating Revenues
CL&P’s retail sales volumes were as follows:
 
For the Three Months Ended September 30,
 
For the Nine Months Ended September 30,
 
2016
 
2015
 
Increase
 
Percent
 
2016
 
2015
 
Decrease
 
Percent
Retail Sales Volumes in GWh
6,225

 
6,103

 
122

 
2.0
%
 
16,541

 
17,123

 
(582
)
 
(3.4
)%

Three Months Ended:
CL&P’s Operating Revenues, which consist of base distribution revenues and tracked revenues further described below, increased by $55.7 million for the three months ended September 30, 2016, as compared to the same period in 2015.

Base distribution revenues increased by $6.5 million due to a higher rate base resulting from the 2015 PURA ADIT settlement agreement that is being collected from customers in distribution rates ($5.4 million) and the absence of an authorized ROE reduction, as stipulated in the PURA 2014 rate case decision, recorded in the third quarter of 2015 ($1.1 million).  

Fluctuations in CL&P’s sales volumes do not impact the level of base distribution revenue realized or earnings due to the PURA approved revenue decoupling mechanism.  CL&P’s revenue decoupling mechanism permits recovery of a base amount of distribution revenues ($1.059 billion annually) and breaks the relationship between sales volumes and revenues recognized.  The revenue decoupling mechanism results in the recovery of approved base distribution revenue requirements.  

Fluctuations in the overall level of operating revenues are primarily related to tracked revenues.  Tracked revenues consist of certain costs that are recovered from customers in rates through PURA-approved cost tracking mechanisms and therefore have no impact on earnings.  Costs recovered through cost tracking mechanisms include energy supply procurement and other energy-related costs, retail transmission charges, energy efficiency program costs and restructuring and stranded cost recovery revenues.  In addition, tracked revenues include certain incentives earned and carrying charges. Tracked distribution revenues increased primarily as a result of an increase in federally mandated congestion charges ($40.5 million), an increase in competitive transition assessment charges ($9.7 million) and an increase in retail transmission charges ($9.6 million).  In addition, as a result of a change to the amounts collected in the system benefits charge, CL&P’s calculated rate base increased, providing an increase to distribution revenues that impacted earnings of $8.2 million. Partially offsetting these increases was a decrease in energy supply costs ($27.1 million) driven by decreased average retail rates.

Transmission revenues increased by $13.1 million due primarily to higher revenue requirements associated with ongoing investments in our transmission infrastructure.


49



Nine Months Ended:
CL&P’s Operating Revenues decreased by $0.6 million for the nine months ended September 30, 2016, as compared to the same period in 2015.

Base distribution revenues increased by $19.4 million due to a higher rate base resulting from the 2015 PURA ADIT settlement agreement that is being collected from customers in distribution rates ($16.1 million) and the absence of an authorized ROE reduction, as stipulated in the PURA 2014 rate case decision, recorded in the first nine months of 2015 ($3.3 million).  

Tracked distribution revenues decreased primarily as a result of a decrease in energy supply costs ($187.1 million) driven by decreased average retail rates and lower sales volumes.  Partially offsetting this decrease was an increase in retail transmission charges ($27.4 million), an increase in federally mandated congestion charges ($70.4 million) and an increase in competitive transition assessment charges ($24 million).  In addition, as a result of a change to the amounts collected in the system benefits charge, CL&P’s calculated rate base increased, providing an increase to distribution revenues that impacted earnings of $17.5 million.

Transmission revenues increased by $49.3 million due primarily to higher revenue requirements associated with ongoing investments in our transmission infrastructure and the absence in 2016 of a $12.5 million reserve charge recorded in the first quarter of 2015 associated with the March 2015 FERC ROE order.

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 decreased for the three and nine months ended September 30, 2016, as compared to the same periods in 2015, due primarily to the following:
(Millions of Dollars)
Three Months Ended
Increase/(Decrease)
 
Nine Months Ended
Increase/(Decrease)
Purchased Power Costs
$
(37.0
)
 
$
(149.7
)
Transmission Costs
15.7

 
48.7

Total Purchased Power and Transmission
$
(21.3
)
 
$
(101.0
)

Included in purchased power costs are the costs associated with CL&P’s generation services charge (GSC) and deferred energy supply costs.  The GSC recovers energy-related costs incurred as a result of providing electric generation service supply to all customers who have not migrated to third party suppliers.  The decrease in purchased power costs for the three months ended September 30, 2016, compared to the same period in 2015, was due primarily to the deferral adjustment of energy supply costs, which can fluctuate from period to period based upon the timing of costs incurred and the related rate changes to recover these costs. The decrease in purchased power costs for the nine months ended September 30, 2016, compared to the same period in 2015, was due primarily to a decrease in the prices of standard offer supply, as well as lower sales volumes.  The increase in transmission costs was primarily the result of an increase in costs billed by ISO-NE that support regional grid investment. 

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 for the three months ended September 30, 2016, as compared to the same period in 2015, driven by a $2.1 million increase in tracked costs, which was primarily attributable to higher transmission expenses, partially offset by a $1.4 million decrease in non-tracked costs, which was primarily attributable to lower public liability claims.

Operations and Maintenance expense decreased for the nine months ended September 30, 2016, as compared to the same period in 2015, driven by a $4.2 million decrease in non-tracked costs, which was primarily attributable to lower public liability claims, lower employee-related expenses, reimbursement of legal fees in the second quarter of 2016, and the absence in 2016 of integration costs recorded in the first nine months of 2015, partially offset by higher storm restoration costs.  Tracked costs, which have no earnings impact, increased $2.3 million, which was primarily attributable to higher transmission expenses partially offset by lower bad debt expense.

Depreciation expense increased for the three and nine months ended September 30, 2016, as compared to the same periods in 2015, due primarily to higher utility plant in service balances.  

Amortization of Regulatory Assets/(Liabilities), Net expense (the costs of which are tracked) includes the deferral of energy supply and energy-related costs and the amortization of storm and other costs.  Amortization of Regulatory Assets/(Liabilities), Net increased for the three and nine months ended September 30, 2016, as compared to the same periods in 2015, 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.  The deferral adjusts expense to match the corresponding revenues.  Energy supply and energy-related costs, which are the primary drivers in amortization, are recovered from customers in rates and have no impact on earnings.   

Taxes Other Than Income Taxes expense increased for the three and nine months ended September 30, 2016, as compared to the same periods in 2015, due primarily to an increase in property taxes as a result of higher utility plant balances and an increase in gross earnings taxes (the costs of which are tracked).


50



Income Tax Expense increased for the three months ended September 30, 2016, as compared to the same period in 2015, due primarily to higher pre-tax earnings ($5.9 million), higher state income taxes ($0.8 million), and items that impact our tax rate as a result of regulatory treatment (flow-through items) and permanent differences ($4.3 million), partially offset by the true up of the return to provision impacts and a lower tax benefit from a reduction in tax reserves ($0.5 million).

Income Tax Expense increased for the nine months ended September 30, 2016, as compared to the same period in 2015, due primarily to higher pre-tax earnings ($19.6 million), higher state income taxes ($2.5 million), and flow-through items and permanent differences ($6.9 million), partially offset by the true up of the return to provision impacts and a lower tax benefit from a reduction in tax reserves ($0.5 million), and the excess tax benefit due to the adoption of new accounting guidance related to share-based payment transactions ($0.9 million).

EARNINGS SUMMARY

CL&P’s earnings increased $6.4 million for the three months ended September 30, 2016, as compared to the same period in 2015, due primarily to an increase in transmission earnings driven by a higher transmission rate base, and higher distribution revenues as a result of higher rate base and the absence of an authorized ROE reduction, as stipulated in the PURA 2014 rate case decision.  These favorable earnings impacts were partially offset by a higher effective tax rate, higher property and other taxes expense, and higher depreciation expense.

CL&P’s earnings increased $28.4 million for the nine months ended September 30, 2016, as compared to the same period in 2015, due primarily to an increase in transmission earnings driven by a higher transmission rate base as well as the absence in 2016 of the 2015 FERC ROE complaint proceedings reserve charge, higher distribution revenues as a result of higher rate base and the absence of an authorized ROE reduction, as stipulated in the PURA 2014 rate case decision, and lower operations and maintenance expense.  These favorable earnings impacts were partially offset by higher property and other taxes expense, a higher effective tax rate and higher depreciation expense.

LIQUIDITY

Cash totaled $8.6 million as of September 30, 2016, compared with $1.1 million as of December 31, 2015.

Eversource parent has a $1.45 billion commercial paper program allowing Eversource parent to issue commercial paper as a form of short-term debt, with intercompany loans to certain subsidiaries, including CL&P.  The weighted-average interest rate on the commercial paper borrowings as of September 30, 2016 and December 31, 2015 was 0.66 percent and 0.72 percent, respectively.  As of September 30, 2016 and December 31, 2015, there were intercompany loans from Eversource parent to CL&P of $108.5 million and $277.4 million, respectively.

Eversource parent, and certain of its subsidiaries, including CL&P, are parties to a five-year $1.45 billion revolving credit facility. Effective September 26, 2016, the revolving credit facility’s termination date was extended for one additional year to September 4, 2021.  There were no borrowings outstanding on the revolving credit facility as of September 30, 2016 or December 31, 2015.

CL&P had cash flows provided by operating activities of $614.4 million for the nine months ended September 30, 2016, as compared to $421.8 million in the same period of 2015.  The increase in operating cash flows was due primarily to a $124.7 million favorable impact due to the change in income tax payments made or refunds received during 2016, as compared to 2015, as well as the favorable impact of the timing of regulatory recoveries, primarily related to purchased power costs. Also contributing to the increase in cash flows was an increase in distribution rates due to higher rate base. Partially offsetting these favorable impacts was the timing of collections and payments related to our working capital items, including accounts receivable and accounts payable.  

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 portions of pension expense.  CL&P’s investments totaled $438.5 million for the nine months ended September 30, 2016.



51



RESULTS OF OPERATIONS – NSTAR ELECTRIC COMPANY AND SUBSIDIARY

The following provides the amounts and variances in operating revenues and expense line items in the statements of income for NSTAR Electric for the nine months ended September 30, 2016 and 2015 included in this combined Quarterly Report on Form 10-Q:  
 
For the Nine Months Ended September 30,
(Millions of Dollars)
2016
 
2015
 
Increase/(Decrease)
 
Percent
Operating Revenues
$
1,986.0

 
$
2,134.7

 
$
(148.7
)
 
(7.0
)%
Operating Expenses:
 
 
 
 
 

 
 

Purchased Power and Transmission
764.9

 
984.0

 
(219.1
)
 
(22.3
)
Operations and Maintenance
279.9

 
228.8

 
51.1

 
22.3

Depreciation
159.2

 
146.8

 
12.4

 
8.4

Amortization of Regulatory Assets/(Liabilities), Net
18.3

 
(10.6
)
 
28.9

 
(a)

Energy Efficiency Programs
212.9

 
164.8

 
48.1

 
29.2

Taxes Other Than Income Taxes
101.8

 
95.8

 
6.0

 
6.3

Total Operating Expenses
1,537.0

 
1,609.6

 
(72.6
)
 
(4.5
)
Operating Income
449.0

 
525.1

 
(76.1
)
 
(14.5
)
Interest Expense
62.2

 
57.2

 
5.0

 
8.7

Other Income, Net
7.6

 
3.6

 
4.0

 
(a)

Income Before Income Tax Expense
394.4

 
471.5

 
(77.1
)
 
(16.4
)
Income Tax Expense
154.5

 
187.4

 
(32.9
)
 
(17.6
)
Net Income
$
239.9

 
$
284.1

 
$
(44.2
)
 
(15.6
)%
(a) Percent greater than 100 not shown as it is not meaningful.  

Operating Revenues
NSTAR Electric’s retail sales volumes were as follows:
 
For the Nine Months Ended September 30,
 
2016
 
2015
 
Decrease
 
Percent
Retail Sales Volumes in GWh
15,746

 
16,260

 
(514
)
 
(3.2
)%

NSTAR Electric’s Operating Revenues, which consist of base distribution revenues and tracked revenues further described below, decreased by $148.7 million for the nine months ended September 30, 2016, as compared to the same period in 2015.  

Base distribution revenues:  Base distribution revenues, excluding LBR, decreased $15.9 million in the first nine months of 2016, driven by a 3.2 percent decrease in sales volumes due primarily to increased customer energy conservation efforts, including those resulting from company-sponsored energy efficiency programs, and the impact of the warmer than normal weather in the first quarter of 2016, as compared to much colder than normal temperatures in the first quarter of 2015.  NSTAR Electric is allowed to recover LBR related to reductions in sales volumes as a result of successful energy efficiency programs.

Also contributing to the decrease in operating revenues in the first nine months of 2016 was the absence of an $11 million benefit recorded in the first quarter of 2015 related to the Comprehensive Settlement Agreement associated with the recovery of LBR related to 2009 through 2011 energy efficiency programs.  

Tracked revenues:  Tracked revenues consist of certain costs that are recovered from customers in rates through DPU-approved cost tracking mechanisms and therefore have no impact on earnings.  Costs recovered through cost tracking mechanisms include energy supply costs, retail transmission charges, energy efficiency program costs, net metering for distributed generation and transition cost recovery revenues.  In addition, tracked revenues include certain incentives earned and carrying charges. Tracked distribution revenues decreased primarily as a result of a decrease in energy supply costs ($295.8 million) driven by decreased average retail rates and lower sales volumes.  Partially offsetting this decrease was an increase in retail transmission charges ($55.1 million), an increase in cost recovery related to energy efficiency programs ($47.8 million) and an increase in net metering revenues ($23 million).

Transmission revenues increased by $25.2 million due primarily to the recovery of higher revenue requirements associated with ongoing investments in our transmission infrastructure and the absence in 2016 of a $2.4 million reserve charge recorded in the first quarter of 2015 associated with the March 2015 FERC ROE order.


52



Purchased Power and Transmission expense includes costs associated with purchasing electricity on behalf of NSTAR Electric’s customers.  These energy supply costs are recovered from customers in DPU-approved cost tracking mechanisms, which have no impact on earnings (tracked costs).  Purchased Power and Transmission expense decreased for the nine months ended September 30, 2016, as compared to the same period in 2015, due primarily to the following:  
(Millions of Dollars)
Increase/(Decrease)
Purchased Power Costs
$
(297.3
)
Transmission Costs
78.2

Total Purchased Power and Transmission
$
(219.1
)

Included in purchased power costs are the costs associated with NSTAR Electric’s basic service charge and deferred energy supply costs.  The basic service charge recovers energy-related costs incurred as a result of providing electric generation service supply to all customers who have not migrated to third party suppliers.  The decrease in purchased power costs was due primarily to lower prices associated with the procurement of energy supply and lower sales volumes.  The increase in transmission costs was primarily the result of an increase in the retail transmission cost deferral, which reflects the actual costs of transmission service compared to estimated amounts billed to customers.

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 for the nine months ended September 30, 2016, as compared to the same period in 2015, driven by a $33.6 million increase in non-tracked costs, which was primarily attributable to the absence in 2016 of the resolution of the basic service bad debt adder mechanism recorded in the first quarter of 2015 ($24.2 million), higher vegetation management expense and higher storm restoration costs.  Additionally, there was a $17.5 million increase in tracked costs, which have no earnings impact, that was primarily attributable to higher employee-related expenses due to increased current year collections of a prior year pension and PBOP costs underrecovery and higher bad debt expense.

Depreciation expense increased for the nine months ended September 30, 2016, as compared to the same period in 2015, due primarily to higher utility plant in service balances.  

Amortization of Regulatory Assets/(Liabilities), Net reflects the absence in 2016 of an $11.7 million benefit recognized in the first quarter of 2015 relating to the Comprehensive Settlement Agreement, and the deferral adjustment of certain costs that exceeded billed revenues for the nine months ended September 30, 2016, as compared to the same period in 2015.  The deferral adjusts expense to match the corresponding revenues.  These deferred costs, which can fluctuate from period to period based on the timing of costs incurred and related rate changes to recover these costs, are recovered from customers in rates and have no impact on earnings.

Energy Efficiency Programs expense (the costs of which are tracked) increased for the nine months ended September 30, 2016, as compared to the same period in 2015, due primarily to the deferral adjustment, which reflects the actual costs billed to energy efficiency programs compared to the amount billed to customers and the timing of the recovery of energy efficiency costs incurred in accordance with the three-year program guidelines established by the DPU.  The deferral adjusts expense to match the energy efficiency programs revenue.  

Taxes Other Than Income Taxes expense increased for the nine months ended September 30, 2016, as compared to the same period in 2015, due primarily to an increase in property taxes as a result of higher utility plant balances.

Other Income, Net increased for the nine months ended September 30, 2016, as compared to the same period in 2015, due primarily to higher AFUDC on equity funds ($4.1 million).

Interest Expense increased for the nine months ended September 30, 2016, as compared to the same period in 2015, due primarily to higher interest on long-term debt ($8.2 million) as a result of new debt issuances, partially offset by an increase in AFUDC borrowed funds ($2 million).

Income Tax Expense decreased for the nine months ended September 30, 2016, as compared to the same period in 2015, due primarily to lower pre-tax earnings ($27.4 million), lower state income taxes ($4.6 million), items that impact our tax rate as a result of regulatory treatment (flow-through items) ($1.5 million), and the excess tax benefit due to the adoption of new accounting guidance related to share-based payment transactions ($1 million), partially offset by other items ($1.6 million).

EARNINGS SUMMARY

NSTAR Electric’s earnings decreased $44.2 million for the nine months ended September 30, 2016, as compared to the same period in 2015, due primarily to the absence in 2016 of both the 2015 resolution of the basic service bad debt adder mechanism ($14.5 million) and the 2015 favorable impact associated with the Comprehensive Settlement Agreement ($13 million), lower retail sales volumes, higher depreciation expense, and higher operations and maintenance expense.  These unfavorable earnings impacts were partially offset by an increase in transmission earnings, which was driven by a higher transmission rate base as well as the absence in 2016 of the 2015 FERC ROE complaint proceedings reserve charge.

53




LIQUIDITY

NSTAR Electric had cash flows provided by operating activities of $564.3 million for the nine months ended September 30, 2016, as compared to $502.3 million in the same period of 2015.  The increase in operating cash flows was due primarily to an increase in regulatory recoveries due to collections from customers in excess of purchased power costs costs and energy efficiency programs. In addition, the timing of accounts payable payments had a favorable impact on operating cash flows. Partially offsetting these favorable impacts was a $43.3 million reduction in income tax refunds in 2016, as compared to the same period in 2015 and an increase in Pension Plan contributions of $15.8 million in 2016, as compared to 2015 and changes related to working capital items.



54



RESULTS OF OPERATIONS – PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARY

The following provides the amounts and variances in operating revenues and expense line items in the statements of income for PSNH for the nine months ended September 30, 2016 and 2015 included in this combined Quarterly Report on Form 10-Q:  
 
For the Nine Months Ended September 30,
(Millions of Dollars)
2016
 
2015
 
Increase/(Decrease)
 
Percent
Operating Revenues
$
727.8

 
$
761.1

 
$
(33.3
)
 
(4.4
)%
Operating Expenses:
 

 
 

 
 

 
 

Purchased Power, Fuel and Transmission
155.7

 
200.5

 
(44.8
)
 
(22.3
)
Operations and Maintenance
187.2

 
200.1

 
(12.9
)
 
(6.4
)
Depreciation
86.5

 
78.0

 
8.5

 
10.9

Amortization of Regulatory Assets, Net
14.5

 
29.2

 
(14.7
)
 
(50.3
)
Energy Efficiency Programs
10.9

 
11.0

 
(0.1
)
 
(0.9
)
Taxes Other Than Income Taxes
64.5

 
61.4

 
3.1

 
5.0

Total Operating Expenses
519.3

 
580.2

 
(60.9
)
 
(10.5
)
Operating Income
208.5

 
180.9

 
27.6

 
15.3

Interest Expense
37.4

 
34.6

 
2.8

 
8.1

Other Income, Net
1.0

 
2.3

 
(1.3
)
 
(56.5
)
Income Before Income Tax Expense
172.1

 
148.6

 
23.5

 
15.8

Income Tax Expense
66.3

 
56.1

 
10.2

 
18.2

Net Income
$
105.8

 
$
92.5

 
$
13.3

 
14.4
 %

Operating Revenues
PSNH’s retail sales volumes were as follows:
 
For the Nine Months Ended September 30,
 
2016
 
2015
 
Decrease
 
Percent
Retail Sales Volumes in GWh
5,985

 
6,049

 
(64
)
 
(1.1
)%

PSNH’s Operating Revenues, which consist of base distribution revenues and tracked revenues further described below, decreased by $33.3 million for the nine months ended September 30, 2016, as compared to the same period in 2015.

Base distribution revenues:  Base distribution revenues increased $2.1 million due primarily to a $4.4 million increase as a result of distribution rate increases effective July 1, 2015 and July 1, 2016. Partially offsetting this increase was a 1.1 percent decrease in sales volumes due primarily to increased customer energy conservation efforts, including those resulting from company-sponsored energy efficiency programs, and the impact of the warmer than normal weather in the first quarter of 2016, as compared to much colder than normal temperatures in the first quarter of 2015.

Tracked revenues: Tracked revenues consist of certain costs that are recovered from customers in rates through NHPUC-approved cost tracking mechanisms and therefore have no impact on earnings.  Costs recovered through cost tracking mechanisms include energy supply costs and costs associated with the generation of electricity for customers, retail transmission charges, energy efficiency program costs and stranded cost recovery revenues.  In addition, tracked revenues include certain incentives earned and carrying charges. Tracked distribution revenues decreased primarily as a result of a decrease in energy supply costs and a reduction in wholesale generation revenues for the nine months ended September 30, 2016, as compared to the same period of 2015 ($39.6 million), driven by lower sales volumes.  In addition, stranded cost recovery and retail transmission charges decreased by $6.4 million and $3 million, respectively, for the nine months ended September 30, 2016, as compared to the same period in 2015.

Transmission revenues increased by $17.2 million due primarily to higher revenue requirements associated with ongoing investments in our transmission infrastructure and the absence in 2016 of a $1 million reserve charge recorded in the first quarter of 2015 associated with the March 2015 FERC ROE order.

Purchased Power, Fuel and Transmission expense includes costs associated with PSNH’s generation of electricity as well as purchasing electricity on behalf of its customers.  These generation and energy supply costs are recovered from customers in NHPUC-approved cost tracking mechanisms, which have no impact on earnings (tracked costs).  Purchased Power, Fuel and Transmission expense decreased for the nine months ended September 30, 2016, as compared to the same period in 2015, due primarily to the following:
(Millions of Dollars)
Increase/(Decrease)
Purchased Power and Generation Fuel Costs
$
(56.9
)
Transmission Costs
12.1

Total Purchased Power, Fuel and Transmission
$
(44.8
)


55



In order to meet the demand of customers who have not migrated to third party suppliers, PSNH procures power through power supply contracts and spot purchases in the competitive New England wholesale power market and/or produces power through its own generation.  The decrease in purchased power and generation fuel costs was due primarily to a decrease in the amount of electricity generated by PSNH facilities. The increase in transmission costs was primarily the result of an increase in costs billed by ISO-NE that support regional grid investment.

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 decreased for the nine months ended September 30, 2016, as compared to the same period in 2015, driven by a $9.9 million decrease in non-tracked costs that was primarily attributable to the absence in 2016 of a $5 million contribution recorded in the second quarter of 2015 to create a clean energy fund in connection with the generation divestiture agreement, and lower employee-related expenses.  Additionally, there was a $3 million decrease in tracked costs that was primarily attributable to lower contractor costs due to the timing of planned outages at PSNH’s generation facilities partially offset by higher transmission expenses, which have no earnings impact.

Depreciation expense increased for the nine months ended September 30, 2016, as compared to the same period in 2015, due primarily to higher utility plant in service balances.  

Amortization of Regulatory Assets, Net expense (the costs of which are tracked) includes the deferral of energy supply costs and the amortization of certain costs, which are recovered from customers in rates and have no impact on earnings.  The decrease for the nine months ended September 30, 2016, as compared to the same period in 2015, was due primarily to a decrease in the default energy service charge.  The deferral adjusts expense to match the corresponding revenues.  

Taxes Other Than Income Taxes expense increased for the nine months ended September 30, 2016, as compared to the same period in 2015, due primarily to an increase in property taxes as a result of higher utility plant balances.

Income Tax Expense increased for the nine months ended September 30, 2016, as compared to the same period in 2015, due primarily to higher pre-tax earnings ($8.2 million), higher state taxes ($1.2 million), and items that impact our tax rate as a result of regulatory treatment (flow-through items) and permanent differences ($1.2 million), partially offset by other items ($0.3 million) and the excess tax benefit due to the adoption of new accounting guidance related to share-based payment transactions ($0.4 million).

EARNINGS SUMMARY

PSNH’s earnings increased $13.3 million for the nine months ended September 30, 2016, as compared to the same period in 2015, due primarily to an increase in transmission earnings, which was driven by a higher transmission rate base as well as the absence in 2016 of the 2015 FERC ROE complaint proceedings reserve charge, higher generation earnings, lower operations and maintenance expense, and the impact of the distribution rate increases effective July 1, 2015 and July 1, 2016.  These favorable earnings impacts were partially offset by higher depreciation expense and lower retail sales volumes.

LIQUIDITY

PSNH had cash flows provided by operating activities of $306 million for the nine months ended September 30, 2016, as compared to $243.9 million in the same period of 2015.  The increase in operating cash flows was due primarily to the favorable impact of the timing of payments related to our accounts payable. In addition, income tax refunds of $41.3 million were received in 2016, compared to income tax payments of $5 million the same period in 2015. Partially offsetting these favorable impacts were an increase in Pension Plan contributions of $15.8 million in 2016 and the use of fuel inventories.


56



RESULTS OF OPERATIONS – WESTERN MASSACHUSETTS ELECTRIC COMPANY

The following provides the amounts and variances in operating revenues and expense line items in the statements of income for WMECO for the nine months ended September 30, 2016 and 2015 included in this combined Quarterly Report on Form 10-Q:  
 
For the Nine Months Ended September 30,
(Millions of Dollars)
2016
 
2015
 
Increase/(Decrease)
 
Percent
Operating Revenues
$
368.5

 
$
403.2

 
$
(34.7
)
 
(8.6
)%
Operating Expenses:
 

 
 

 
 

 
 

Purchased Power and Transmission
104.4

 
149.2

 
(44.8
)
 
(30.0
)
Operations and Maintenance
68.0

 
61.7

 
6.3

 
10.2

Depreciation
34.4

 
32.4

 
2.0

 
6.2

Amortization of Regulatory Assets, Net
3.3

 
11.2

 
(7.9
)
 
(70.5
)
Energy Efficiency Programs
33.6

 
32.7

 
0.9

 
2.8

Taxes Other Than Income Taxes
30.4

 
28.4

 
2.0

 
7.0

Total Operating Expenses
274.1

 
315.6

 
(41.5
)
 
(13.1
)
Operating Income
94.4

 
87.6

 
6.8

 
7.8

Interest Expense
18.3

 
19.0

 
(0.7
)
 
(3.7
)
Other Income, Net
0.1

 
2.4

 
(2.3
)
 
(95.8
)
Income Before Income Tax Expense
76.2

 
71.0

 
5.2

 
7.3

Income Tax Expense
30.1

 
28.6

 
1.5

 
5.2

Net Income
$
46.1

 
$
42.4

 
$
3.7

 
8.7
 %

Operating Revenues
WMECO’s retail sales volumes were as follows:
 
For the Nine Months Ended September 30,
 
2016
 
2015
 
Decrease
 
Percent
Retail Sales Volumes in GWh
2,695

 
2,742

 
(47
)
 
(1.7
)%

WMECO’s Operating Revenues, which consist of base distribution revenues and tracked revenues further described below, decreased by $34.7 million for the nine months ended September 30, 2016, as compared to the same period in 2015.

Fluctuations in WMECO’s sales volumes do not impact the level of base distribution revenue realized or earnings due to the DPU approved revenue decoupling mechanism.  WMECO’s revenue decoupling mechanism permits recovery of a base amount of distribution revenues ($132.4 million annually) and breaks the relationship between sales volumes and revenues recognized.  The revenue decoupling mechanism results in the recovery of approved base distribution revenue requirements.  

Fluctuations in the overall level of operating revenues are primarily related to tracked revenues.  Tracked revenues consist of certain costs that are recovered from customers in rates through DPU-approved cost tracking mechanisms and therefore have no impact on earnings.  Costs recovered through cost tracking mechanisms include energy supply costs, retail transmission charges, energy efficiency program costs, low income assistance programs, and restructuring and stranded cost recovery revenues.  In addition, tracked revenues include certain incentives earned and carrying charges. Tracked revenues decreased due primarily to a decrease in energy supply costs ($47.8 million) driven by decreased average retail rates and lower sales volumes.

Transmission revenues increased by $13.6 million due primarily to the absence in 2016 of a $4.1 million reserve charge recorded in the first quarter of 2015 associated with the March 2015 FERC ROE order and higher revenue requirements associated with ongoing investments in our transmission infrastructure.

Purchased Power and Transmission expense includes costs associated with the purchasing of energy supply on behalf of WMECO’s customers. These energy supply costs are recovered from customers in DPU-approved cost tracking mechanisms, which have no impact on earnings (tracked costs).  Purchased Power and Transmission expense decreased for the nine months ended September 30, 2016, as compared to the same period in 2015, due primarily to the following:
(Millions of Dollars)
Increase/(Decrease)
Purchased Power Costs
$
(51.3
)
Transmission Costs
6.5

Total Purchased Power and Transmission
$
(44.8
)


57



Included in purchased power costs are the costs associated with WMECO’s basic service charge and deferred energy supply costs.  The basic service charge recovers energy-related costs incurred as a result of providing electric generation service supply to all customers who have not migrated to third party suppliers.  The decrease in purchased power costs was due primarily to lower prices associated with the procurement of energy supply and lower sales volumes. The increase in transmission costs was primarily the result of an increase in costs billed by ISO-NE that support regional grid investment.

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 for the nine months ended September 30, 2016, as compared to the same period in 2015, driven by a $3.7 million increase in tracked costs, which have no earnings impact, that was primarily attributable to higher transmission expenses and the deferral of RECs generated and sold by the WMECO solar program, and an increase of $2.6 million in non-tracked costs that was primarily attributable to higher employee-related expenses and higher public liability claims.

Depreciation expense increased for the nine months ended September 30, 2016, as compared to the same period in 2015, due primarily to higher utility plant in service balances.  

Amortization of Regulatory Assets, Net expense (the costs of which are tracked) decreased for the nine months ended September 30, 2016, as compared to the same period in 2015, due to the timing of refunds or recovery of tracked costs from customers in rates.  These costs have no impact on earnings.

Taxes Other Than Income Taxes expense increased for the nine months ended September 30, 2016, as compared to the same period in 2015, due primarily to an increase in property taxes as a result of higher utility plant balances.

Other Income, Net decreased for the nine months ended September 30, 2016, as compared to the same period in 2015, due primarily to lower AFUDC on equity funds ($1.4 million) and a decrease in net gains related to the deferred compensation plans ($0.3 million).

Income Tax Expense increased for the nine months ended September 30, 2016, as compared to the same period in 2015, due primarily to higher pre-tax earnings ($1.9 million), partially offset by other items ($0.2 million) and the excess tax benefit due to the adoption of new accounting guidance related to share-based payment transactions ($0.2 million).

EARNINGS SUMMARY

WMECO’s earnings increased $3.7 million for the nine months ended September 30, 2016, as compared to the same period in 2015, due primarily to an increase in transmission earnings, which was driven by the absence in 2016 of the 2015 FERC ROE complaint proceedings reserve charge as well as a higher transmission rate base, and lower interest expense on long-term debt.  These favorable earnings impacts were partially offset by higher operations and maintenance expense, higher property and other taxes expense, and higher depreciation expense.

LIQUIDITY

WMECO had cash flows provided by operating activities of $124.8 million for the nine months ended September 30, 2016, as compared to $68 million in the same period of 2015.  The increase in operating cash flows was due primarily to the timing of collections of accounts receivable and an increase of $21 million in income tax refunds in 2016, as compared to the same period in 2015.


58



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 by maintaining a mix of fixed and variable rate long-term debt.  

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 September 30, 2016, our Regulated companies did not hold collateral (letters of credit) from counterparties related to our standard service contracts.  As of September 30, 2016, Eversource had $16.7 million of cash posted with ISO-NE related to energy purchase 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 2015 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 2015 Form 10-K.

ITEM 4.
CONTROLS AND PROCEDURES

Management, on behalf of Eversource, CL&P, NSTAR Electric, PSNH and WMECO, evaluated the design and operation of the disclosure controls and procedures as of September 30, 2016 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, PSNH and WMECO 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.

During the third quarter of 2016, we implemented a new time keeping and human resource system resulting in a material change in internal controls over financial reporting. These new systems standardized the timekeeping and human resource management for Eversource and provides for common time and employee data collection and reporting processes, practices and structures. Pre-implementation testing and post-implementation reviews were conducted by management to ensure that internal controls surrounding the system implementation process, the applications, and the closing process were properly designed to prevent material financial statement errors. Such procedures included the review of required documents, user acceptance testing, change management procedures, access controls, data migration strategies and reconciliations, application interface testing and other standard application controls.

There have been no changes, except previously discussed, in internal controls over financial reporting for Eversource, CL&P, NSTAR Electric, PSNH and WMECO during the quarter ended September 30, 2016 that have materially affected, or are reasonably likely to materially affect, internal controls over financial reporting.


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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 2015 Form 10-K.  These disclosures are incorporated herein by reference.  

In August 2013, the Yankee Companies each filed lawsuits against the DOE seeking recovery of actual damages incurred in the years 2009 through 2012, as described under the caption “Yankee Companies v. U.S. Department of Energy” “DOE Phase III Damages” in Part I, Item 3, “Legal Proceedings” of our 2015 Form 10-K. On March 25, 2016, the court issued its decision and awarded the Yankee Companies approximately $76.8 million of the $77.9 million in damages sought in Phase III. The decision became final on July 18, 2016, and the Yankee Companies received the awards from the DOE on October 14, 2016.  The Yankee Companies have filed a request with FERC seeking approval of the proposed distribution of certain amounts of the awarded damages proceeds to member companies, including CL&P, NSTAR Electric, PSNH, and WMECO. Subject to receipt of FERC approval, CYAPC and MYAPC expect to be able to make distributions in December 2016. MYAPC also anticipates refunding approximately $57 million from its spent nuclear fuel trust, a portion of which will be refunded to the Eversource utility subsidiaries. In total, Eversource expects to receive approximately $26 million, of which CL&P expects to receive $13.6 million, NSTAR Electric expects to receive $5 million, PSNH expects to receive $3.9 million, and WMECO expects to receive $3.6 million. These anticipated amounts will be refunded to the customers of the respective Eversource utility subsidiaries.

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 2015 Form 10-K and our Form 10-Q filed for the quarter ended June 30, 2016.

ITEM 1A.
RISK FACTORS

We are subject to a variety of significant risks in addition to the matters set forth under “Forward-Looking Statements,” 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 2015 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 2015 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 shares awarded under the Company’s Incentive Plan and Dividend Reinvestment Plan and 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)
July 1 – July 31, 2016
103,301

$
59.31



August 1 – August 31, 2016
5,468

56.26



September 1  – September 30, 2016
13,172

54.33



Total
121,941

$
58.63





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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)
 
 
 
12
 
Ratio of Earnings to Fixed Charges
 
 
 
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)
 
 
 
12
 
Ratio of Earnings to Fixed Charges
 
 
 
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)
 
 
 
12
 
Ratio of Earnings to Fixed Charges
 
 
 
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)
 
 
 
12
 
Ratio of Earnings to Fixed Charges
 
 
 
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
 
 
 
 
 
 
 
 
 
 
 
 

61



Listing of Exhibits (WMECO)
 
 
 
12
 
Ratio of Earnings to Fixed Charges
 
 
 
31
 
Certification by the Chairman of Western Massachusetts Electric Company pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
 
 
 
31.1
 
Certification by the Chief Financial Officer of Western Massachusetts Electric Company pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
 
 
 
32
 
Certification by the Chairman and the Chief Financial Officer of Western Massachusetts 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 (Eversource, CL&P, NSTAR Electric, PSNH, WMECO)
 
 
 
101.INS
 
XBRL Instance Document
 
 
 
101.SCH
 
XBRL Taxonomy Extension Schema
 
 
 
101.CAL
 
XBRL Taxonomy Extension Calculation
 
 
 
101.DEF
 
XBRL Taxonomy Extension Definition
 
 
 
101.LAB
 
XBRL Taxonomy Extension Labels
 
 
 
101.PRE
 
XBRL Taxonomy Extension Presentation


62



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
 
 
 
 
November 4, 2016
 
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
 
 
 
 
November 4, 2016
 
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
 
 
 
 
November 4, 2016
 
By:
/s/ Jay S. Buth
 
 
 
Jay S. Buth
 
 
 
Vice President, Controller and Chief Accounting Officer






63




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
 
 
 
 
November 4, 2016
 
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.





 
 
WESTERN MASSACHUSETTS ELECTRIC COMPANY
 
 
 
 
November 4, 2016
 
By:
/s/ Jay S. Buth
 
 
 
Jay S. Buth
 
 
 
Vice President, Controller and Chief Accounting Officer




64