UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
_________________________________ ________________________________________________________
Form 10-Q
(Mark One)
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x | QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
For the quarterly period ended March 31, 20182019
OR
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o | 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: 001-14206
El Paso Electric Company
(Exact name of registrant as specified in its charter)
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| | |
Texas | | 74-0607870 |
(State or other jurisdiction of incorporation or organization) | | (I.R.S. Employer Identification No.) |
| | |
Stanton Tower, 100 North Stanton Street, El Paso, Texas | | 79901 |
(Address of principal executive offices) | | (Zip Code) |
(915) 543-5711
(Registrant’s telephone number, including area code)
Indicate by check mark whether the registrant (1) has 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 registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. YES x NO o
Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). YES x NO o
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company or an emerging growth company. See the definitions of “large"large accelerated filer,” “accelerated" "accelerated filer,” “smaller" "smaller reporting company,”" and "emerging growth company" in Rule 12b-2 of the Exchange Act.
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| Large accelerated filer | x | Accelerated filer | o |
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| Non-accelerated filer | o | Smaller reporting company | o |
| | | | |
| | | Emerging growth company | o |
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. o
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). YES o NO x
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| | |
Securities registered pursuant to Section 12(b) of the Act: |
Title of each class | Trading symbol(s) | Name of each exchange on which registered |
Common Stock, No Par Value | EE | New York Stock Exchange |
As of April 30, 2018,2019, there were 40,664,75440,738,183 shares of the Company’s no par value common stock outstanding.
DEFINITIONS
The following abbreviations, acronyms or defined terms used in this report are defined below:
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| | |
Abbreviations, Acronyms or Defined Terms | | Terms |
| | |
A&G | | Administrative and general |
ABFUDC | | Allowance for Borrowed Funds Used During Construction |
AEFUDC | | Allowance for Equity Funds Used During Construction |
AFUDC | | Allowance for Funds Used During Construction |
ANPP Participation Agreement | | Arizona Nuclear Power Project Participation Agreement dated August 23, 1973, as amended |
AOCI | | Accumulated Other Comprehensive Income |
APS | | Arizona Public Service Company |
ARO | | Asset Retirement Obligations |
ASU | | Accounting Standards Update |
CAA | | Clean Air Act |
Company | | El Paso Electric Company |
CWIP | | Construction Work In Progress |
DOE | | U.S. Department of Energy |
El Paso | | City of El Paso, Texas |
Exchange Act | | The Securities Exchange Act of 1934, as amended |
FASB | | Financial Accounting Standards Board |
FERC | | Federal Energy Regulatory Commission |
Four Corners | | Four Corners Generating Station |
FPPCAC | | New Mexico Fuel and Purchased Power Cost Adjustment Clause |
GAAP | | U.S. Generally Accepted Accounting Principles |
HAFBGHG | | Holloman Air Force Base |
IRS | | U.S. Internal Revenue ServiceGreenhouse Gas |
kW | | Kilowatt(s) |
kWh | | Kilowatt-hour(s) |
Las Cruces | | City of Las Cruces, New Mexico |
MPS | | The Company's Montana Power Station |
MW | | Megawatt(s) |
MWh | | Megawatt-hour(s) |
NAV | | Net Asset Value |
Newman | | The Company's Newman Power Station |
NDT | | The Company's Palo Verde nuclear decommissioning trust funds |
Newman | | The Company's Newman Power Station |
NMPRC | | New Mexico Public Regulation Commission |
NMPRC Final Order | | NMPRC Final Order in Case No. 15-00127-UT |
NOL carryforwards | | Net Operating Loss carryforwards |
O&M | | Operations and maintenance |
Palo Verde | | Palo Verde Generating Station |
PCBs | | Pollution Control Refunding Revenue Bonds |
PUCT | | Public Utility Commission of Texas |
RCF | | The Company's Revolving Credit Facility |
RGEC | | Rio Grande Electric Cooperative |
RGRT | | Rio Grande Resources Trust II |
Rio Grande | | The Company's Rio Grande Power Station |
SAB 118ROU | | Right-of-use |
SEC Staff Accounting Bulletin | | U.S. Securities and Exchange Commission |
TCJA | | The federal legislation commonly referred to as the Tax Cuts and Jobs Act of 2017 |
U.S. | | United States |
2017 PUCT Final Order | | PUCT Final Order in Docket No. 11846831 |
2018 Form 10-K | | Annual Report of El Paso Electric Company on Form 10-K for the fiscal year ended December 31, 2018 |
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| | |
Abbreviations, Acronyms or Defined Terms | | Terms |
| | |
SEC | | U.S. Securities and Exchange Commission |
Texas Fuel Rule | | Texas fuel cost recovery rule |
TCJA | | The Federal Tax Cuts and Jobs Act of 2017 |
U.S. | | United States |
2016 PUCT Final Order | | PUCT Final Order in Docket No. 44941 |
2017 Form 10-K | | Annual Report of El Paso Electric Company on Form 10-K for the fiscal year ended December 31, 2017
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2017 PUCT Final Order | | PUCT Final Order in Docket No. 46831 |
EL PASO ELECTRIC COMPANY
INDEX TO FORM 10-Q
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Item 1. | | |
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Item 2. | | |
Item 3. | | |
Item 4. | | |
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Item 1. | | |
Item 1A. | | |
Item 2. | | |
Item 5. | | |
Item 6. | | |
PART I. FINANCIAL INFORMATION
| |
Item 1. | Financial Statements |
EL PASO ELECTRIC COMPANY
BALANCE SHEETS
| | | March 31, 2018 | | December 31, 2017 | March 31, 2019 | | December 31, 2018 |
| (Unaudited) | | (Unaudited) | |
| | | | | | |
ASSETS (In thousands) | | | | | | |
Utility plant: | | | | | | |
Electric plant in service | $ | 4,018,380 |
| | $ | 3,982,095 |
| $ | 4,227,687 |
| | $ | 4,181,409 |
|
Less accumulated depreciation and amortization | (1,332,076 | ) | | (1,320,175 | ) | (1,409,573 | ) | | (1,391,266 | ) |
Net plant in service | 2,686,304 |
| | 2,661,920 |
| 2,818,114 |
| | 2,790,143 |
|
Construction work in progress | 165,608 |
| | 146,059 |
| 176,891 |
| | 169,327 |
|
Nuclear fuel; includes fuel in process of $69,533 and $59,689, respectively | 204,778 |
| | 194,933 |
| |
Nuclear fuel; includes fuel in process of $73,105 and $62,833, respectively | | 208,552 |
| | 198,280 |
|
Less accumulated amortization | (84,229 | ) | | (74,475 | ) | (82,699 | ) | | (72,703 | ) |
Net nuclear fuel | 120,549 |
| | 120,458 |
| 125,853 |
| | 125,577 |
|
Net utility plant | 2,972,461 |
| | 2,928,437 |
| 3,120,858 |
| | 3,085,047 |
|
Current assets: | | | | | | |
Cash and cash equivalents | 2,574 |
| | 6,990 |
| 8,505 |
| | 12,900 |
|
Accounts receivable, principally trade, net of allowance for doubtful accounts of $1,820 and $2,300, respectively | 76,681 |
| | 88,585 |
| |
Restricted cash | | 38,445 |
| | — |
|
Accounts receivable, principally trade, net of allowance for doubtful accounts of $1,514 and $2,070, respectively | | 70,259 |
| | 77,855 |
|
Inventories, at cost | 49,919 |
| | 50,910 |
| 57,542 |
| | 55,432 |
|
Regulatory assets | | 7,272 |
| | 6,972 |
|
Prepayments and other | 10,781 |
| | 10,307 |
| 25,531 |
| | 20,375 |
|
Total current assets | 139,955 |
| | 156,792 |
| 207,554 |
| | 173,534 |
|
Deferred charges and other assets: | | | | | | |
Decommissioning trust funds | 284,082 |
| | 286,866 |
| 298,338 |
| | 276,905 |
|
Regulatory assets | 92,619 |
| | 96,036 |
| 74,107 |
| | 74,848 |
|
Other | 16,503 |
| | 16,232 |
| 17,713 |
| | 18,168 |
|
Total deferred charges and other assets | 393,204 |
| | 399,134 |
| 390,158 |
| | 369,921 |
|
Total assets | $ | 3,505,620 |
| | $ | 3,484,363 |
| $ | 3,718,570 |
| | $ | 3,628,502 |
|
See accompanying notes to financial statements.
EL PASO ELECTRIC COMPANY
BALANCE SHEETS (Continued)
| | | March 31, 2018 | | December 31, 2017 | March 31, 2019 | | December 31, 2018 |
| (Unaudited) | | (Unaudited) | |
CAPITALIZATION AND LIABILITIES (In thousands except for share data) | | | | | | |
Capitalization: | | | | | | |
Common stock, stated value $1 per share, 100,000,000 shares authorized, 65,666,420 and 65,694,829 shares issued, and 162,268 and 133,859 restricted shares, respectively | $ | 65,829 |
| | $ | 65,829 |
| |
Common stock, stated value $1 per share, 100,000,000 shares authorized, 65,678,261 and 65,707,156 shares issued, and 150,427 and 121,532 restricted shares, respectively | | $ | 65,829 |
| | $ | 65,829 |
|
Capital in excess of stated value | 325,227 |
| | 326,117 |
| 328,228 |
| | 328,480 |
|
Retained earnings | 1,180,114 |
| | 1,159,667 |
| 1,218,902 |
| | 1,227,471 |
|
Accumulated other comprehensive income (loss), net of tax | (32,321 | ) | | 11,058 |
| |
Accumulated other comprehensive loss, net of tax | | (37,127 | ) | | (38,784 | ) |
| 1,538,849 |
| | 1,562,671 |
| 1,575,832 |
| | 1,582,996 |
|
Treasury stock, 25,166,943 and 25,244,350 shares, respectively, at cost | (419,216 | ) | | (420,506 | ) | |
Treasury stock, 25,090,505 and 25,147,567 shares, respectively, at cost | | (417,943 | ) | | (418,893 | ) |
Common stock equity | 1,119,633 |
| | 1,142,165 |
| 1,157,889 |
| | 1,164,103 |
|
Long-term debt, net of current portion | 1,196,110 |
| | 1,195,988 |
| 1,286,111 |
| | 1,285,980 |
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Total capitalization | 2,315,743 |
| | 2,338,153 |
| 2,444,000 |
| | 2,450,083 |
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Current liabilities: | | | | | | |
Current maturities of long-term debt | | 36,550 |
| | 99,239 |
|
Short-term borrowings under the revolving credit facility | 233,067 |
| | 173,533 |
| 202,951 |
| | 49,207 |
|
Accounts payable, principally trade | 35,838 |
| | 59,270 |
| 46,911 |
| | 58,150 |
|
Taxes accrued | 26,478 |
| | 35,660 |
| 28,147 |
| | 37,139 |
|
Interest accrued | 19,060 |
| | 12,470 |
| 19,449 |
| | 16,478 |
|
Over-collection of fuel revenues | 14,190 |
| | 6,225 |
| |
Regulatory liabilities | | 26,484 |
| | 14,686 |
|
Other | 35,764 |
| | 29,067 |
| 41,000 |
| | 38,356 |
|
Total current liabilities | 364,397 |
| | 316,225 |
| 401,492 |
| | 313,255 |
|
Deferred credits and other liabilities: | | | | | | |
Accumulated deferred income taxes | 298,440 |
| | 305,023 |
| 326,849 |
| | 325,133 |
|
Accrued pension liability | 81,576 |
| | 83,838 |
| 85,012 |
| | 87,259 |
|
Accrued post-retirement benefit liability | 26,957 |
| | 26,417 |
| 25,134 |
| | 24,575 |
|
Asset retirement obligation | 95,098 |
| | 93,029 |
| 103,349 |
| | 101,108 |
|
Regulatory liabilities | 298,035 |
| | 296,685 |
| 298,615 |
| | 298,570 |
|
Other | 25,374 |
| | 24,993 |
| 34,119 |
| | 28,519 |
|
Total deferred credits and other liabilities | 825,480 |
| | 829,985 |
| 873,078 |
| | 865,164 |
|
Commitments and contingencies |
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Total capitalization and liabilities | $ | 3,505,620 |
| | $ | 3,484,363 |
| $ | 3,718,570 |
| | $ | 3,628,502 |
|
See accompanying notes to financial statements.
EL PASO ELECTRIC COMPANY
STATEMENTS OF OPERATIONS
(Unaudited)
(In thousands except for share data)
| | | Three Months Ended | | Twelve Months Ended | Three Months Ended | | Twelve Months Ended |
| March 31, | | March 31, | March 31, | | March 31, |
| 2018 | | 2017 | | 2018 | | 2017 | 2019 | | 2018 | | 2019 | | 2018 |
Operating revenues | $ | 175,713 |
| | $ | 171,335 |
| | $ | 921,175 |
| | $ | 900,462 |
| $ | 174,363 |
| | $ | 175,713 |
| | $ | 902,253 |
| | $ | 921,175 |
|
Energy expenses: | | | | | | | | |
Fuel | 41,054 |
| | 36,606 |
| | 189,517 |
| | 176,025 |
| |
Purchased and interchanged power | 11,134 |
| | 13,673 |
| | 57,143 |
| | 63,754 |
| |
| 52,188 |
| | 50,279 |
| | 246,660 |
| | 239,779 |
| |
Operating revenues net of energy expenses | 123,525 |
| | 121,056 |
| | 674,515 |
| | 660,683 |
| |
Other operating expenses: | | | | | | | | |
Operating expenses: | | | | | | | | |
Fuel and purchased power | | 48,326 |
| | 52,188 |
| | 225,247 |
| | 246,660 |
|
Operations and maintenance | 80,160 |
| | 79,187 |
| | 321,254 |
| | 317,518 |
| 80,413 |
| | 80,160 |
| | 335,136 |
| | 321,254 |
|
Depreciation and amortization | 23,814 |
| | 21,934 |
| | 92,723 |
| | 82,958 |
| 25,126 |
| | 23,814 |
| | 97,694 |
| | 92,723 |
|
Taxes other than income taxes | 15,507 |
| | 15,730 |
| | 70,640 |
| | 66,451 |
| 16,189 |
| | 15,507 |
| | 71,682 |
| | 70,640 |
|
| 119,481 |
| | 116,851 |
| | 484,617 |
| | 466,927 |
| 170,054 |
| | 171,669 |
| | 729,759 |
| | 731,277 |
|
Operating income | 4,044 |
| | 4,205 |
| | 189,898 |
| | 193,756 |
| 4,309 |
| | 4,044 |
| | 172,494 |
| | 189,898 |
|
Other income (deductions): | | | | | | | | | | | | | | |
Allowance for equity funds used during construction | 920 |
| | 815 |
| | 3,130 |
| | 5,502 |
| 1,001 |
| | 920 |
| | 3,534 |
| | 3,130 |
|
Investment and interest income, net | 5,155 |
| | 9,263 |
| | 34,745 |
| | 35,959 |
| 23,707 |
| | 5,155 |
| | 36,929 |
| | 34,745 |
|
Miscellaneous non-operating income | 3,136 |
| | 2,895 |
| | 12,292 |
| | 10,983 |
| 3,048 |
| | 3,136 |
| | 12,735 |
| | 12,292 |
|
Miscellaneous non-operating deductions | (2,743 | ) | | (2,828 | ) | | (11,494 | ) | | (11,513 | ) | (2,357 | ) | | (2,743 | ) | | (11,594 | ) | | (11,494 | ) |
| 6,468 |
| | 10,145 |
| | 38,673 |
| | 40,931 |
| 25,399 |
| | 6,468 |
| | 41,604 |
| | 38,673 |
|
Interest charges (credits): | | | | | | | | | | | | | | |
Interest on long-term debt and revolving credit facility | 17,988 |
| | 18,367 |
| | 72,591 |
| | 73,312 |
| 18,989 |
| | 17,988 |
| | 76,425 |
| | 72,591 |
|
Other interest | 4,654 |
| | 4,345 |
| | 18,479 |
| | 17,155 |
| 5,233 |
| | 4,654 |
| | 18,469 |
| | 18,479 |
|
Capitalized interest | (1,214 | ) | | (1,294 | ) | | (4,942 | ) | | (5,042 | ) | (1,532 | ) | | (1,214 | ) | | (5,801 | ) | | (4,942 | ) |
Allowance for borrowed funds used during construction | (898 | ) | | (791 | ) | | (3,082 | ) | | (4,116 | ) | (972 | ) | | (898 | ) | | (3,686 | ) | | (3,082 | ) |
| 20,530 |
| | 20,627 |
| | 83,046 |
| | 81,309 |
| 21,718 |
| | 20,530 |
| | 85,407 |
| | 83,046 |
|
Income (loss) before income taxes | (10,018 | ) | | (6,277 | ) | | 145,525 |
| | 153,378 |
| 7,990 |
| | (10,018 | ) | | 128,691 |
| | 145,525 |
|
Income tax (benefit) expense | (3,052 | ) | | (2,288 | ) | | 50,240 |
| | 54,791 |
| |
Income tax expense (benefit) | | 1,901 |
| | (3,052 | ) | | 31,321 |
| | 50,240 |
|
Net income (loss) | $ | (6,966 | ) | | $ | (3,989 | ) | | $ | 95,285 |
| | $ | 98,587 |
| $ | 6,089 |
| | $ | (6,966 | ) | | $ | 97,370 |
| | $ | 95,285 |
|
| | | | | | | | | | | | | | |
Basic earnings (loss) per share | $ | (0.17 | ) | | $ | (0.10 | ) | | $ | 2.35 |
| | $ | 2.43 |
| $ | 0.15 |
| | $ | (0.17 | ) | | $ | 2.39 |
| | $ | 2.35 |
|
| | | | | | | | | |
| | | | |
Diluted earnings (loss) per share | $ | (0.17 | ) | | $ | (0.10 | ) | | $ | 2.34 |
| | $ | 2.43 |
| $ | 0.15 |
| | $ | (0.17 | ) | | $ | 2.39 |
| | $ | 2.34 |
|
| | | | | | | | | | | | | | |
Dividends declared per share of common stock | $ | 0.335 |
| | $ | 0.310 |
| | $ | 1.340 |
| | $ | 1.240 |
| $ | 0.360 |
| | $ | 0.335 |
| | $ | 1.440 |
| | $ | 1.340 |
|
Weighted average number of shares outstanding | 40,491,194 |
| | 40,387,235 |
| | 40,440,189 |
| | 40,366,024 |
| 40,582,936 |
| | 40,491,194 |
| | 40,543,986 |
| | 40,440,189 |
|
Weighted average number of shares and dilutive potential shares outstanding | 40,491,194 |
| | 40,387,235 |
| | 40,563,625 |
| | 40,435,689 |
| 40,663,753 |
| | 40,491,194 |
| | 40,661,228 |
| | 40,563,625 |
|
See accompanying notes to financial statements.
EL PASO ELECTRIC COMPANY
STATEMENTS OF COMPREHENSIVE OPERATIONS
(Unaudited)
(In thousands)
| | | Three Months Ended | | Twelve Months Ended | Three Months Ended | | Twelve Months Ended |
| March 31, | | March 31, | March 31, | | March 31, |
| 2018 | | 2017 | | 2018 | | 2017 | 2019 | | 2018 | | 2019 | | 2018 |
Net income (loss) | $ | (6,966 | ) | | $ | (3,989 | ) | | $ | 95,285 |
| | $ | 98,587 |
| $ | 6,089 |
| | $ | (6,966 | ) | | $ | 97,370 |
| | $ | 95,285 |
|
Other comprehensive income (loss): | | | | | | | | | | | | | | |
Unrecognized pension and post-retirement benefit costs: | | | | | | | | | | | | | | |
Net gain (loss) arising during period | — |
| | — |
| | 12,634 |
| | (20,053 | ) | — |
| | — |
| | (5,898 | ) | | 12,634 |
|
Prior service benefit | — |
| | — |
| | — |
| | 32,697 |
| |
Reclassification adjustments included in net income for amortization of: | | | | | | | | | | | | | | |
Prior service benefit | (2,416 | ) | | (2,416 | ) | | (9,657 | ) | | (8,157 | ) | (2,186 | ) | | (2,416 | ) | | (9,427 | ) | | (9,657 | ) |
Net loss | 1,575 |
| | 1,694 |
| | 6,657 |
| | 5,436 |
| 843 |
| | 1,575 |
| | 5,655 |
| | 6,657 |
|
Net unrealized gains/losses on marketable securities: | | | | | | | | | | | | | | |
Net holding gains (losses) arising during period | (2,708 | ) | | 7,721 |
| | 14,846 |
| | 13,975 |
| 2,471 |
| | (2,708 | ) | | 1,107 |
| | 14,846 |
|
Reclassification adjustments for net (gains) losses included in net income | 518 |
| | (2,191 | ) | | (7,917 | ) | | (8,443 | ) | 829 |
| | 518 |
| | 1,756 |
| | (7,917 | ) |
Net losses on cash flow hedges: | | | | | | | | | | | | | | |
Reclassification adjustment for interest expense included in net income | 139 |
| | 130 |
| | 541 |
| | 506 |
| 148 |
| | 139 |
| | 577 |
| | 541 |
|
Total other comprehensive income (loss) before income taxes | (2,892 | ) | | 4,938 |
| | 17,104 |
| | 15,961 |
| 2,105 |
| | (2,892 | ) | | (6,230 | ) | | 17,104 |
|
Income tax benefit (expense) related to items of other comprehensive income (loss): | | | | | | | | | | | | | | |
Unrecognized pension and post-retirement benefit costs | 156 |
| | 193 |
| | (3,652 | ) | | (4,124 | ) | 265 |
| | 156 |
| | 2,144 |
| | (3,652 | ) |
Net unrealized (gains) losses on marketable securities | 435 |
| | (1,121 | ) | | (1,366 | ) | | (1,054 | ) | (665 | ) | | 435 |
| | (577 | ) | | (1,366 | ) |
Losses on cash flow hedges | (50 | ) | | (78 | ) | | (195 | ) | | (335 | ) | (48 | ) | | (50 | ) | | (143 | ) | | (195 | ) |
Total income tax benefit (expense) | 541 |
| | (1,006 | ) | | (5,213 | ) | | (5,513 | ) | (448 | ) | | 541 |
| | 1,424 |
| | (5,213 | ) |
Other comprehensive income (loss), net of tax | (2,351 | ) | | 3,932 |
| | 11,891 |
| | 10,448 |
| 1,657 |
| | (2,351 | ) | | (4,806 | ) | | 11,891 |
|
Comprehensive income (loss) | $ | (9,317 | ) | | $ | (57 | ) | | $ | 107,176 |
| | $ | 109,035 |
| $ | 7,746 |
| | $ | (9,317 | ) | | $ | 92,564 |
| | $ | 107,176 |
|
See accompanying notes to financial statements.
EL PASO ELECTRIC COMPANY
STATEMENTS OF CHANGES IN COMMON STOCK EQUITY
(In thousands except for share data)
|
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Common Stock | | Capital in Excess of Stated Value | | Retained Earnings | | Accumulated Other Comprehensive Income (Loss), Net of Tax | | Treasury Stock | |
Common Stock Equity |
| | | | | |
| Shares | | Amount | | | | | Shares | | Amount | |
Balances at December 31, 2018 | 65,828,688 |
| | $ | 65,829 |
| | $ | 328,480 |
| | $ | 1,227,471 |
| | $ | (38,784 | ) | | 25,147,567 |
| | $ | (418,893 | ) | | $ | 1,164,103 |
|
Restricted common stock grants and deferred compensation | | | | | (1,328 | ) | | | | | | (31,461 | ) | | 524 |
| | (804 | ) |
Performance share awards vested | | | | | 1,478 |
| | | | | | (39,923 | ) | | 665 |
| | 2,143 |
|
Stock awards withheld for taxes | | | | | (430 | ) | | | | | | 12,425 |
| | (207 | ) | | (637 | ) |
Forfeited restricted common stock | | | | | | | | | | | 2,566 |
| | (43 | ) | | (43 | ) |
Compensation paid in shares | | | | | 28 |
| | | | | | (669 | ) | | 11 |
| | 39 |
|
Net income | | | | | | | 6,089 |
| | | | | | | | 6,089 |
|
Other comprehensive income | | | | | | | | | 1,657 |
| | | | | | 1,657 |
|
Common stock, dividends declared, $0.36 per share | | | | | | | (14,658 | ) | | | | | | | | (14,658 | ) |
Balances at March 31, 2019 | 65,828,688 |
| | $ | 65,829 |
| | $ | 328,228 |
| | $ | 1,218,902 |
| | $ | (37,127 | ) | | 25,090,505 |
| | $ | (417,943 | ) | | $ | 1,157,889 |
|
|
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Common Stock | | Capital in Excess of Stated Value | | Retained Earnings | | Accumulated Other Comprehensive Income (Loss), Net of Tax | | Treasury Stock | |
Common Stock Equity |
| | | | | |
| Shares | | Amount | | | | | Shares | | Amount | |
Balances at December 31, 2017 | 65,828,688 |
| | $ | 65,829 |
| | $ | 326,117 |
| | $ | 1,159,667 |
| | $ | 11,058 |
| | 25,244,350 |
| | $ | (420,506 | ) | | $ | 1,142,165 |
|
Restricted common stock grants and deferred compensation | | | | | (560 | ) | | | | | | (30,800 | ) | | 513 |
| | (47 | ) |
Performance share awards vested | | | | | 360 |
| | | | | | (68,379 | ) | | 1,139 |
| | 1,499 |
|
Stock awards withheld for taxes | | | | | (725 | ) | | | | | | 20,389 |
| | (339 | ) | | (1,064 | ) |
Forfeited restricted common stock | | | | | | | | | | | 2,391 |
| | (40 | ) | | (40 | ) |
Compensation paid in shares | | | | | 35 |
| | | | | | (1,008 | ) | | 17 |
| | 52 |
|
Cumulative effect adjustment for financial instruments | | | | | | | 41,028 |
| | (41,028 | ) | | | | | | — |
|
Net loss | | | | | | | (6,966 | ) | | | | | | | | (6,966 | ) |
Other comprehensive loss | | | | | | | | | (2,351 | ) | | | | | | (2,351 | ) |
Common stock, dividends declared, $0.335 per share | | | | | | | (13,615 | ) | | | | | | | | (13,615 | ) |
Balances at March 31, 2018 | 65,828,688 |
| | $ | 65,829 |
| | $ | 325,227 |
| | $ | 1,180,114 |
| | $ | (32,321 | ) | | 25,166,943 |
| | $ | (419,216 | ) | | $ | 1,119,633 |
|
See accompanying notes to financial statements.
EL PASO ELECTRIC COMPANY
STATEMENTS OF CASH FLOWS
(Unaudited)
(In thousands)
| | | Three Months Ended | Three Months Ended |
| March 31, | March 31, |
| 2018 | | 2017 | 2019 | | 2018 |
Cash flows from operating activities: | | | | | | |
Net loss | $ | (6,966 | ) | | $ | (3,989 | ) | |
Adjustments to reconcile net loss to net cash provided by operating activities: | | | | |
Net income (loss) | | $ | 6,089 |
| | $ | (6,966 | ) |
Adjustments to reconcile net income (loss) to net cash provided by operating activities: | | | | |
Depreciation and amortization of electric plant in service | 23,814 |
| | 21,934 |
| 25,126 |
| | 23,814 |
|
Amortization of nuclear fuel | 10,404 |
| | 11,278 |
| 10,706 |
| | 10,404 |
|
Deferred income taxes, net | (3,964 | ) | | (3,209 | ) | 1,236 |
| | (3,964 | ) |
Allowance for equity funds used during construction | (920 | ) | | (815 | ) | (1,001 | ) | | (920 | ) |
Other amortization and accretion | 5,240 |
| | 4,988 |
| 5,173 |
| | 5,240 |
|
Net loss (gain) on decommissioning trust funds | 2,509 |
| | (2,191 | ) | |
Net losses (gains) on decommissioning trust funds | | (15,989 | ) | | 2,509 |
|
Other operating activities | 81 |
| | (165 | ) | 349 |
| | 81 |
|
Change in: | | | | | | |
Accounts receivable | 8,063 |
| | 8,663 |
| 8,352 |
| | 8,063 |
|
Inventories | 1,418 |
| | (1,638 | ) | (2,110 | ) | | 1,418 |
|
Prepayments and other | (2,603 | ) | | (2,494 | ) | (5,519 | ) | | (2,603 | ) |
Accounts payable | (23,324 | ) | | (13,766 | ) | (11,021 | ) | | (23,324 | ) |
Taxes accrued | (7,552 | ) | | (4,843 | ) | (8,827 | ) | | (7,552 | ) |
Interest accrued | 6,590 |
| | 6,097 |
| 2,971 |
| | 6,590 |
|
Net over-collection of fuel revenues | 7,965 |
| | 8,530 |
| 12,799 |
| | 7,965 |
|
Other current liabilities | 6,697 |
| | 648 |
| 1,599 |
| | 6,697 |
|
Deferred charges and credits | (1,216 | ) | | (2,896 | ) | (3,513 | ) | | (1,216 | ) |
Net cash provided by operating activities | 26,236 |
| | 26,132 |
| 26,420 |
| | 26,236 |
|
Cash flows from investing activities: | | | | | | |
Cash additions to utility property, plant and equipment | (66,924 | ) | | (53,867 | ) | (52,428 | ) | | (66,924 | ) |
Cash additions to nuclear fuel | (9,257 | ) | | (10,873 | ) | (9,502 | ) | | (9,257 | ) |
Insurance proceeds received for equipment | 4,175 |
| | 742 |
| — |
| | 4,175 |
|
Capitalized interest and AFUDC: | | | | | | |
Utility property, plant and equipment | (1,818 | ) | | (1,606 | ) | (1,973 | ) | | (1,818 | ) |
Nuclear fuel and other | (1,214 | ) | | (1,294 | ) | (1,532 | ) | | (1,214 | ) |
Allowance for equity funds used during construction | 920 |
| | 815 |
| 1,001 |
| | 920 |
|
Decommissioning trust funds: | | | | | | |
Purchases, including funding of $0.5 million and $1.1 million, respectively | (33,578 | ) | | (28,482 | ) | |
Purchases, including funding of $0.5 million and $0.5 million, respectively | | (37,613 | ) | | (33,578 | ) |
Sales and maturities | 31,663 |
| | 26,055 |
| 35,468 |
| | 31,663 |
|
Other investing activities | 526 |
| | (236 | ) | (724 | ) | | 526 |
|
Net cash used for investing activities | (75,507 | ) | | (68,746 | ) | (67,303 | ) | | (75,507 | ) |
Cash flows from financing activities: | | | | | | |
Dividends paid | (13,615 | ) | | (12,565 | ) | (14,658 | ) | | (13,615 | ) |
Borrowings under the revolving credit facility: | | | | | | |
Proceeds | 192,670 |
| | 128,339 |
| 215,196 |
| | 192,670 |
|
Payments | (133,136 | ) | | (75,735 | ) | (61,452 | ) | | (133,136 | ) |
Payment on purchase in lieu of redemption of pollution control bonds | | (63,500 | ) | | — |
|
Other financing activities | (1,064 | ) | | (679 | ) | (653 | ) | | (1,064 | ) |
Net cash provided by financing activities | 44,855 |
| | 39,360 |
| 74,933 |
| | 44,855 |
|
Net decrease in cash and cash equivalents | (4,416 | ) | | (3,254 | ) | |
Cash and cash equivalents at beginning of period | 6,990 |
| | 8,420 |
| |
Cash and cash equivalents at end of period | $ | 2,574 |
| | $ | 5,166 |
| |
Net increase (decrease) in cash, cash equivalents and restricted cash | | 34,050 |
| | (4,416 | ) |
Cash, cash equivalents and restricted cash at beginning of period | | 12,900 |
| | 6,990 |
|
Cash, cash equivalents and restricted cash at end of period | | $ | 46,950 |
| | $ | 2,574 |
|
See accompanying notes to financial statements.
EL PASO ELECTRIC COMPANY
NOTES TO FINANCIAL STATEMENTS
(Unaudited)
A. Principles of Preparation
These condensed financial statements should be read in conjunction with the financial statements and notes thereto in the Annual Report of El Paso Electric Company on Form 10-K for the fiscal year ended December 31, 20172018 ("20172018 Form 10-K"). Capitalized terms used in this report and not defined herein have the meaning ascribed to such terms in the 20172018 Form 10-K. In the opinion of the Company’s management, the accompanying financial statements contain all adjustments necessary to present fairly the financial position of the Company at March 31, 20182019 and December 31, 20172018; the results of its operations and comprehensive operations for the three and twelve months ended March 31, 20182019 and 20172018; changes in common stock equity and its cash flows for the three months ended March 31, 20182019 and 20172018. The results of operations and comprehensive operations for the three months ended March 31, 20182019 and 2018, and the cash flows for the three months ended March 31, 20182019 and 2018, are not necessarily indicative of the results to be expected for the full calendar year.
Pursuant to the rules and regulations of the United States ("U.S.") Securities and Exchange Commission ("SEC"), certain financial information has been condensed and certain footnote disclosures have been omitted. Such information and disclosures are normally included in financial statements prepared in accordance with U.S. Generally Accepted Accounting Principles ("GAAP").
Reclassification. Certain amounts in the financial statements for 2017 have been reclassified to conform with the 2018 presentation. The Company implemented Accounting Standards Update ("ASU") 2017-07, Compensation - Retirement Benefits, and ASU 2016-15, Statement of Cash Flows, in the first quarter of 2018, retrospective to all periods presented in the Company's financial statements. See "New Accounting Standards Adopted" below for further details.
Use of Estimates. The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. The Company evaluates its estimates on an on-going basis, including those related to depreciation, unbilled revenue, income taxes, fuel costs, pension and other post-retirement obligations and asset retirement obligations ("AROs"ARO"). Actual results could differ from those estimates.
Operating Revenues. The Company accrues revenues for services rendered, including unbilled electric service revenues. The Company recognizes revenue associated with contracts with customers when performance obligations under the terms of the contract with the customer are satisfied. Revenue is measured as the amount of consideration the Company receives in exchange for transferring goods or providing services to the customer. Taxes collected concurrently with revenue producing activities are excluded from revenue. Unbilled revenues are recorded for estimated amounts of energy delivered in the period following the customer's last billing cycle to the end of the reporting period. Unbilled revenues are estimated based on monthly generation volumes and by applying an average revenue/kilowatt-hour ("kWh") to the number of estimated kWhs delivered but not billed. Accounts receivable included accrued unbilled revenues of $20.019.3 million at March 31, 20182019 and $22.221.6 million at December 31, 20172018.
The Company’s Texas retail customers are billed under base rates and a fixed fuel factor approved by the Public Utility Commission of Texas ("PUCT"). The Company’s New Mexico retail customers are billed under base rates and a fuel adjustment clause that is adjusted monthly, as approved by the New Mexico Public Regulation Commission ("NMPRC"). The Company's Federal Energy Regulatory Commission ("FERC") sales for resale customers are billed under formula base rates and fuel factors and a fuel adjustment clause that is adjusted monthly. The Company’s recovery of fuel and purchased power expenses is subject to periodic reconciliations of actual fuel and purchased power expenses incurred to actual fuel revenues collected. The difference between fuel and purchased power expenses incurred and fuel revenues charged to customers is reflected as over/under-collection of fuel revenues, which is included in regulatory liabilities/assets - current in the balance sheets. See Part I, Item 1, Financial Statements, Note D of Notes to Financial Statements for further discussion.
Leases. The Company presents revenues netdetermines if an arrangement contains a lease and the classification of sales taxesthat lease at inception. Operating lease right-of-use (“ROU”) assets represent the Company’s right to use an underlying asset for the lease term and operating lease liabilities represent the obligation to make payments under the lease. ROU assets and lease liabilities are recognized at the lease commencement date based on the estimated present value of the minimum lease payments over the lease term. In determining lease terms, the Company considers any options to extend or terminate the lease that are reasonably certain of being exercised. As the Company’s leases do not include an implicit rate, the Company uses an estimated incremental borrowing rate, at lease commencement, to determine the present value of the future lease payments. In calculating the incremental borrowing rate, the Company takes into consideration recent debt issuances and other data for instruments with similar characteristics. The Company’s lease agreements do not contain residual value guarantees or restrictive covenants. For leases with lease and non-lease components, the Company has elected to account for the consideration as a single lease component. The Company has also elected not to record leases with a term of 12 months or less on the balance sheets. The operating lease ROU assets are included as part of electric plant in its statementsservice and lease liabilities are included as part of operations.current and non-current liabilities in the Company’s balance sheets.
EL PASO ELECTRIC COMPANY
NOTES TO FINANCIAL STATEMENTS
(Unaudited)
Depreciation. The Company routinely evaluates the depreciable service lives, cost of removal and salvage values of its property, plant and equipment. Depreciation is provided on a straight-line basis over the estimated remaining lives of the assets (ranging in average from 5 to 48 years). When property subject to composite depreciation is retired or otherwise disposed of in the normal course of business, its cost together with the cost of removal, less salvage is charged to accumulated depreciation. For other property dispositions, the applicable cost and accumulated depreciation is removed from the balance sheet accounts and a gain or loss is recognized.
New Accounting Standards Adopted
In MarchFebruary 2016, the Financial Accounting Standards Board ("FASB") issued ASU 2016-09, Compensation - Stock Compensation (Topic 718) Improvements to Employee Share-Based Payment Accounting, to simplify the accounting for share-based payment transactions, including the income tax consequences, classification of awards either as equity or liabilities, and classification on the statements of cash flows. The Company adopted the new standard effective January 1, 2017. The adoption of the new standard did not have a material impact on the Company’s financial condition, results of operations or cash flows. The
EL PASO ELECTRIC COMPANY
NOTES TO FINANCIAL STATEMENTS
(Unaudited)
cumulative effect of the adoption of the new standard was to increase net operating loss carryforward deferred tax assets and retained earnings by $0.2 million on January 1, 2017.
In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers (Topic 606), to provide a framework that replaces the existing revenue recognition guidance, and has since modified the standard with several ASUs. The standard provides that an entity should recognize the amount of revenue to which it expects to be entitled for the transfer of promised goods or services to customers. On January 1, 2018, the Company adopted the new accounting standard using the modified retrospective method. There was no cumulative effect adjustment at the initial application of the new standard. In addition, comparative information has not been restated and continues to be reported under the accounting standards in effect for those periods. The Company expects the ongoing impact of the new standard to be immaterial to net income. As required by the standard, revenues of $1.9 million related to reimbursed costs of energy efficiency programs approved by the Company's regulators are reported in operating revenues from customers prospectively, as opposed to being offset with associated costs within operations and maintenance. Related expenses of an equal amount are reported in operations and maintenance expenses. See Note B, Revenues, for additional information.
In January 2016, the FASB issued ASU 2016-01, Financial Instruments-Overall (Subtopic 825-10): Recognition and Measurement of Financial Assets and Liabilities, to enhance the reporting model for financial instruments by addressing certain aspects of recognition, measurement, presentation and disclosure. The Company adopted the new standard effective January 1, 2018. The adoption of ASU 2016-01 eliminates the requirements to classify investments in equity securities with readily determinable fair values into trading or available for sale and requires entities to measure equity investments at fair value and recognize any changes in fair value in the Statements of Operations. ASU 2016-01 requires a modified-retrospective approach and therefore comparative information has not been restated and continues to be reported under the accounting standards in effect for those periods. Upon adoption of the new standard, the Company recorded a cumulative effect adjustment, net of income taxes, to increase retained earnings by $41.0 million with an offset to accumulated other comprehensive income ("AOCI"). In addition, the Company recorded net losses of $3.8 million related to equity securities still held at March 31, 2018. In March 2018, the FASB issued ASU 2018-04, Investments - Debt Securities (Topic 320) and Regulated Operations (Topic 980), which provides clarification to ASU 2016-01.
In August 2016, the FASB issued ASU 2016-15, Statement of Cash Flows (Topic 230) Classification of Certain Cash Receipts and Cash Payments, to reduce diversity in practice in how certain cash receipts and cash payments are classified in the statement of cash flows. The Company adopted the new standard effective January 1, 2018. ASU 2016-15 was applied using a retrospective transition method to each period presented. Accordingly, the Company presented in the Statement of Cash Flows insurance proceeds received for equipment of $4.2 million and $0.7 million, respectively, for the three months ended March 31, 2018 and 2017 as cash inflows from investing activities.
In March 2017, the FASB issued ASU 2017-07, Compensation-Retirement Benefits (Topic 715) Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost. ASU 2017-07 amends Accounting Standards Codification 715, Compensation - Retirement Benefits, to require companies to present the service cost component of net benefit cost in the income statement line items where compensation cost is reported. Companies will present all other components of net benefit cost separately from the line item(s) that includes the service cost and outside of any subtotal of operating income. In addition, only the service cost component will be eligible for capitalization in assets. The Company adopted the new standard effective January 1, 2018. The amendments in ASU 2017-07 were applied retrospectively for the income statement presentation of the service cost component and the other components of net benefit costs. The Company elected to apply the practical expedient and used the amounts disclosed in its pension and other postretirement benefit plan note for the 2017 comparative period as the estimation basis for applying the retrospective presentation requirements. See Note J, Employee Benefits, for additional information.
In March 2018, the FASB issued ASU 2018-05, Income Taxes (Topic 740) Amendments to SEC Paragraphs Pursuant to SEC Staff Accounting Bulletin No. 118Update ("SAB 118"ASU"), to add various SEC paragraphs for clarification due to The Federal Tax Cuts and Jobs Act of 2017 ("TCJA"). The Company adopted ASU 2018-05 upon issuance and implemented SAB 118 in December of 2017 in conjunction with the enactment of the TCJA.
New Accounting Standards to be Adopted in the Future
In February 2016, the FASB issued ASU 2016-02, Leases (Topic 842), to increase transparency and comparability among organizations by recognizing lease assets and lease liabilities on the balance sheet and requiring qualitative and quantitative disclosures on leasing agreements. ASU 2016-02 maintains a distinction between finance leases and operating leases similar to the distinction under previous lease guidance for capital leases and operating leases. Effective January 1, 2019, the Company adopted ASU 2016-02 using the modified retrospective method, applying the transition provisions to the beginning of the period of adoption rather than to the earliest comparative period presented, which continues to be reported in accordance with previous lease guidance, Accounting Standards Codification Topic 840. The Company adopted the package of practical expedients, which does not require the Company to reassess: (i) whether an arrangement contained a lease, (ii) lease classification for any expired or existing leases, and (iii) initial direct costs for any expired or existing leases. The Company also adopted the practical expedient related to land easements, which allowed carry forward accounting treatment for existing land easements. The most significant impact of leases reportedadopting ASU 2016-02, as of January 1, 2019, was the recording of approximately $6.3 million of operating lease liabilities and related ROU assets with no cumulative effect adjustment to retained earnings. The Company anticipates the ongoing impact of the new standard to be immaterial to net income and cash flows. See Part I, Item 1, Financial Statements, Note I of Notes to Financial Statements for further discussion.
In February 2018, the FASB issued ASU 2018-02, Income Statement - Reporting Comprehensive Income (Topic 220), as a result of concerns raised due to the federal law commonly referred to as the Tax Cuts and Jobs Act of 2017 ("TCJA"). More specifically, because the remeasurement of deferred taxes due to the change in the Company's operating results and statement of cash flowsfederal corporate income tax rate is expectedrequired to be similarincluded in income from continuing operations, the tax effects of items within accumulated other comprehensive income ("AOCI") (referred to previous GAAP.as stranded tax effects) do not reflect the appropriate tax rate. ASU 2016-02 requires the recognition
EL PASO ELECTRIC COMPANY
NOTES TO FINANCIAL STATEMENTS
(Unaudited)
in the statement of financial position, by the lessee, of a liability to make lease payments (the lease liability) and a right-of-use asset representing its right to use the underlying asset for the lease term. How leases are recorded in regard to financial position represents a significant change from previous GAAP guidance. The lessee is permitted to make2018-02 allows companies an accounting policy election to not recognize lease assets and lease liabilities for short-term leases. Implementationreclassify stranded taxes from AOCI to retained earnings. The amount of the standard willreclassification would be requiredthe difference between the historical federal corporate income tax rate of 35% and the newly enacted 21% federal corporate income tax rate, which approximates $7.2 million. The provisions of ASU 2018-02 are effective for fiscal years and interim periods within that reporting periodsperiod beginning after December 15, 2018. Adoption of the new lease accounting standard will require the Company to apply the new standard to the earliest period using a modified retrospective approach. The Company is currentlyadopted ASU 2018-02 on January 1, 2019, and has elected to not reclassify stranded taxes from AOCI to retained earnings.
New Accounting Standards to be Adopted in the process of evaluating the impact of the new standard, which includes continuing to monitor activities of the FASB, including the impact of the recently issued ASU 2018-01, and the proposed project to allow entities to adopt the standard with a cumulative effect adjustment as of the beginning of the adoption year, while maintaining prior year comparative financial information and disclosures as reported. ASU 2018-01, Land Easement Practical expedient for Transition to Topic 842, provides an optional practical expedient to not evaluate existing or expired land easements under Topic 842, if those land easements were not previously accounted for as leases under Accounting Standards Codification ("ASC") Topic 840. The Company currently anticipates that it will apply the practical expedient under ASU 2018-01 to its existing or expired land easements as part of its transition to Topic 842. The Company's evaluation process also includes evaluating the impact, if any, on changes to business processes, systems and controls to support recognition and disclosure under the new guidance; however, at this time the Company is unable to determine the impact this standard will have on the financial statements and related disclosures.Future
In June 2016, the FASB issued ASU 2016-13, Financial Instruments - Credit Losses (Topic 326). ASU 2016-13 changes how companies measure and recognize credit impairment for many financial assets. The new current expected credit loss model will require companies to immediately recognize an estimate of credit losses expected to occur over the remaining life of the financial assets that are in the scope of the standard. The ASU also makes targeted amendments to the current impairment model for available-for-sale debt securities. ASU 2016-13 will be required for reporting periods beginning after December 15, 2019. ASU 2016-13 will be applied in a modified retrospective approach through a cumulative-effect adjustment to retained earnings as of the beginning of the first reporting period in which the guidance is implemented. The Company is currently assessing the future impact of ASU 2016-13.
In February 2018, the FASB issued ASU 2018-02, Income Statement - Reporting Comprehensive Income (Topic 220), as a result of concerns raised due to the TCJA. More specifically, because the remeasurement of deferred taxes due to the change in the federal corporate income tax rate is required to be included in income from continuing operations, the tax effects of items within AOCI (referred to as stranded tax effects) do not reflect the appropriate tax rate. ASU 2018-02 generally allows companies to reclassify stranded taxes from AOCI to retained earnings. The amount of the adjustment would be the difference between the historical federal corporate income tax rate of 35% and the newly enacted 21% federal corporate income tax rate. The provisions of ASU 2018-02 are effective for fiscal years and interim periods within that reporting period beginning after December 15, 2018. Early adoption is permitted, including adoption in any interim periods for reporting periods for which financial statements have not been issued. The Company is currently evaluating the impact of ASU 2018-02 and its impact on regulated utilities. At March 31, 2018, stranded taxes in AOCI are approximately $7.2 million.
|
| | | | | | | | |
Supplemental Cash Flow Disclosures (in thousands) | | | |
| | Three Months Ended |
| | March 31, |
| | 2018 | | 2017 |
Cash paid (received) for: | | | |
| Interest on long-term debt and borrowings under the revolving credit facility | $ | 11,967 |
| | $ | 11,721 |
|
| Income tax refunded, net | (1,060 | ) | | (697 | ) |
Non-cash investing and financing activities: | | | |
| Changes in accrued plant additions | (108 | ) | | (3,335 | ) |
| Grants of restricted shares of common stock | 513 |
| | 540 |
|
| Issuance of performance shares | 1,499 |
| | 932 |
|
EL PASO ELECTRIC COMPANY
NOTES TO FINANCIAL STATEMENTS
(Unaudited)
|
| | | | | | | | |
Supplemental Cash Flow Disclosures (in thousands) | | | |
| | Three Months Ended |
| | March 31, |
| | 2019 | | 2018 |
Cash paid (received) for: | | | |
| Interest on long-term debt and borrowings under the revolving credit facility | $ | 11,592 |
| | $ | 11,967 |
|
| Income tax refunded, net | (300 | ) | | (1,060 | ) |
Non-cash investing and financing activities: | | | |
| Changes in accrued plant additions | (218 | ) | | (108 | ) |
| Grants of restricted shares of common stock | 524 |
| | 513 |
|
| Issuance of performance shares | 2,143 |
| | 1,499 |
|
Non-cash operating activities: | | | |
| Operating lease liabilities arising from obtaining ROU assets | 6,217 |
| | — |
|
B. Revenues
On January 1, 2018, theThe Company adopted ASU 2014-09, Revenue from Contracts with Customers (Topic 606), on January 1, 2018, for all of its contracts using the modified retrospective method. There was no cumulative effect adjustment at the initial application of the new standard. In addition, comparative information has not been restated and continues to be reported under the accounting standards in effect for those periods. The Company expects the ongoing impact of the new standard to be immaterial to net income and no significant changes in the Company's business processes and internal controls were necessary upon adoption of the new standard.
The following table disaggregates revenue from contracts with customers, for the three and twelve months ended March 31, 2019 and 2018 (in thousands):
|
| | | | | | | | |
| | March 31, 2018 |
| | Three Months Ended | | Twelve Months Ended |
| Retail | $ | 146,628 |
| | $ | 826,148 |
|
| Wholesale | 24,143 |
| | 72,641 |
|
| Wheeling (transmission) | 4,286 |
| | 18,133 |
|
| Total revenues from contracts with customers | 175,057 |
| | 916,922 |
|
| Other | 656 |
| | 4,253 |
|
| Total operating revenues | $ | 175,713 |
| | $ | 921,175 |
|
The Company recognizes revenue when performance obligations under the terms of the contract with the customer are satisfied. Revenue is measured as the amount of consideration the Company receives in exchange for transferring goods or providing services to the customer. Taxes collected concurrently with revenue producing activities are excluded from revenue. The Company has elected the optional invoice practical expedient for Wholesale and Wheeling revenues, as the invoice amount will correspond directly to the value provided by the Company's performance to date.
Retail. Retail contracts represent the Company's primary revenue source. The Company has determined that retail electric service to residential, commercial and industrial, and public authority customers represents an implied daily contract with the customer. The contract is comprised of an obligation to supply and distribute electricity and related capacity. Revenue is recognized, over time, equal to the product of the applicable tariff rates, as approved by the Public Utility Commission of Texas (the "PUCT") and the New Mexico Public Regulation Commission, (the "NMPRC), and the volume of the electricity delivered to the customer, or through the passage of time based upon providing the service of standing ready. Unbilled revenues are recognized at month end based on estimated monthly generation volumes and by applying an average revenue per kWh to the number of estimated kWhs delivered but not billed to customers, and recorded as a receivable for the period following the last billing cycle to the end of the reporting period. Retail customers receive a bill monthly, with payment due sixteen days after issuance.
Wholesale. Wholesale contracts primarily include forward power sales into markets outside the Company’s service territory when the Company has competitive generation capacity available, after meeting its regulated service obligations. Pricing is either fixed or based on an index rate with consideration potentially including variable components. Uncertainties regarding the variable consideration will be resolved when the transaction price is known at the point of delivering the energy. The obligation to deliver the electricity is satisfied over time as the customer receives and consumes the electricity. Wholesale customers are invoiced on the 10th day of each month, with payment due by the 20th day of the month. In the case of the sale of renewable energy certificates, the transaction price is allocated to the performance obligation to deliver the confirmed quantity of the certificates based on the stand alone selling price of each certificate. Revenue is recognized as control of the certificates is transferred to the customer. The customer is invoiced upon the completed transfer of the certificates, with payment due within ten business days.Wholesalealso includes an annual agreement between the Company and one of its wholesale customers, Rio Grande Electric Cooperative (“RGEC”), which involves the provision of full requirements electric service from the Company to RGEC. The rates for this service are recalculated annually and require Federal Energy Regulatory Commission (“FERC”) approval.
Wheeling (transmission). Wheeling involves the Company providing point-to-point transmission service, which includes the receipt of capacity and energy at designated point(s) and the transfer of such capacity and energy to designated point(s) of delivery on either a firm or non-firm basis for periods of one year or less. The performance obligation to provide capacity and transmit
EL PASO ELECTRIC COMPANY
NOTES TO FINANCIAL STATEMENTS
(Unaudited)
energy is satisfied over time as the Company performs. Transmission customers are invoiced on a monthly basis, with payment due within twenty days of receipt of the invoice.
Other. Other includes alternative revenue program revenue relating to the Company’s potential bonus awards from the PUCT and the NMPRC mandated energy efficiency programs. Both the PUCT and the NMPRC allow for the potential to earn an incentive bonus if the Company achieves its approved energy efficiency goals under the applicable programs. The Company recognizes revenue related to the energy efficiency program incentives at the point in time that the amount is objectively determinable generally based upon an approved order from the regulator, is probable of recovery, and if it is expected to be collected within 24 months. Other revenue also includes (i) late payment fees, (ii) leasing income, and (iii) the Company’s allocated share, based on ownership, of sales of surplus effluent water from Palo Verde Generating Station (“Palo Verde”). |
| | | | | | | | | | | | | | | |
| Three Months Ended March 31, | | Twelve Months Ended March 31, |
| 2019 | | 2018 | | 2019 | | 2018 |
Retail | $ | 132,126 |
| | $ | 146,628 |
|
| $ | 775,174 |
| | $ | 826,148 |
|
Wholesale | 35,691 |
| | 24,143 |
|
| 102,221 |
| | 72,641 |
|
Wheeling (transmission) | 6,005 |
| | 4,286 |
| | 20,745 |
| | 18,133 |
|
Total revenues from contracts with customers | 173,822 |
| | 175,057 |
|
| 898,140 |
| | 916,922 |
|
Other | 541 |
| | 656 |
| | 4,113 |
| | 4,253 |
|
Total operating revenues | $ | 174,363 |
| | $ | 175,713 |
|
| $ | 902,253 |
| | $ | 921,175 |
|
Accounts receivable. Accounts receivable is principally comprised of revenue from contracts with customers. The Company recognizes expense for accounts that are deemed uncollectible in operating expense. The Company recognized $0.5$0.2 million and $3.2$2.5 million of uncollectible expense for the three and twelve months ended March 31, 2018,2019, respectively.
EL PASO ELECTRIC COMPANY
NOTES TO FINANCIAL STATEMENTS
(Unaudited)
C. Accumulated Other Comprehensive Income (Loss)
| | Upon adoption of ASU 2016-01, Financial Instruments-Overall, the Company recorded, on January 1, 2018, a cumulative effect adjustment, net of income taxes, to increase retained earnings by $41.0 million with an offset to AOCI. Changes in Accumulated Other Comprehensive Income (Loss) (net of tax) by component are presented below (in thousands): | |
Upon adoption of ASU 2016-01, Financial Instruments - Overall, the Company recorded, on January 1, 2018, a cumulative effect adjustment, net of income taxes, to increase retained earnings by $41.0 million with an offset to AOCI. Changes in Accumulated Other Comprehensive Income (Loss) (net of tax) by component are presented below (in thousands): | | Upon adoption of ASU 2016-01, Financial Instruments - Overall, the Company recorded, on January 1, 2018, a cumulative effect adjustment, net of income taxes, to increase retained earnings by $41.0 million with an offset to AOCI. Changes in Accumulated Other Comprehensive Income (Loss) (net of tax) by component are presented below (in thousands): |
| | Three Months Ended March 31, 2018 | | Three Months Ended March 31, 2017 | | Three Months Ended March 31, 2019 | | Three Months Ended March 31, 2018 |
| | Unrecognized Pension and Post-retirement Benefit Costs | | Net Unrealized Gains (Losses) on Debt Securities | | Net Losses on Cash Flow Hedges | | Accumulated Other Comprehensive Income (Loss) | | Unrecognized Pension and Post-retirement Benefit Costs | | Net Unrealized Gains (Losses) on Marketable Securities | | Net Losses on Cash Flow Hedges | | Accumulated Other Comprehensive Income (Loss) | | Unrecognized Pension and Post-retirement Benefit Costs | | Net Unrealized Gains (Losses) on Debt Securities | | Net Losses on Cash Flow Hedges | | Accumulated Other Comprehensive Income (Loss) | | Unrecognized Pension and Post-retirement Benefit Costs | | Net Unrealized Gains (Losses) on Debt Securities | | Net Losses on Cash Flow Hedges | | Accumulated Other Comprehensive Income (Loss) |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
Balance at beginning of period as previously reported | Balance at beginning of period as previously reported | $ | (17,790 | ) | | $ | 40,190 |
| | $ | (11,342 | ) | | $ | 11,058 |
| | $ | (23,928 | ) | | $ | 28,463 |
| | $ | (11,651 | ) | | $ | (7,116 | ) | Balance at beginning of period as previously reported | $ | (24,923 | ) | | $ | (2,942 | ) | | $ | (10,919 | ) | | $ | (38,784 | ) | | $ | (17,790 | ) | | $ | 40,190 |
| | $ | (11,342 | ) | | $ | 11,058 |
|
| Cumulative effect adjustment | — |
| | (41,028 | ) | | — |
| | (41,028 | ) | | — |
| | — |
| | — |
| | — |
| Cumulative effect adjustment | — |
| | — |
| | — |
| | — |
| | — |
| | (41,028 | ) | | — |
| | (41,028 | ) |
| Other comprehensive income before reclassifications | — |
| | (2,159 | ) | | — |
| | (2,159 | ) | | — |
| | 6,165 |
| | — |
| | 6,165 |
| Other comprehensive income before reclassifications | — |
| | 1,973 |
| | — |
| | 1,973 |
| | — |
| | (2,159 | ) | | — |
| | (2,159 | ) |
| Amounts reclassified from accumulated other comprehensive income (loss) | (685 | ) | | 404 |
| | 89 |
| | (192 | ) | | (529 | ) | | (1,756 | ) | | 52 |
| | (2,233 | ) | Amounts reclassified from accumulated other comprehensive income (loss) | (1,078 | ) | | 662 |
| | 100 |
| | (316 | ) | | (685 | ) | | 404 |
| | 89 |
| | (192 | ) |
Balance at end of period | Balance at end of period | $ | (18,475 | ) | | $ | (2,593 | ) | | $ | (11,253 | ) | | $ | (32,321 | ) | | $ | (24,457 | ) | | $ | 32,872 |
| | $ | (11,599 | ) | | $ | (3,184 | ) | Balance at end of period | $ | (26,001 | ) | | $ | (307 | ) | | $ | (10,819 | ) | | $ | (37,127 | ) | | $ | (18,475 | ) | | $ | (2,593 | ) | | $ | (11,253 | ) | | $ | (32,321 | ) |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | Twelve Months Ended March 31, 2018 | | Twelve Months Ended March 31, 2017 | | Twelve Months Ended March 31, 2019 | | Twelve Months Ended March 31, 2018 |
| | Unrecognized Pension and Post-retirement Benefit Costs | | Net Unrealized Gains (Losses) on Marketable Securities | | Net Losses on Cash Flow Hedges | | Accumulated Other Comprehensive Income (Loss) | | Unrecognized Pension and Post-retirement Benefit Costs | | Net Unrealized Gains (Losses) on Marketable Securities | | Net Losses on Cash Flow Hedges | | Accumulated Other Comprehensive Income (Loss) | | Unrecognized Pension and Post-retirement Benefit Costs | | Net Unrealized Gains (Losses) on Debt Securities | | Net Losses on Cash Flow Hedges | | Accumulated Other Comprehensive Income (Loss) | | Unrecognized Pension and Post-retirement Benefit Costs | | Net Unrealized Gains (Losses) on Marketable Securities | | Net Losses on Cash Flow Hedges | | Accumulated Other Comprehensive Income (Loss) |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
Balance at beginning of period as previously reported | Balance at beginning of period as previously reported | $ | (24,457 | ) | | $ | 32,872 |
| | $ | (11,599 | ) | | $ | (3,184 | ) | | $ | (30,256 | ) | | $ | 28,394 |
| | $ | (11,770 | ) | | $ | (13,632 | ) | Balance at beginning of period as previously reported | $ | (18,475 | ) | | $ | (2,593 | ) | | $ | (11,253 | ) | | $ | (32,321 | ) | | $ | (24,457 | ) | | $ | 32,872 |
| | $ | (11,599 | ) | | $ | (3,184 | ) |
| Cumulative effect adjustment | — |
| | (41,028 | ) | | — |
| | (41,028 | ) | | — |
| | — |
| | — |
| | — |
| Cumulative effect adjustment | — |
| | — |
| | — |
| | — |
| | — |
| | (41,028 | ) | | — |
| | (41,028 | ) |
| Other comprehensive income before reclassifications | 7,951 |
| | 11,927 |
| | — |
| | 19,878 |
| | 7,363 |
| | 11,327 |
| | — |
| | 18,690 |
| Other comprehensive income before reclassifications | (4,589 | ) | | 892 |
| | — |
| | (3,697 | ) | | 7,951 |
| | 11,927 |
| | — |
| | 19,878 |
|
| Amounts reclassified from accumulated other comprehensive income (loss) | (1,969 | ) | | (6,364 | ) | | 346 |
| | (7,987 | ) | | (1,564 | ) | | (6,849 | ) | | 171 |
| | (8,242 | ) | Amounts reclassified from accumulated other comprehensive income (loss) | (2,937 | ) | | 1,394 |
| | 434 |
| | (1,109 | ) | | (1,969 | ) | | (6,364 | ) | | 346 |
| | (7,987 | ) |
Balance at end of period | Balance at end of period | $ | (18,475 | ) | | $ | (2,593 | ) | | $ | (11,253 | ) | | $ | (32,321 | ) | | $ | (24,457 | ) | | $ | 32,872 |
| | $ | (11,599 | ) | | $ | (3,184 | ) | Balance at end of period | $ | (26,001 | ) | | $ | (307 | ) | | $ | (10,819 | ) | | $ | (37,127 | ) | | $ | (18,475 | ) | | $ | (2,593 | ) | | $ | (11,253 | ) | | $ | (32,321 | ) |
| | | | | | | | | | | | | | | | | |
EL PASO ELECTRIC COMPANY
NOTES TO FINANCIAL STATEMENTS
(Unaudited)
Amounts reclassified from Accumulated Other Comprehensive Income (Loss) for the three and twelve months ended March 31, 20182019 and 20172018 are as follows (in thousands):
| | Details about Accumulated Other Comprehensive Income (Loss) Components | Details about Accumulated Other Comprehensive Income (Loss) Components | | Three Months Ended March 31, | | Twelve Months Ended March 31, | | Affected Line Item in the Statements of Operations | Details about Accumulated Other Comprehensive Income (Loss) Components | | Three Months Ended March 31, | | Twelve Months Ended March 31, | | Affected Line Item in the Statements of Operations |
| 2018 | | 2017 | | 2018 | | 2017 | | | 2019 | | 2018 | | 2019 | | 2018 | |
| | | | | | | | | | | | | | | | | | |
Amortization of pension and post-retirement benefit costs: | Amortization of pension and post-retirement benefit costs: | | | | | | | | | | Amortization of pension and post-retirement benefit costs: | | | | | | | | | |
| Prior service benefit | | $ | 2,416 |
| | $ | 2,416 |
| | $ | 9,657 |
| | $ | 8,157 |
| | Miscellaneous non-operating income | Prior service benefit | | $ | 2,186 |
| | $ | 2,416 |
| | $ | 9,427 |
| | $ | 9,657 |
| | Miscellaneous non-operating income |
| Net loss | | (1,575 | ) | | (1,694 | ) | | (6,657 | ) | | (5,436 | ) | | Miscellaneous non-operating deductions | Net loss | | (843 | ) | | (1,575 | ) | | (5,655 | ) | | (6,657 | ) | | Miscellaneous non-operating deductions |
| | 841 |
| | 722 |
| | 3,000 |
| | 2,721 |
| | Income (loss) before income taxes | | 1,343 |
| | 841 |
| | 3,772 |
| | 3,000 |
| | Income (loss) before income taxes |
| Income tax effect | | (156 | ) | | (193 | ) | | (1,031 | ) | | (1,157 | ) | | Income tax (benefit) expense | Income tax effect | | (265 | ) | | (156 | ) | | (835 | ) | | (1,031 | ) | | Income tax (benefit) expense |
| | 685 |
| | 529 |
| | 1,969 |
| | 1,564 |
| | Net income (loss) | | 1,078 |
| | 685 |
| | 2,937 |
| | 1,969 |
| | Net income (loss) |
| | | | | | | | | | | | | | | | | | |
Marketable securities: | Marketable securities: | | | | | | | | | | Marketable securities: | | | | | | | | | |
| Net realized gain (loss) on sale of securities | | (518 | ) | | 2,191 |
| | 7,917 |
| | 8,443 |
| | Investment and interest income, net | Net realized gain (loss) on sale of securities | | (829 | ) | | (518 | ) | | (1,756 | ) | | 7,917 |
| | Investment and interest income, net |
| | (518 | ) | | 2,191 |
| | 7,917 |
| | 8,443 |
| | Income (loss) before income taxes | | (829 | ) | | (518 | ) | | (1,756 | ) | | 7,917 |
| | Income (loss) before income taxes |
| Income tax effect | | 114 |
| | (435 | ) | | (1,553 | ) | | (1,594 | ) | | Income tax (benefit) expense | Income tax effect | | 167 |
| | 114 |
| | 362 |
| | (1,553 | ) | | Income tax (benefit) expense |
| | (404 | ) | | 1,756 |
| | 6,364 |
| | 6,849 |
| | Net income (loss) | | (662 | ) | | (404 | ) | | (1,394 | ) | | 6,364 |
| | Net income (loss) |
| | | | | | | | | | | | | | | | | | |
Loss on cash flow hedge: | Loss on cash flow hedge: | | | | | | | | | | Loss on cash flow hedge: | | | | | | | | | |
| Amortization of loss | | (139 | ) | | (130 | ) | | (541 | ) | | (506 | ) | | Interest on long-term debt and revolving credit facility | Amortization of loss | | (148 | ) | | (139 | ) | | (577 | ) | | (541 | ) | | Interest on long-term debt and revolving credit facility |
| | (139 | ) | | (130 | ) | | (541 | ) | | (506 | ) | | Income (loss) before income taxes | | (148 | ) | | (139 | ) | | (577 | ) | | (541 | ) | | Income (loss) before income taxes |
| Income tax effect | | 50 |
| | 78 |
| | 195 |
| | 335 |
| | Income tax (benefit) expense | Income tax effect | | 48 |
| | 50 |
| | 143 |
| | 195 |
| | Income tax (benefit) expense |
| | (89 | ) | | (52 | ) | | (346 | ) | | (171 | ) | | Net income (loss) | | (100 | ) | | (89 | ) | | (434 | ) | | (346 | ) | | Net income (loss) |
| | | | | | | | | | | | | | | | | | |
| Total reclassifications | | $ | 192 |
| | $ | 2,233 |
| | $ | 7,987 |
| | $ | 8,242 |
| | Total reclassifications | | $ | 316 |
| | $ | 192 |
| | $ | 1,109 |
| | $ | 7,987 |
| |
| | |
EL PASO ELECTRIC COMPANY
NOTES TO FINANCIAL STATEMENTS
(Unaudited)
D. Regulation
General
The rates and services of the Company are regulated by incorporated municipalities in Texas, the PUCT, the NMPRC and the FERC. Municipal orders, ordinances and other agreements regarding rates and services adopted by Texas municipalities are subject to review and approval by the PUCT. The FERC has jurisdiction over the Company's wholesale (sales for resale)resale - full requirement customer) transactions, transmission service and compliance with federally-mandated reliability standards. The decisions of the PUCT, the NMPRC and the FERC are subject to judicial review.
Texas Regulatory Matters
2015 Texas Retail Rate Case Filing. On August 10, 2015, the Company filed with the City of El Paso, other municipalities incorporated in its Texas service territory, and the PUCT in Docket No. 44941, a request for an annual increase in non-fuel base revenues ("2015 Texas Retail Rate Case").
On July 21, 2016, the parties to PUCT Docket No. 44941 filed the Joint Motion to Implement Uncontested Amended and Restated Stipulation and Agreement which was unopposed by the parties. On August 25, 2016, the PUCT issued the PUCT Final Order in Docket No. 44941 ("2016 PUCT Final Order"). The 2016 PUCT Final Order provided for: (i) an annual non-fuel base rate increase, lower annual depreciation expense, a revised return on equity for allowance for funds used during construction ("AFUDC") purposes, and the inclusion of substantially all new plant in service in rate base; (ii) an additional annual non-fuel base rate increase of $3.7 million related to Four Corners Generating Station ("Four Corners") costs, which was collected through a surcharge that terminated on July 11, 2017; (iii) removing the separate rate treatment for residential customers with solar systems that the Company had proposed in its August 10, 2015 filing; (iv) allowing the Company to recover $3.1 million in rate case expenses through a separate surcharge; and (v) allowing the Company to recover revenues associated with the relate back of rates to consumption on and after January 12, 2016 through March 31, 2016 through a separate surcharge.
Interim rates associated with the annual non-fuel base rate increase became effective on April 1, 2016. The additional surcharges associated with the incremental Four Corners costs, rate case expenses and the relate back of rates to consumption on and after January 12, 2016 through March 31, 2016, were implemented on October 1, 2016.
For financial reporting purposes, the Company deferred any recognition of the Company's request in its 2015 Texas Retail Rate Case until it received the 2016 PUCT Final Order on August 25, 2016. Accordingly, it reported in the third quarter of 2016 the cumulative effect of the 2016 PUCT Final Order, which related back to January 12, 2016.
2017 Texas Retail Rate Case Filing. On February 13, 2017, the Company filed with the City of El Paso, other municipalities incorporated in the Company's Texas service territory and the PUCT in Docket No. 46831,the 2017 Texas Retail Rate Case, a request for an increase in non-fuel base revenues ("2017 Texas Retail Rate Case").revenues. On November 2, 2017, the Company filed the Joint Motion to Implement Uncontested Stipulation and Agreement with the Administrative Law Judges for the 2017 Texas Retail Rate Case.
On December 18, 2017, the PUCT issued the PUCT Final Order in Docket No. 46831 ("2017 PUCT Final Order"), which provides, among other things, for the following: (i) an annual non-fuel base rate increase of $14.5 million; (ii) a return on equity of 9.65%; (iii) all new plant in service as filed in the Company's rate filing package was prudent and used and useful and therefore is included in rate base; (iv) recovery of the costs of decommissioning Four Corners Generating Station ("Four Corners") in the amount of $5.5 million over a seven year period beginning August 1, 2017; (v) the Company to recover reasonable rate case expenses of approximately $3.4 million through a separate surcharge over a three year period; and (vi) a requirement that the Company file a refund tariff if the federal statutory income tax rate, as it relates to the Company, is decreased before the Company files its next rate case. The 2017 PUCT Final Order also established baseline revenue requirements for recovery of future transmission and distribution investment costs (for which the Company could seek recovery after January 1, 2019) and includes a minimum monthly bill of $30.00 for new residential customers with distributed generation, such as private rooftop solar. Additionally, the 2017 PUCT Final Order allowsallowed for the annual recovery of $2.1 million of nuclear decommissioning funding and establishes annual depreciation expense that is approximately $1.9 million lower than the annual amount requested by the Company in its initial filing. Finally, the 2017 PUCT Final Order allowsallowed for the Company to recover revenues associated with the relate back of rates to consumption on and after July 18, 2017, through a separate surcharge.surcharge, which expired on January 9, 2019, with a reconciliation of any over-or under-charge to be addressed in a separate proceeding.
New base rates, including additional surcharges associated with rate case expenses and the relate back of rates to consumption on and after July 18, 2017, through December 31, 2017, were implemented in January 2018.
EL PASO ELECTRIC COMPANY
NOTES TO FINANCIAL STATEMENTS
(Unaudited)
rates expired on January 9, 2019.
For financial reporting purposes, the Company deferred any recognition of the Company's request in its 2017 Texas Retail Rate Case until it received the 2017 PUCT Final Order on December 18, 2017. Accordingly, it reported in the fourth quarter of 2017 the cumulative effect of the 2017 PUCT Final Order, which related back to July 18, 2017.
The 2017 PUCT Final Order required the Company to file a refund tariff if the federal statutory income tax rate, as it relates to the Company, werewas decreased before the Company files its next general rate case. Following the enactment of the TCJA on December 22, 2017, and in compliance with the 2017 PUCT Final Order, on March 1, 2018, the Company filed with the PUCT and each of its Texas municipalities a proposed refund tariff designed to reduce base charges for Texas customers equivalent to the expected annual decrease of $22.7 million in federal income tax expense resulting from the TCJA changes and an additional refund of $4.3 million for the amortization of a regulatory liability related to the reduced tax law changes.expense for the months of January through March of 2018. This filing was assigned PUCT Docket No. 48124. On March 27, 2018, the PUCT approved the Company's proposed refund tariff on an interim basis, subject to refund or surcharge, for customer billing effective April 1, 2018. Each of the Company's municipalities also implemented the Company's proposed tax credits on an interim basis effective April 1, 2018. The refund will beis reflected in rates over a period of aone year beginning April 1, 2018, and will be updated annually until new base rates are implemented pursuant to the Company's next Texas rate case filing. No party requested a hearing inThe PUCT issued an order on December 10, 2018, approving the case beforeproposed refund tariff. On February 22, 2019, the Company filed with the PUCT byand each of its Texas municipalities an application to modify the deadline of April 16, 2018, and on April 18, 2018,tax refund tariff to remove the PUCT Staff filed its final recommendation supporting approvalportion of the Company's application. The refund tariff case is pendingbase rate credit associated with the refund tariff subject to final action by the incorporated municipalities in the Company's Texas service territory and a final order from the PUCT.$4.3 million of regulatory liability amortization, which expired March 31, 2019. The filing was assigned PUCT Docket No. 49251.
EL PASO ELECTRIC COMPANY
NOTES TO FINANCIAL STATEMENTS
(Unaudited)
Texas Energy Efficiency Cost Recovery Factor. On May 1, 2017, the Company filed its annual application with the PUCT, which was assigned PUCT Docket No. 47125, to establish its energy efficiency cost recovery factor for 2018. In addition to projected energy efficiency costs for 2018 and a reconciliation of collections to prior year actual costs, the Company requested approval of an incentive bonus for the 2016 energy efficiency program results in accordance with PUCT rules. Interim rates were approved effective January 1, 2018. The Company, the PUCT Staff and the City of El Paso reached an agreement that includes an incentive bonus of $0.8 million. The agreement was filed on January 25, 2018, and was approved by the PUCT on February 15, 2018.
On May 1, 2018, the Company filed its annual application with the PUCT, which was assigned PUCT Docket No. 48332, to establish its energy efficiency cost recovery factor for 2019. In addition to projected energy efficiency costs for 2019 and a reconciliation of collections to actual costs for the prior year, actual costs, the Company requested approval of a $1.1$1.0 million incentive bonus for the 2017 energy efficiency program results in accordance with PUCT rules. Instead of convening a live hearing on the merits of this case, the parties agreed to enter into the record the pre-filed testimony of the parties and certain other exhibits and then file briefs on the contested issues. The Administrative Law Judge issued a proposal for decision on November 15, 2018, including the Company's fully requested incentive bonus. On January 17, 2019, the PUCT issued a final order approving a modified bonus amount of $0.9 million.
On May 1, 2019, the Company filed its annual application with the PUCT, which was assigned PUCT Docket No. 49496, to establish its energy efficiency cost recovery factor for 2020. In addition to projected energy efficiency costs for 2020 and a reconciliation of collections to actual costs for the prior year, the Company anticipates requesting an approval for an amount to be determined for the 2018 energy efficiency program results in accordance with PUCT rules. The Company cannot predict the outcome of this filing at this time.
Fuel and Purchased Power Costs. The Company's actual fuel costs, including purchased power energy costs, net of the cost of off-system sales and related shared margins, are recovered from customers through a fixed fuel factor. The PUCT has adopted thea fuel cost recovery rule ("Texas Fuel Rule") that allows the Company to seek periodic adjustments to its fixed fuel factor. The Company can seek to revise its fixed fuel factor based upon the approved formula at least four months after its last revision except in the month of December. The Texas Fuel Rule requires the Company to request to refund fuel costs in any month when the over-recovery balance exceeds a threshold material amount and it expects fuel costs to continue to be materially over-recovered. The Texas Fuel Rule also permits the Company to seek to surcharge fuel under-recoveries in any month the balance exceeds a threshold material amount and it expects fuel cost recovery to continue to be materially under-recovered. Fuel overover- and under-recoveries are considered material when they exceed 4% of the previous twelve months' fuel costs. All such fuel revenue and expense activities are subject to periodic final review by the PUCT in periodic fuel reconciliation proceedings.
On November 30, 2016, the Company filed a request, which was assigned PUCT Docket No. 46610, to increase its fixed fuel factor by approximately 28.8% to reflect increased fuel expenses primarily related to an increase in the price of natural gas used to generate power. The increase in the fixed fuel factor was effective on an interim basis January 1, 2017 and approved by the PUCT on January 10, 2017.
On October 13, 2017, the Company filed a request with the PUCT, which was assigned PUCT Docket No. 47692, to decrease the Texas fixed fuel factor by approximately 19% to reflect decreased fuel expenses primarily related to a decrease in the price of natural gas used to generate power. The decrease in the Texas fixed fuel factor became effective beginning with the November 2017 billing month.
On April 13, 2018, the Company filed a request with the PUCT, which was assigned PUCT Docket No. 48264, to decrease the Texas fixed fuel factor by approximately 29% to reflect decreased fuel expenses primarily related to a decrease in the price of natural gas used to generate power. On April 25, 2018, the Company's proposed fuel factors were approved on an interim basis effective for the first billing cycle of the May 2018 billing month. If no partyThe revised factor was approved by the PUCT and the docket closed on May 22, 2018.
On October 15, 2018, the Company filed a request with the PUCT, which was assigned PUCT Docket No. 48781, to decrease the case requestsTexas fixed fuel factor by approximately 6.99% to reflect decreased fuel expenses primarily related to a hearing by May 14,decrease in the price of natural gas used to generate power. On October 25, 2018, the Company's fixed fuel factors will become final as provided byfactor was approved on an interim basis effective for the PUCT's rules and no further actionfirst billing cycle of the November 2018 billing month. The revised factor was approved by the PUCT is required.and the docket closed on November 19, 2018. The Texas fixed fuel factor will continue thereafter until changed by the PUCT. As of March 31, 2018,2019, the Company had a net fuel over-recovery balance of approximately $13.3$19.3 million in Texas.
On April 29, 2019, the Company filed a petition with the PUCT, which was assigned PUCT Docket No. 49482, requesting authority to implement, beginning on June 1, 2019, a four-month, interim fuel refund of $19.4 million in fuel cost over-recoveries, including interest, for the period from April 2016 through March 2019. The Company cannot predict the outcome of this filing at this time.
EL PASO ELECTRIC COMPANY
NOTES TO FINANCIAL STATEMENTS
(Unaudited)
Fuel Reconciliation Proceeding. On September 27, 2016, the Company filed an application with the PUCT, designated as PUCT Docket No. 46308, to reconcile $436.6 million of Texas fuel and purchased power expenses incurred during the period of April 1, 2013, through March 31, 2016. On June 29, 2017, the PUCT approved a settlement in this proceeding. The settlement providesprovided for the reconciliation of fuel and purchased power costs incurred from April 1, 2013, through March 31, 2016. Additionally, the settlement modifies and tightens the Palo Verde performance rewards measurement bands beginning with the 2018 performance period. The financial results for the twelve months ended March 31, 2018, includeincluded a $5.0 million, pre-tax increase to income reflecting the settlement of the Texas fuel reconciliation proceeding. This amount represents Palo Verde Generating Station ("Palo Verde") performance rewards associated with the 2013 to 2015 performance periods net of disallowed fuel and purchased power costs as approved in the settlement. Additionally, the settlement modified and tightened the Palo Verde performance rewards measurement bands beginning with the 2018 performance period.
The April 1, 2016, through March 31, 2019, Texas jurisdictional fuel and purchased power costs subject to prudence review are costs from April 1, 2016 through March 31, 2018, thatby the PUCT later this year total approximately $271.3$361.5 million.
Community Solar. On June 8, 2015, the Company filed a petition with the PUCT to initiate a community solar program that includes the construction and ownership of a 3 Megawattsthree-megawatt ("MW") solar photovoltaic system located at Montana Power Station ("MPS"). Participation is on a voluntary basis, and customers contract for a set capacity (kW) amount and receive all energy produced. This case was assigned PUCT Docket No. 44800. The Company filed a settlement agreement among all parties on July 1, 2016, approving the program, and the PUCT approved the settlement agreement and program on September 1, 2016. On April 19, 2017, the Company announced that the entire 3 MWthree-MW program was fully subscribed by approximately 1,500 Texas customers. The community solarCommunity Solar facility began commercial operation on May 31, 2017.
On March 20, 2018, the Company filed a petition with the PUCT and each of its regulatory authoritiesTexas municipalities to expand its community solar program in Texas to include 2 MWtwo-MW of solar powered generation from the 10 MWten-MW solar photovoltaic facility located at Newman Power Station ("Newman") and to reduce rates under the community solar tariff. The case before the PUCT was assigned PUCT Docket No. 48181, and a hearing was held on December 4, 2018. The Administrative Law Judge issued a proposal for decision on March 19, 2019, that approved the project as proposed by the Company. The Company awaits a final order from the PUCT and cannot predict the outcome of the case at this time.
Transmission Cost Recovery Factor. On January 25, 2019, the Company filed an application with the PUCT to establish its Transmission Cost Recovery Factor ("TCRF"), which was assigned PUCT Docket No. 49148 (the "2019 TCRF rate filing"). The 2019 TCRF rate filing is designed to recover a requested $8.2 million of Texas jurisdictional transmission revenue requirement that is not currently pending.being recovered in the Company's Texas base rates for transmission-related investments placed in service from October 1, 2016, through September 30, 2018, net of retirements. On April 30, 2019, the Company revised the request to $8.1 million to reflect a reclassified item that would likely be included in a future Distribution Cost Recovery Factor ("DCRF") filing. The Company cannot predict the outcome of this filing at this time.
Distribution Cost Recovery Factor. The Company filed an application with the PUCT and each of its Texas municipalities to establish its DCRF on March 28, 2019 (the "2019 DCRF rate filing"). The case was assigned PUCT Docket No. 49395. The 2019 DCRF rate filing is designed to recover a $7.9 million Texas jurisdictional revenue requirement that is not currently being recovered in the Company’s Texas base rates for distribution-related investments placed in service from October 1, 2016, through December 31, 2018, net of retirements. The Company cannot predict the outcome of this filing at this time.
Other Required Approvals. The Company has obtained other required approvals for tariffs and other approvals required by the Texas Public Utility Regulatory Act and the PUCT.
New Mexico Regulatory Matters
2015 New Mexico Rate Case Filing. On May 11, 2015, the Company filed a request with the NMPRC, in Case No. 15-00127-UT, for an annual increase in non-fuel base rates. On June 8, 2016, the NMPRC issued the NMPRC Final Order in Case No. 15-00127-UT ("NMPRC Final Order"), which approved an annual increase in non-fuel base rates of approximately $0.6 million, an increase of approximately $0.5 million in other service fees and a decrease in the Company's allowed return on equity to 9.48%. The NMPRC Final Order concluded that all of the Company's new plant in service was reasonable and necessary and therefore would be recoverable in rates. The Company's rates were approved by the NMPRC effective July 1, 2016, and implemented at such time.
Future New Mexico Rate Case Filing. On April 12, 2017, the NMPRC issued an order in Case No. 15-00109-UT requiring the Company to make a rate filing in New Mexico no later than July 31, 2019, using an appropriate historical test year period. The Company expects to file its New Mexico rate case using a December 31, 2018, historical test year period on July 31, 2019.
New Mexico Order Commencing Review of the Effects of the TCJA on Regulated New Mexico Utilities. On January 24, 2018, the NMPRC initiated a proceeding in Case No. 18-00016-UT intoon the impact of the TCJA on New Mexico regulated utilities. On February 23, 2018, the Company responded to a NMPRC Staff inquiry regarding the proceeding. On April 4, 2018, the NMPRC issued an order requiring the Company to file a proposed interim rate rider to adjust the Company’sCompany's New Mexico base revenues in amounts equivalent to the Company’sCompany's reduced income tax expense for New Mexico customers resulting from the TCJA, to be implemented on or before May 1, 2018. The NMPRC order further requires that the Company record and track a regulatory liability for the excess accumulated deferred income taxes created by the change in the federal corporate income tax rate, consistent with
EL PASO ELECTRIC COMPANY
NOTES TO FINANCIAL STATEMENTS
(Unaudited)
the effective date of the TCJA, and subject to amortization determined by the NMPRC in the Company’sCompany's next general rate case. The Company recorded such a regulatory liability during the quarter ended December 31, 2017. On April 16, 2018, after consultation with the New Mexico Attorney General pursuant to the NMPRC order, the Company filed an interim rate rider with the NMPRC with a proposed effective date of May 1, 2018. The annualized credits expected to be refunded to New Mexico customers approximate $4.9 million. On April 25, 2018,The Company implemented the NMPRC approved the Company's interim rate rider to be implemented in customer bills beginning May 1, 2018 pursuant to the NMPRC order.
On September 5, 2018, the NMPRC issued an order in Case No. 17-00255-UT involving Southwestern Public Service Company’s ("SPS’s") request to change rates in which the NMPRC directed SPS to refund the difference in corporate tax rate from January 1, 2018, through the effective date of new rates. SPS appealed the NMPRC order to the New Mexico Supreme Court in Southwestern Public Service Co. v. NMPRC, No. S-1-SC-37248 ("SPS Appeal No. 1"), challenging the refund as prohibited retroactive ratemaking among other reasons. The New Mexico Supreme Court issued a partial and interim stay of the rates on September 26, 2018. On September 12, 2018, the NMPRC in Case No. 18-00016-UT issued an Order Regarding the Disposition of Tax Savings Under the Federal Tax Cuts and Jobs Act of 2017, which put public utilities on notice that all revenue collected through general rates for the purpose of payment of federal income taxes is and will continue to be subject to possible refund upon a subsequent determination to be made in the appropriate pending or future NMPRC adjudicatory hearing. On October 11, 2018, SPS filed a Notice of Appeal of that NMPRC order to the New Mexico Supreme Court in Southwestern Public Service Co. v. NMPRC, No. S-1-SC-37308 ("SPS Appeal No. 2"). On February 15, 2019, the NMPRC and SPS filed a joint motion for remand and stipulated dismissal of SPS appeals of NMPRC orders with the New Mexico Supreme Court, which among other things, reflected agreements between the NMPRC and SPS, which in part provide that the NMPRC will replace the order in Case No. 17-00255-UT with a new order that eliminates the retroactive TCJA refund and that SPS will request dismissal of SPS Appeals No. 1 and No. 2. On February 28, 2019, the New Mexico Supreme Court remanded SPS Appeal No. 1 back to the NMPRC and dismissed the appeal. On March 6, 2019, the NMPRC issued a revised final order on remand in Case No. 17-00255-UT that, in part, eliminated the retroactive TCJA refund.
Fuel and Purchased Power Costs. Historically,Pursuant to NMPRC Rule 550, fuel and purchased power costs, werenet of the cost of off-system sales and related shared margins, are reconciled to actual costs on a monthly basis and recovered or refunded to customers the second succeeding month through base rates and athe Fuel and Purchased Power Cost Adjustment Clause ("FPPCAC") that accounts. Additionally, the Renewable Portfolio Standard ("RPS") costs for changes in the costs of fuel relative to the amount included in base rates. Effective July 1, 2016, with the implementation of the NMPRC Final Order, fuel and purchased power
EL PASO ELECTRIC COMPANY
NOTES TO FINANCIAL STATEMENTS
(Unaudited)
costs are no longer recovered through base rates butNew Mexico are recovered through a separate RPS Cost Rider that is updated annually. The Company must file an application for continued use of its FPPCAC no more than four years from the FPPCAC. The Company'sdate its last FPPCAC was continued. As required, the Company filed a request to reconcilecontinue use of its Fuel and Purchased Power Cost Adjustment Clause ("FPPCAC") with the NMPRC on January 5, 2018, which was assigned Case No. 18-00006-UT. The NMPRC issued a final order in the case on February 13, 2019, which authorized the Company to continue use of its FPPCAC without change and approved the Company's reconciliation of its fuel and purchased power costs for the period January 1, 20132015, through December 31, 2014, also was approved in Case No. 15-00127-UT.2016. New Mexico jurisdictional costs subject to prudence review are costs from January 1, 20152017, through March 31, 20182019, that total approximately $181.0$96.4 million. At March 31, 2018,2019, the Company had a net fuel over-recovery balance of approximately $0.9$2.5 million related to the FPPCAC in New Mexico. As required,
New Mexico Renewable Portfolio Standard. Effective January 1, 2018, pursuant to the Company filed a request to continue use of its FPPCAC with the NMPRC on January 5, 2018, which was assignedfinal order in NMPRC Case No. 18-00006-UT. Hearings17-00090-UT, the RPS costs for New Mexico are recovered through a separate RPS Cost Rider and not through the FPPCAC. At March 31, 2019, the Company had a net fuel over-recovery balance related to the RPS Cost Rider of approximately $1.9 million. The RPS Cost Rider is updated in an annual NMPRC filing, including a reconciliation of the case are scheduled to begin in July 2018.prior year’s RPS costs and RPS Cost Rider revenue.
5 MW5-MW Holloman Air Force Base ("HAFB") Facility Certificate of Convenience and Necessity ("CCN"). On October 7, 2015, in NMPRC Case No. 15-00185-UT, the NMPRC issued a final order approving a CCN for a 5 MWfive-MW solar power generation facility located on HAFB in the Company's service territory in New Mexico. The Company and HAFB negotiated a retail contract, which includes a power sales agreement for the facility, to replace the existing load retention agreement whichthat was approved by NMPRC final order issued October 5, 2016, in NMPRC Case No. 16-00224-UT. Construction of theThe solar generation facility is expected to be completed in the third quarter ofbegan commercial operation on October 18, 2018.
New Mexico Efficient Use of Energy Recovery Factor. On July 1, 2016, the Company filed its annual application with the NMPRC requesting approval of its 2017 Energy Efficiency and Load Management Plan and to establish energy efficiency costthe Efficient Use of Energy recovery factorsfactor ("EUERF") for 2017. In addition to projected energy efficiency costs for 2017, the Company requested approval of a $0.4 million incentive for 2017 energy efficiency programs in accordance with NMPRC rules. This caseapplication was assigned Case No. 16-00185-UT. On February 22, 2017, the NMPRC issued a final order approving the Company’s 2017 Energy Efficiency and Load Management Plan and authorizing recovery in 2017 of a base incentive of $0.4 million.Plan. The Company’s energy efficiency cost recovery factors wereEUERF was approved and effective in customer bills beginning on March 1, 2017. NMPRC rules authorize continuation of the energy efficiency programs and incentive approved in Case
EL PASO ELECTRIC COMPANY
NOTES TO FINANCIAL STATEMENTS
(Unaudited)
No. 16-00185-UT through 2018. The Company recorded approved incentives in operating revenues of $0.3 million and $0.7 million in 2018 and 2017, respectively, related to its 2015 through 2017 Energy Efficiency and Load Management Plans.
On July 1, 2016,2, 2018, the Company filed its 2015 Annual Reportrequired application with the NMPRC for approval of its 2019-2021 Energy Efficiency Programs, which included anand Load Management Plan and EUERF. The application includes a request for a base incentive of 7.1% of program expenditures, or approximately $0.4 million annually for verified 2015 program performance of $0.3 million, which2019-2021. The application was approved inassigned Case No. 13-00176-UT.18-00116-UT and hearings were held on November 7, 2018, and November 8, 2018. The Company recordedHearing Examiner issued a Recommended Decision on January 30, 2019, and a final order was adopted by the $0.3 million approved incentive in operating revenues in the first quarter of 2017. In addition,NMPRC, with minor program modifications, on June 30, 2017, the Company filed its 2016 Annual Report for Energy Efficiency Programs, which included an incentive for verified 2016 program performance of $0.4 million that was approved in Case No. 13-00176-UT. The Company recorded the $0.4 million approved incentive in operating revenues in the third quarter of 2017.March 6, 2019.
Community Solar. On April 24, 2018, the Company filed a petitionan application with the NMPRC to initiate a community solar program in New Mexico to include construction and ownership of a 2 MWtwo-MW solar photovoltaic system located in Doña Ana County near the City of Las Cruces. Customer participation will bewould have been on a voluntary basis, and customers will contractwould have contracted for a set capacity (kW) amount and receivewould have received all energy produced by their subscribed capacity. The application was assigned Case No. 18-00099-UT and was dismissed without prejudice on October 31, 2018. The NMPRC set aside its October 31, 2018, order dismissing the application without prejudice, and on December 19, 2018, the NMPRC issued an Order Requiring El Paso Electric Company to Conduct Request for Proposals and to Amend Application; Order Extending Statutory Period and Appointing Hearing Examiner that would have required the Company to amend its initially-filed application on or before February 15, 2019. However, on January 10, 2019, the NMPRC with three new Commissioners reconsidered its prior order and dismissed the Community Solar application without prejudice. The case is now closed.
Integrated Resource Plan. On September 17, 2018, the Company filed its Integrated Resource Plan with the NMPRC for the period 2018-2037 ("2018 IRP") in Case No. 18-00293-UT as required by regulation and the Joint Stipulation in NMPRC Case No. 15-00241-UT, which was the Company's prior integrated resource plan filing. The triennial filing requires a public advisory process as part of the development of the plan to identify a cost-effective portfolio of resources. The filed plan is subject to written public comments filed with the NMPRC to which the Company responded on October 29, 2018. NMPRC Staff filed a written report on November 16, 2018, recommending that the NMPRC return the 2018 IRP to the Company with instructions for re-filing to correct 12 deficiencies identified by the NMPRC Staff report. On December 5, 2018, the NMPRC issued an Order Partially Accepting Integrated Resource Plan; Order Requiring Refiling for Deficiencies. Pursuant to that order, on January 3, 2019, the Company filed an amended 2018 IRP. On January 10, 2019, in light of a pending motion for reconsideration, the NMPRC ordered its Staff to provide additional information and respond to issues raised regarding the filed 2018 IRP. On March 15, 2019, NMPRC Staff filed the additional response and recommended that the Company correct one deficiency identified. The Company is awaiting action by the NMPRC on the Staff recommendation. The Company cannot predict the outcome of the NMPRC's review of the plan or the outcome of this petitioncase at this time.
Issuance of Long-Term Debt, Securities Financing, and Guarantee of Debt. On October 7, 2015, the Company received approval in NMPRC Case No. 15-00280-UT to guarantee the issuance of up to $65.0 million of long-term debt by the Rio Grande Resources Trust II ("RGRT") to finance future purchases of nuclear fuel and to refinance existing nuclear fuel debt obligations, which remains effective. Under this authorization, on June 28, 2018, the RGRT issued $65.0 million in aggregate principal amount of 4.07% Senior Guaranteed Notes due August 15, 2025. On October 4, 2017, the Company received additional approval in NMPRC Case No. 17-00217-UT to amend and extend the Company's Revolving Credit Facility ("RCF"), issue up to $350.0 million in long-term debt and to redeem and refinance the $63.5 million 2009 Series A 7.25% Pollution Control Bonds ("PCBs") and the $37.1 million 2009 Series B 7.25% PCBs, which have optional redemptions beginning in 2019. The NMPRC approval to issue $350.0 million in long-term debt supersedes its prior approval. Under this authorization, on June 28, 2018, the Company issued $125.0 million in aggregate principal amount of the Company's 4.22% Senior Notes due August 15, 2028. Additionally, on September 13, 2018, the Company and the Bank of New York Mellon Trust Company, N.A., as trustee of the RGRT, entered into a $350.0 million third amended and restated credit agreement.
On January 30, 2019, the Company submitted an application with the NMPRC seeking approval to issue shares of common stock, including the reissuance of treasury shares, in an amount up to $200.0 million in one or more transactions. The application was assigned Case No. 19-00033-UT, and the NMPRC issued a final order approving the Company's request on March 27, 2019. Additionally, the Company is preparing for potential transactions related to the 2009 Series A 7.25% PCBs and 2009 Series B 7.25% PCBs. On February 1, 2019, and April 1, 2019, the Company purchased in lieu of redemption all the $63.5 million 2009 Series A 7.25% PCBs and the $37.1 million 2009 Series B 7.25% PCBs, respectively. The bonds were purchased utilizing funds borrowed under the RCF. The Company is currently holding the bonds and may remarket them or replace them with debt instruments of equivalent value at a future date depending on the Company's financing needs and market conditions. See Part I, Item 1, Financial Statements, Note M of Notes to Financial Statements for further discussion.
EL PASO ELECTRIC COMPANY
NOTES TO FINANCIAL STATEMENTS
(Unaudited)
Amendments to the New Mexico Renewable Energy Act (“REA”). The REA requires electric utilities to meet a renewable portfolio standard (“RPS”) of twenty percent of its total retail sales to New Mexico customers by 2020, reduced for sales to qualifying large non-governmental customers whose costs are capped under the REA (“Large Customer Adjustment”) and subject to a reasonable cost threshold (“RCT”) established by the NMPRC and currently set by the NMPRC at 3 percent of customers’ bills. Effective June 14, 2019, the New Mexico Energy Transition Act amends the REA (the “Amended REA”) to, among other amendments: (i) increase the RPS to forty percent by 2025, fifty percent by 2030, and eighty percent by 2040; (ii) impose a zero-carbon standard by 2045; (iii) eliminate the Large Customer Adjustment; (iv) set a statutory RCT; and (v) provide cost recovery for certain undepreciated investments and decommissioning costs (i.e., coal-fired generation) associated with generation required by the NMPRC to be discontinued and replaced with lower or zero-carbon generation. In administering the eighty percent RPS and zero-carbon standards, the Amended REA requires by Commission to consider certain factors, including safety, reliability and rate impact to customers. The NMPRC has not docketed a rulemaking proceeding to implement the Amended REA. Under current NMPRC rules, the Company is required to file its next annual REA procurement plan case on May 1, 2019. On April 24, 2019, in NMPRC Case No. 19-00099-UT, the NMPRC granted the Company a variance authorizing the Company to file its next annual REA procurement plan case on October 1, 2019. The Company cannot predict the outcome of the filing at this time.
Other Required Approvals. The Company has obtained other required approvals for tariffs and other approvals as required by the New Mexico Public Utility Act and the NMPRC.
Federal Regulatory Matters
Inquiry Regarding the Effect of the TCJA on Commission-Jurisdictional Rates and Order to Show Cause. On March 15, 2018, the FERC issued two show cause orders under Section 206 of the Federal Power Act and Rule 209(a) of the FERC’s Rules of Practice and Procedure, directing 48 individual public utilities with stated transmission rates or transmission formula rates with a fixed line item of 35% for the federal income tax component to, within 60 days of the date of the orders, either (1) propose revisions to their transmission rates under their open access transmission tariffs or transmission owner tariffs on file with the FERC, or (2) show cause why they should not be required to do so.so ("Show Cause Proceeding"). The Company iswas included in the list of public utilities impacted by the FERC ordersorders. On May 14, 2018, the Company submitted its response, as required by the FERC order, which demonstrated that the reduced annual income tax does not cause the Company's total transmission revenues to become excessive and therefore no rate reduction was justified. Instead, the Company stated in its response that it will prepare for a future filing in which it will seek approval for revised Open Access Transmission Tariff ("OATT") rates that would include the recovery of an increased total transmission revenue requirement from OATT customers based on current circumstances and appropriate forward-looking adjustments. On November 15, 2018, FERC issued an order finding that the Company had demonstrated that no rate reduction was justified and terminating the Show Cause Proceeding. The Company expects to file its request for approval to revise OATT rates in the third quarter of 2019.
Notice of Proposed Rulemaking on Public Utility Transmission Changes to Address Accumulated Deferred Income Taxes. On November 15, 2018, the FERC issued a Notice of Proposed Rulemaking ("NOPR") that proposes to direct public utilities with transmission OATT rates, a transmission owner tariff or a rate schedule to determine the amount of excess or deficient accumulated deferred income taxes caused by the TCJA’s reduction to the federal corporate income tax rate and return or recover this amount to or from customers. The NOPR has been assigned FERC Docket No. RM19-5-000. The Company is currently evaluating the impact of this proposed rulemaking.
Issuance of Long-Term Debt, Securities Financing, and Guarantee of Debt. On October 31, 2017, the FERC issued an order in Docket No. ES17-54-000 approving the Company’s filing to (i) amend and extend the RCF; (ii) issue up to $350.0 million in long-term debt; (iii) guarantee the issuance of up to $65.0 million of long-term debt by the RGRT; and (iv) redeem, refinance, and/or replace the $63.5 million 2009 Series A 7.25% PCBs and the $37.1 million 2009 Series B 7.25% PCBs, which have optional redemptions beginning in 2019. The order also approved the Company's request to continue to utilize the Company's existing RCF with the ability to amend and extend at a future date. The authorization is effective from November 15, 2017, through November 14, 2019, and supersedes prior FERC approvals. Under this authorization, on June 28, 2018, the Company issued $125.0 million in aggregate principal amount of the Company's 4.22% Senior Notes due August 15, 2028, and the RGRT issued $65.0 million in aggregate principal amount of its 4.07% Senior Guaranteed Notes due August 15, 2025. Also, on September 13, 2018, the Company and the Bank of New York Mellon Trust Company, N.A., as trustee of the RGRT, entered into a $350.0 million third amended and restated credit agreement. Additionally, the Company is preparing for potential transactions related to the 2009 Series A 7.25% PCBs and 2009 Series B 7.25% PCBs. On February 1, 2019, and April 1, 2019, the Company purchased in lieu of redemption all the $63.5 million 2009 Series A 7.25% PCBs and the $37.1 million 2009 Series B 7.25% PCBs, respectively. The bonds were purchased utilizing funds borrowed under the RCF. The Company is currently holding the bonds and may remarket them or replace
EL PASO ELECTRIC COMPANY
NOTES TO FINANCIAL STATEMENTS
(Unaudited)
them with debt instruments of equivalent value at a future date depending on the Company's financing needs and market conditions and in accordance with FERC action in response to the orders.Company’s most recent FERC application (see below).
On January 30, 2019, the Company submitted an application with the FERC seeking approval to issue shares of common stock, including the reissuance of treasury shares, in an amount up to $200.0 million in one or more transactions. Included in the FERC application, the Company also requested various debt-related authorizations: approval to utilize the existing RCF for short-term borrowing not to exceed $400.0 million at any one time; to issue up to $225.0 million in new long-term debt; and to remarket the $63.5 million 2009 Series A 7.25% PCBs and the $37.1 million 2009 Series B 7.25% PCBs in the form of replacement bonds or senior notes of equivalent value, not to exceed $100.6 million. On April 18, 2019, the FERC issued an order authorizing the issuances through April 18, 2021. See Part I, Item 1, Financial Statements, Note M of Notes to Financial Statements for further discussion.
Other Required Approvals. The Company has obtained required approvals for rates, tariffs and other approvals as required by the Federal Power Act and the FERC.
EL PASO ELECTRIC COMPANY
NOTES TO FINANCIAL STATEMENTS
(Unaudited)
E. Palo Verde
Spent Fuel and Waste Disposal. Pursuant to the Nuclear Waste Policy Act of 1982, as amended in 1987, the U.S. Department of Energy ("DOE") is legally obligated to accept and dispose of all spent nuclear fuel and other high-level radioactive waste generated by all domestic power reactors by 1998. The DOE's obligations are reflected in a contract for Disposal of Spent Nuclear Fuel and/or High Level Radioactive Waste with each nuclear power plant. The DOE failed to begin accepting spent nuclear fuel by 1998. Pursuant to the terms of the August 18, 2014 settlement agreement, and as amended with the DOE, Arizona Public Service Company ("APS") files annual claims for the period July 1 of the then-previous year to June 30 of the then-current year on behalf of itself and those utilities that share in power and energy entitlements, and bear certain allocated costs, with respect to Palo Verde pursuant to the Arizona Nuclear Power Project Participation Agreement dated August 23, 1973, as amended ("ANPP Participation Agreement"). The settlement agreement, as amended, provides APS with a method for submitting claims and receiving recovery for costs incurred through December 31, 2016, which has been extended to December 31, 2019.
On October 31, 2018, APS filed a $10.2 million claim for the period July 1, 2017 through June 30, 2018. The Company's share of costs recoveredthis claim is approximately $1.6 million. The DOE approved the claim on April 10, 2019. Any reimbursement is anticipated to be received in 2017the second quarter of 2019, and 2018the majority of the reimbursement received by the Company is presented below (in thousands):
|
| | | | | | | | | | | |
| | | | | Amount Credited
| | |
| | | | | to Customers | | |
| | | | | through Fuel | | Period Credited |
| Costs Recovery Period | | Amount Refunded | | Adjustment Clauses | | to Customers |
| | | | | | | |
| July 2015 - June 2016 | | $ | 1,779 |
| | $ | 1,432 |
| | March 2017 |
| July 2016 - June 2017 | | 1,413 |
| | 1,121 |
| | March 2018 |
expected to be credited to customers through the applicable fuel adjustment clauses.Palo Verde Operations and Maintenance Expense. Included in "operations"Operations and maintenance" in the Company's Statements of Operations are expenses associated with Palo Verde as follows (in thousands):
| | | | 2018 | | 2017 | | 2019 | | 2018 |
Three months ended March 31, | | $ | 22,175 |
| | $ | 21,608 |
| | $ | 21,344 |
| | $ | 22,175 |
|
Twelve months ended March 31, | | 99,931 |
| | 96,179 |
| | 95,623 |
| | 99,931 |
|
EL PASO ELECTRIC COMPANY
NOTES TO FINANCIAL STATEMENTS
(Unaudited)
F. Common Stock
Dividends. The Company paid $13.614.7 million and $12.613.6 million in quarterly cash dividends during the three months ended March 31, 20182019 and 2017,2018, respectively. The Company paid a total of $54.3$58.6 million and $50.3$54.3 million in quarterly cash dividends during the twelve months ended March 31, 20182019 and 2017,2018, respectively.
| | Basic and Diluted Earnings Per Share. The basic and diluted earnings per share are presented below (in thousands except for share data): | Basic and Diluted Earnings Per Share. The basic and diluted earnings per share are presented below (in thousands except for share data): | Basic and Diluted Earnings Per Share. The basic and diluted earnings per share are presented below (in thousands except for share data): |
| Three Months Ended March 31, | | Twelve Months Ended March 31, | Three Months Ended March 31, | | Twelve Months Ended March 31, |
| 2018 | | 2017 | | 2018 | | 2017 | 2019 | | 2018 | | 2019 | | 2018 |
Weighted average number of common shares outstanding: | | | | | | | | | | | | | | |
Basic number of common shares outstanding | 40,491,194 |
| | 40,387,235 |
| | 40,440,189 |
| | 40,366,024 |
| 40,582,936 |
| | 40,491,194 |
| | 40,543,986 |
| | 40,440,189 |
|
Dilutive effect of unvested performance awards | — |
| | — |
| | 123,436 |
| | 69,665 |
| 80,817 |
| | — |
| | 117,242 |
| | 123,436 |
|
Diluted number of common shares outstanding | 40,491,194 |
| | 40,387,235 |
| | 40,563,625 |
| | 40,435,689 |
| 40,663,753 |
| | 40,491,194 |
| | 40,661,228 |
| | 40,563,625 |
|
Basic net income (loss) per common share: | | | | | | | | | | | | | | |
Net income (loss) | $ | (6,966 | ) | | $ | (3,989 | ) | | $ | 95,285 |
| | $ | 98,587 |
| $ | 6,089 |
| | $ | (6,966 | ) | | $ | 97,370 |
| | $ | 95,285 |
|
Income allocated to participating restricted stock | (48 | ) | | (45 | ) | | (353 | ) | | (349 | ) | (47 | ) | | (48 | ) | | (340 | ) | | (353 | ) |
Net income (loss) available to common shareholders | $ | (7,014 | ) | | $ | (4,034 | ) | | $ | 94,932 |
| | $ | 98,238 |
| $ | 6,042 |
| | $ | (7,014 | ) | | $ | 97,030 |
| | $ | 94,932 |
|
Diluted net income (loss) per common share: | | | | | | | | | | | | | | |
Net income (loss) | $ | (6,966 | ) | | $ | (3,989 | ) | | $ | 95,285 |
| | $ | 98,587 |
| $ | 6,089 |
| | $ | (6,966 | ) | | $ | 97,370 |
| | $ | 95,285 |
|
Income reallocated to participating restricted stock | (48 | ) | | (45 | ) | | (353 | ) | | (349 | ) | (47 | ) | | (48 | ) | | (339 | ) | | (353 | ) |
Net income (loss) available to common shareholders | $ | (7,014 | ) | | $ | (4,034 | ) | | $ | 94,932 |
| | $ | 98,238 |
| $ | 6,042 |
| | $ | (7,014 | ) | | $ | 97,031 |
| | $ | 94,932 |
|
Basic net income (loss) per common share: | | | | | | | | | | | | | | |
Distributed earnings | $ | 0.335 |
| | $ | 0.31 |
| | $ | 1.34 |
| | $ | 1.24 |
| $ | 0.36 |
| | $ | 0.335 |
| | $ | 1.44 |
| | $ | 1.34 |
|
Undistributed earnings (losses) | (0.505 | ) | | (0.41 | ) | | 1.01 |
| | 1.19 |
| (0.21 | ) | | (0.505 | ) | | 0.95 |
| | 1.01 |
|
Basic net income (loss) per common share | $ | (0.170 | ) | | $ | (0.10 | ) | | $ | 2.35 |
| | $ | 2.43 |
| $ | 0.15 |
| | $ | (0.170 | ) | | $ | 2.39 |
| | $ | 2.35 |
|
Diluted net income (loss) per common share: | | | | | | | | | | | | | | |
Distributed earnings | $ | 0.335 |
| | $ | 0.31 |
| | $ | 1.34 |
| | $ | 1.24 |
| $ | 0.36 |
| | $ | 0.335 |
| | $ | 1.44 |
| | $ | 1.34 |
|
Undistributed earnings (losses) | (0.505 | ) | | (0.41 | ) | | 1.00 |
| | 1.19 |
| (0.21 | ) | | (0.505 | ) | | 0.95 |
| | 1.00 |
|
Diluted net income (loss) per common share | $ | (0.170 | ) | | $ | (0.10 | ) | | $ | 2.34 |
| | $ | 2.43 |
| $ | 0.15 |
| | $ | (0.170 | ) | | $ | 2.39 |
| | $ | 2.34 |
|
| | The number of restricted stock awards and performance shares at 100% performance level excluded from the calculation of the diluted number of common shares outstanding because their effect was antidilutive is presented below: | | Three Months Ended | | Twelve Months Ended | Three Months Ended | | Twelve Months Ended |
| March 31, | | March 31, | March 31, | | March 31, |
| 2018 | | 2017 | | 2018 | | 2017 | 2019 | | 2018 | | 2019 | | 2018 |
Restricted stock awards | 72,218 |
| | 78,025 |
| | 66,288 |
| | 58,344 |
| 62,605 |
| | 72,218 |
| | 60,432 |
| | 66,288 |
|
Performance shares (a) | 45,977 |
| | — |
| | 11,494 |
| | 47,246 |
| 43,652 |
| | 45,977 |
| | 22,234 |
| | 11,494 |
|
________________________
| |
(a) | Certain performance shares were excluded from the computation of diluted earnings per share as no payouts would have been required based upon performance at the end of each corresponding period. |
EL PASO ELECTRIC COMPANY
NOTES TO FINANCIAL STATEMENTS
(Unaudited)
Authorization to Issue Shares
On January 30, 2019, the Company submitted an application with both the NMPRC and the FERC seeking approval to issue shares of common stock, including the reissuance of treasury shares, in an amount up to $200.0 million in one or more transactions. The Company received final approvals from the NMPRC and the FERC on March 27, 2019 and April 18, 2019, respectively.
G. Income Taxes
The Company files income tax returns in the U.S. federal jurisdiction and in the states of Texas, New Mexico and Arizona. The Company is no longer subject to tax examination by the taxing authorities in the federal, Texas, Arizona, and New Mexico jurisdictions for years prior to 2013.2014.
For the three months ended March 31, 20182019 and 2017,2018, the Company’s effective tax rate was 30.5%23.8% and 36.5%30.5%, respectively. For the twelve months ended March 31, 20182019 and 2017,2018, the Company's effective tax rate was 34.5%24.3% and 35.7%34.5%, respectively. The federal statutory tax rate is 21% in 2019 and in 2018, and 35%35.0% in 2017. The Company's effective tax rate for the three months ended March 31, 2018,2019 differs from the federal statutory tax rate primarily due to the tax benefit of stock incentive plans and other permanent differences that increase theCompany's effective tax rate when the Company incurs a net loss. The Company's effective tax rates for the three months ended March 31, 2017,2018 due to lower values of stock incentives vested and other permanent differences. The Company's effective tax rate for the twelve months ended March 31, 2019 differs from the Company's effective tax rate for the twelve months ended March 31, 2018 and 2017, differs from the federal statutory tax rate primarily due to state income taxes offset by capital gainsthe change in the decommissioning trusts, which are taxed at the federal income tax rate of 20%,partially offset by an increase in state tax reserves and the tax benefit of stock incentive plans.
The results for the three and twelve months ended March 31, 2018, contain provisional estimates of the impact of the TCJA. These amounts are considered provisional because they use estimates for which tax returns have not yet been filed and because estimated amounts may be impacted by future regulatory and accounting guidance if and when issued. The Company will adjust these provisional amounts as further information becomes available and as we refine our calculations. As permitted by recent guidance issued by the SEC, these adjustments will occur during a reasonable “measurement period” not to exceed twelve months from the date of enactment.
In February 2018, the FASB issued ASU 2018-02. The Company is currently evaluating the impact of ASU 2018-02 and its impact on regulated utilities. See Note A, Principles of Preparation - New Accounting Standards to be Adopted in the Future, for additional information.other permanent differences.
H. Commitments, Contingencies and Uncertainties
For a full discussion of commitments and contingencies, see Part II, Item 8, Financial Statements and Supplementary Data, Note KL of the Notes to Financial Statements in the 20172018 Form 10-K. In addition, see Part I, Item 1, Financial Statements, Notes D and E of Notes to Financial Statements above and Part II, Item 8, Financial Statements and Supplementary Data, Notes CD and EF of the Notes to Financial Statements in the 20172018 Form 10-K regarding matters related to wholesale power sales contracts and transmission contracts subject to regulation and Palo Verde, including decommissioning, spent nuclear fuel and waste disposal, and liability and insurance matters.
Power Purchase and Sale Contracts
To supplement its own generation and operating reserve requirements and to meet required renewable portfolio standards,its RPS requirements, the Company engages in power purchase arrangements that may vary in duration and amount based on an evaluation of the Company's resource needs, the economics of the transactions and specific renewable portfolioRPS requirements. For a discussion of power purchase and sale contracts that the Company has entered into with various counterparties, see Part II, Item 8, Financial Statements and Supplementary Data, Note KL of the Notes to Financial Statements in the 20172018 Form 10-K.
Environmental Matters
General. The Company is subject to extensive laws, regulations and permit requirements with respect to air and greenhouse gas emissions, water discharges, soil and water quality, waste management and disposal, natural resources and other environmental matters by federal, state, regional, tribal and local authorities. Failure to comply with such laws, regulations and requirements can result in actions by authorities or other third parties that might seek to impose on the Company administrative, civil and/or criminal penalties or other sanctions. In addition, releases of pollutants or contaminants into the environment can result in costly cleanup liabilities. These laws, regulations and requirements are subject to change through modification or reinterpretation, or the introduction of new laws and regulations and, as a result, the Company may face additional capital and operating costs to comply.
Environmental Litigation
EL PASO ELECTRIC COMPANY
NOTES TO FINANCIAL STATEMENTS
(Unaudited)
I. Leases
The Company’s lease population is composed of operating leases. The Company leases land in El Paso, Texas, adjacent to Newman under a lease that expires in June 2033 with a renewal option of 25 years. The Company also has several other leases for offices, parking facilities and Investigations. Since July 2011,equipment that expire within the U.S. Departmentnext 5 years. The Company has transmission and distribution lines that are operated under various land rights agreements, including easements, leases, permits and franchises. The components of Justice, on behalf of the U.S. Environmental Protection Agency, and APS have been engaged in substantive settlement negotiations in an effort to resolve certain of the pending matterslease expense are as follows:
|
| | | |
| Three Months Ended March 31, 2019 |
Lease cost (in thousands): | |
Operating lease cost | $ | 253 |
|
Short-term lease cost | 274 |
|
Variable lease cost | 34 |
|
Total lease cost | $ | 561 |
|
Supplemental balance sheet information related to Four Corners. The allegations being addressed through settlement negotiations are that APS failedleases was as follows (in thousands, except lease term and discount rate):
|
| | | |
| March 31, 2019 |
Operating leases: | |
Operating lease ROU assets (included in electric plant in service) | $ | 6,217 |
|
| |
Operating lease liabilities (current included in other current liabilities) | 552 |
|
Operating lease liabilities (net of current included in deferred credits and other liabilities) | 5,336 |
|
Total lease liabilities | $ | 5,888 |
|
| |
Weighted average remaining lease terms (in years) | 12.22 |
|
Weighted average discount rate | 4.63 | % |
Supplemental cash flow information related to obtain the necessary permits and install the controls necessary under the U.S. Clean Air Act ("CAA") to reduce sulfur dioxide, nitrogen oxides, and particulate matter, and that defendants failed to obtain an operating permit under Title V of the CAA that reflects applicable requirements imposed by law. On June 24, 2015, the parties filed with the U.S. District Courtleases was as follows (in thousands):
|
| | | |
| Three Months Ended March 31, 2019 |
Cash paid for amounts included in the measurement of lease liabilities: | |
Operating cash flows used for operating leases | $ | 557 |
|
ROU assets obtained in exchange for New Mexicolease obligations (in thousands):
|
| | | |
| Three Months Ended March 31, 2019 |
Operating leases | $ | 6,217 |
|
EL PASO ELECTRIC COMPANY
NOTES TO FINANCIAL STATEMENTS
(Unaudited)
a settlement agreement resolving this matter. On August 17, 2015,Maturities of operating lease liabilities at March 31, 2019 were as follows (in thousands):
|
| | | |
Year ending December 31, | |
2019 | $ | 306 |
|
2020 | 770 |
|
2021 | 696 |
|
2022 | 639 |
|
2023 | 590 |
|
Thereafter | 4,829 |
|
Total lease payments | 7,830 |
|
Less imputed interest | (1,942 | ) |
Total | $ | 5,888 |
|
Disclosures related to periods prior to adoption of the U.S. District Court for New Mexico entered the settlement agreement. new lease standard
The agreement imposes aCompany’s total civil penalty payable by the co-owners of Four Corners collectively in the amount of $1.5rental expense related to operating leases was $1.7 million and it requires the co-owners to pay $6.7$2.4 million for environmental mitigation projects. At Marchthe twelve months ended December 31, 2018 and 2017, respectively. As of December 31, 2018, the Company has accrued its remaining unpaid share of approximately $0.2 million related to this matter.Company’s minimum future rental payments for the next five years were as follows (in thousands):
|
| | | |
Year ending December 31, | |
2019 | $ | 923 |
|
2020 | 820 |
|
2021 | 700 |
|
2022 | 544 |
|
2023 | 526 |
|
I.J. Litigation
The Company is involved in various legal, environmental, tax and regulatory proceedings before various courts, regulatory commissions and governmental agencies regarding matters arising in the ordinary course of business. In many of these matters, the Company has excess casualty liability insurance that covers the various claims, actions and complaints. The Company regularly analyzes current information and, as necessary, makes provisions in its financial statements for probable liabilities for the eventual disposition of these matters. While the outcome of these matters cannot be predicted with certainty, based upon a review of the matters and applicable insurance coverage, the Company believes that none of these matters will have a material adverse effect on the financial position, results of operations or cash flows of the Company. The Company expenses legal costs, including expenses related to loss contingencies, as they are incurred.
See Part I, Item 1, Financial Statements, Notes D and H of Notes to Financial Statements above and Part II, Item 8, Financial Statements and Supplementary Data, Notes CD and KL of the Notes to Financial Statements in the 20172018 Form 10-K for discussion of the effects of government legislation and regulation on the Company.
J.EL PASO ELECTRIC COMPANY
NOTES TO FINANCIAL STATEMENTS
(Unaudited)
K. Employee Benefits
The Company adopted ASU 2017-07, Compensation-Retirement Benefits, effective January 1, 2018. Upon adoption of the new standard, the service cost is included in "Operations and maintenance" in the Company's Statements of Operations. The expected return on plan assets is included in "Investment and interest income, net". in the Company's Statements of Operations. The amortization of prior service benefit and amortization of gains are included in "Miscellaneous non-operating income". The amortization of prior service cost and amortization of losses are included in "Miscellaneous non-operating deductions". The interest cost component of net periodic benefit cost is included in "Other interest".
The provisions in ASU 2017-07 were applied retrospectively for the income statement presentation of the service cost component and the other components of net benefit costs. The Company elected to apply the practical expedient and used the amounts disclosed in its pension and other postretirement benefit plan note for the 2017 comparative period as the estimation basis for applying the retrospective presentation requirements. The Company reclassified $2.1 million to "Operations and maintenance" in the Company’s Statement of Operations for the three months ended March 31, 2017 by increasing (i) "Investment and interest income, net" by $5.3 million, (ii) "Miscellaneous non-operating income" by $2.8 million, (iii) "Miscellaneous non-operating deductions" by $2.1 million, and (iv) "Other interest" by $3.9 million. As a result of the reclassifications, "Operations and maintenance" increased to $2.9 million in service cost from the $0.8 million in net periodic benefit cost previously reported.
The Company reclassified $7.5 million to "Operations and maintenance" in the Company’s Statement of Operations for the twelve months ended March 31, 2017 by increasing (i) "Investment and interest income, net" by $20.8 million, (ii) "Miscellaneous non-operating income" by $10.3 million, (iii) "Miscellaneous non-operating deductions" by $7.5 million, and (iv) "Other interest" by $16.0 million. As a result of the reclassifications, "Operations and maintenance" increased to $11.0 million in service cost from the $3.5 million in net periodic benefit cost previously reported.
Retirement Plans
The net periodic benefit cost recognized for the three and twelve months ended March 31, 20182019 and 2017,2018, is made up of the components listed below as determined using the projected unit credit actuarial cost method (in thousands):
EL PASO ELECTRIC COMPANY
NOTES TO FINANCIAL STATEMENTS
(Unaudited)
| | | Three Months Ended | | Twelve Months Ended | Three Months Ended | | Twelve Months Ended |
| March 31, | | March 31, | March 31, | | March 31, |
| 2018 | | 2017 | | 2018 | | 2017 | 2019 | | 2018 | | 2019 | | 2018 |
Components of net periodic benefit cost: | | | | | | | | | | | | | | |
Service cost | $ | 2,758 |
| | $ | 2,270 |
| | $ | 9,006 |
| | $ | 8,366 |
| $ | 2,488 |
| | $ | 2,758 |
| | $ | 10,818 |
| | $ | 9,006 |
|
Interest cost | 3,223 |
| | 3,248 |
| | 13,034 |
| | 13,022 |
| 3,608 |
| | 3,223 |
| | 13,263 |
| | 13,034 |
|
Expected return on plan assets | (5,315 | ) | | (4,808 | ) | | (19,696 | ) | | (18,975 | ) | (5,383 | ) | | (5,315 | ) | | (21,144 | ) | | (19,696 | ) |
Amortization of: | | | | | | | | | | | | | | |
Net loss | 2,100 |
| | 2,089 |
| | 8,465 |
| | 7,540 |
| 1,418 |
| | 2,100 |
| | 7,871 |
| | 8,465 |
|
Prior service benefit | (878 | ) | | (878 | ) | | (3,506 | ) | | (3,506 | ) | (878 | ) | | (878 | ) | | (3,506 | ) | | (3,506 | ) |
Net periodic benefit cost | $ | 1,888 |
| | $ | 1,921 |
| | $ | 7,303 |
| | $ | 6,447 |
| $ | 1,253 |
| | $ | 1,888 |
| | $ | 7,302 |
| | $ | 7,303 |
|
During the three months ended March 31, 20182019, the Company contributed $2.93.0 million of its projected $9.49.5 million 20182019 annual contribution to its retirement plans.
Other Postretirement Benefits
The net periodic benefit recognized for the three and twelve months ended March 31, 20182019 and 2017,2018, is made up of the components listed below (in thousands):
| | | Three Months Ended | | Twelve Months Ended | Three Months Ended | | Twelve Months Ended |
| March 31, | | March 31, | March 31, | | March 31, |
| 2018 | | 2017 | | 2018 | | 2017 | 2019 | | 2018 | | 2019 | | 2018 |
Components of net periodic benefit: | | | | | | | | | | | | | | |
Service cost | $ | 700 |
| | $ | 588 |
| | $ | 2,348 |
| | $ | 2,642 |
| $ | 625 |
| | $ | 700 |
| | $ | 2,720 |
| | $ | 2,348 |
|
Interest cost | 565 |
| | 678 |
| | 2,610 |
| | 2,972 |
| 618 |
| | 565 |
| | 2,305 |
| | 2,610 |
|
Expected return on plan assets | (613 | ) | | (470 | ) | | (2,050 | ) | | (1,845 | ) | (530 | ) | | (613 | ) | | (2,352 | ) | | (2,050 | ) |
Amortization of: | | | | | | | | | | | | | | |
Prior service benefit | (1,538 | ) | | (1,538 | ) | | (6,151 | ) | | (4,651 | ) | (1,308 | ) | | (1,538 | ) | | (5,921 | ) | | (6,151 | ) |
Net gain | (525 | ) | | (395 | ) | | (1,808 | ) | | (2,104 | ) | (575 | ) | | (525 | ) | | (2,216 | ) | | (1,808 | ) |
Net periodic benefit | $ | (1,411 | ) | | $ | (1,137 | ) | | $ | (5,051 | ) | | $ | (2,986 | ) | $ | (1,170 | ) | | $ | (1,411 | ) | | $ | (5,464 | ) | | $ | (5,051 | ) |
During the three months ended March 31, 2018,2019, the Company contributed $0.1$0.2 million of its projected $0.5 million 20182019 annual contribution to its other postretirement benefits plan.
K.EL PASO ELECTRIC COMPANY
NOTES TO FINANCIAL STATEMENTS
(Unaudited)
L. Financial Instruments and Investments
The FASB guidance requires the Company to disclose estimated fair values for its financial instruments. The Company has determined that cash and temporary investments (including restricted cash), investment in debt securities, accounts receivable, decommissioning trust funds, long-term debt, short-term borrowings under the Company's Revolving Credit Facility ("RCF"),RCF, accounts payable and customer deposits meet the definition of financial instruments. The carrying amounts of cash and temporary investments, accounts receivable, accounts payable and customer deposits approximate fair value because of the short maturity of these items. Investments in debt securities and decommissioning trust funds are carried at estimated fair value.
Long-Term Debt and Short-Term Borrowings Under the RCF. The fair values of the Company's long-term debt and short-term borrowings under the RCF are based on estimated market prices for similar issues and are presented below (in thousands):
EL PASO ELECTRIC COMPANY
NOTES TO FINANCIAL STATEMENTS
(Unaudited)
| | | March 31, 2018 | | December 31, 2017 | March 31, 2019 | | December 31, 2018 |
| Carrying Amount | | Estimated Fair Value | | Carrying Amount | | Estimated Fair Value | Carrying Amount | | Estimated Fair Value | | Carrying Amount | | Estimated Fair Value |
Pollution Control Bonds(1) | $ | 157,699 |
| | $ | 166,779 |
| | $ | 157,676 |
| | $ | 169,186 |
| $ | 95,088 |
| | $ | 98,217 |
| | $ | 157,769 |
| | $ | 161,917 |
|
Senior Notes | 993,514 |
| | 1,147,504 |
| | 993,426 |
| | 1,211,922 |
| 1,118,036 |
| | 1,283,200 |
| | 1,117,943 |
| | 1,244,310 |
|
RGRT Senior Notes (1)(2) | 44,897 |
| | 46,620 |
| | 44,886 |
| | 47,070 |
| 109,537 |
| | 112,850 |
| | 109,507 |
| | 111,440 |
|
RCF (1)(2) | 233,067 |
| | 233,067 |
| | 173,533 |
| | 173,533 |
| 202,951 |
| | 202,951 |
| | 49,207 |
| | 49,207 |
|
Total | $ | 1,429,177 |
| | $ | 1,593,970 |
| | $ | 1,369,521 |
| | $ | 1,601,711 |
| $ | 1,525,612 |
| | $ | 1,697,218 |
| | $ | 1,434,426 |
| | $ | 1,566,874 |
|
_______________ | |
(1) | On February 1, 2019, the Company purchased in lieu of redemption all of the 2009 Series A 7.25% PCBs with a principal amount of $63.5 million, utilizing funds borrowed under the RCF. The Company is currently holding the 2009 Series A 7.25% PCBs and may remarket them or replace them with debt instruments of equivalent value at a future date depending on the Company's financing needs and market conditions, and in accordance with the Company's regulators' approvals. See Part I, Item 1, Financial Statements, Note M of Notes to Financial Statements for further discussion. |
| |
(2) | Nuclear fuel financing, as of March 31, 20182019 and December 31, 2017,2018, is funded through $45$110 million Rio Grande Resources Trust ("RGRT")RGRT Senior Notes and $89.1$30.0 million and $88.5$26.2 million, respectively, under the RCF. As of March 31, 20182019, $173.0 million was outstanding under the RCF for working capital and general corporate purposes. As of December 31, 2017, $144.02018, $23.0 million, and $85.0 million, respectively, was outstanding under the RCF for working capital or general corporate purposes. The interest rate on the Company's borrowings under the RCF is reset throughout the quarter reflecting current market rates. Consequently, the carrying value approximates fair value. |
Marketable Securities. The Company's marketable securities, included in decommissioning trust funds in the balance sheets, are reported at fair value which was $284.1$298.3 million and $286.9$276.9 million at March 31, 20182019 and December 31, 2017,2018, respectively. The investments in the Company's Palo Verde nuclear decommissioning trust funds ("NDT") are classified as available for sale debt securities, equity securities and temporary cash and cash equivalents.equivalents restricted solely for investment in the NDT. These investments are recorded at their estimated fair value in accordance with FASB guidance for certain investments in debt and equity securities. On January 1, 2018, the Company adopted ASU 2016-01, Financial Instruments-Overall,Instruments - Overall, which eliminates the requirements to classify investments in equity securities with readily determinable fair values as trading or available for sale and requires entities to recognize changes in fair value for these securities in net income as reported in the Statements of Operations. ASU 2016-01 requires a modified-retrospective approach and therefore, comparative information has not been restated and continues to be reported under the accounting standards in effect for those periods.
EL PASO ELECTRIC COMPANY
NOTES TO FINANCIAL STATEMENTS
(Unaudited)
The reported fair values include gross unrealized losses on securities classified as available for sale whose impairment the Company has deemed to be temporary. The tables below present the gross unrealized losses and the fair value of these securities, aggregated by investment category and length of time that individual securities have been in a continuous unrealized loss position (in thousands):
| | | March 31, 2018 | March 31, 2019 |
| Less than 12 Months | | 12 Months or Longer | | Total | Less than 12 Months | | 12 Months or Longer | | Total |
| Fair Value | | Unrealized Losses | | Fair Value | | Unrealized Losses | | Fair Value | | Unrealized Losses | Fair Value | | Unrealized Losses | | Fair Value | | Unrealized Losses | | Fair Value | | Unrealized Losses |
Description of Securities (1): | | | | | | | | | | | | | | | | | | | | | | |
Federal Agency Mortgage Backed Securities | $ | 5,995 |
| | $ | (114 | ) | | $ | 10,376 |
| | $ | (407 | ) | | $ | 16,371 |
| | $ | (521 | ) | $ | 694 |
| | $ | (20 | ) | | $ | 13,210 |
| | $ | (271 | ) | | $ | 13,904 |
| | $ | (291 | ) |
U.S. Government Bonds | 34,018 |
| | (940 | ) | | 18,325 |
| | (1,215 | ) | | 52,343 |
| | (2,155 | ) | 4,722 |
| | (6 | ) | | 26,267 |
| | (1,194 | ) | | 30,989 |
| | (1,200 | ) |
Municipal Debt Obligations | 4,227 |
| | (109 | ) | | 7,031 |
| | (581 | ) | | 11,258 |
| | (690 | ) | 4,480 |
| | (332 | ) | | 1,614 |
| | (127 | ) | | 6,094 |
| | (459 | ) |
Corporate Debt Obligations | 20,855 |
| | (609 | ) | | 3,769 |
| | (301 | ) | | 24,624 |
| | (910 | ) | 6,851 |
| | (114 | ) | | 11,170 |
| | (299 | ) | | 18,021 |
| | (413 | ) |
Total | $ | 65,095 |
| | $ | (1,772 | ) | | $ | 39,501 |
| | $ | (2,504 | ) | | $ | 104,596 |
| | $ | (4,276 | ) | $ | 16,747 |
| | $ | (472 | ) | | $ | 52,261 |
| | $ | (1,891 | ) | | $ | 69,008 |
| | $ | (2,363 | ) |
_________________
| |
(1) | Includes 14796 securities. |
EL PASO ELECTRIC COMPANY
NOTES TO FINANCIAL STATEMENTS
(Unaudited)
| | | December 31, 2017 | December 31, 2018 |
| Less than 12 Months | | 12 Months or Longer | | Total | Less than 12 Months | | 12 Months or Longer | | Total |
| Fair Value | | Unrealized Losses | | Fair Value | | Unrealized Losses | | Fair Value | | Unrealized Losses | Fair Value | | Unrealized Losses | | Fair Value | | Unrealized Losses | | Fair Value | | Unrealized Losses |
Description of Securities (2): | | | | | | | | | | | | | | | | | | | | | | |
Federal Agency Mortgage Backed Securities | $ | 4,700 |
| | $ | (46 | ) | | $ | 10,099 |
| | $ | (165 | ) | | $ | 14,799 |
| | $ | (211 | ) | $ | 6,187 |
| | $ | (36 | ) | | $ | 14,567 |
| | $ | (510 | ) | | $ | 20,754 |
| | $ | (546 | ) |
U.S. Government Bonds | 28,866 |
| | (416 | ) | | 18,186 |
| | (969 | ) | | 47,052 |
| | (1,385 | ) | 4,005 |
| | (9 | ) | | 36,615 |
| | (1,663 | ) | | 40,620 |
| | (1,672 | ) |
Municipal Debt Obligations | 4,290 |
| | (73 | ) | | 9,736 |
| | (742 | ) | | 14,026 |
| | (815 | ) | 3,100 |
| | (74 | ) | | 9,037 |
| | (723 | ) | | 12,137 |
| | (797 | ) |
Corporate Debt Obligations | 10,685 |
| | (107 | ) | | 4,475 |
| | (331 | ) | | 15,160 |
| | (438 | ) | 22,259 |
| | (763 | ) | | 11,231 |
| | (731 | ) | | 33,490 |
| | (1,494 | ) |
Total Debt Securities | 48,541 |
| | (642 | ) | | 42,496 |
| | (2,207 | ) | | 91,037 |
| | (2,849 | ) | |
Domestic Equity Securities | 962 |
| | (210 | ) | | — |
| | — |
| | 962 |
| | (210 | ) | |
Total | $ | 49,503 |
| | $ | (852 | ) | | $ | 42,496 |
| | $ | (2,207 | ) | | $ | 91,999 |
| | $ | (3,059 | ) | $ | 35,551 |
| | $ | (882 | ) | | $ | 71,450 |
| | $ | (3,627 | ) | | $ | 107,001 |
| | $ | (4,509 | ) |
_________________
| |
(2) | Includes 146156 securities. |
The Company monitors the length of time specific securities trade below their cost basis along with the amount and percentage of the unrealized loss in determining if a decline in fair value below recorded cost of debt securities classified as available for sale is considered to be other than temporary. The Company recognizes impairment losses on certain of its available for sale debt securities deemed to be other than temporary. In accordance with the FASB guidance, these impairment losses are recognized in net income, and a lower cost basis is established for these securities. In addition, the Company will research the future prospects of individual securities as necessary. The Company does not anticipate expending monies held in trust before 2044 or a later period when decommissioning of Palo Verde begins.
For the three and twelve months ended March 31, 20182019 and 2017,2018, the Company recognizeddid not recognize any other than temporary impairment losses on its available-for-sale securities as follows (in thousands):securities.
EL PASO ELECTRIC COMPANY
NOTES TO FINANCIAL STATEMENTS
(Unaudited)
|
| | | | | | | | | | | | | | | |
| Three Months Ended | | Twelve Months Ended |
| March 31, | | March 31, |
| 2018 | | 2017 | | 2018 | | 2017 |
Unrealized holding losses included in pre-tax income | $ | — |
| | $ | — |
| | $ | — |
| | $ | (196 | ) |
Investments categorized as available for sale securities also include gross unrealized gains which have not been recognized in the Company's net income. The table below presents the unrecognized gross unrealized gains and the fair value of these securities, aggregated by investment category (in thousands):
|
| | | | | | | | | | | | | | | |
| March 31, 2018 | | December 31, 2017 |
| Fair Value | | Unrealized Gains | | Fair Value | | Unrealized Gains |
Description of Securities: | | | | | | | |
Federal Agency Mortgage Backed Securities | $ | 9,469 |
| | $ | 143 |
| | $ | 5,933 |
| | $ | 203 |
|
U.S. Government Bonds | 2,205 |
| | 92 |
| | 11,129 |
| | 256 |
|
Municipal Debt Obligations | 1,073 |
| | 92 |
| | 2,558 |
| | 109 |
|
Corporate Debt Obligations | 11,444 |
| | 546 |
| | 19,514 |
| | 1,067 |
|
Total Debt Securities | 24,191 |
| | 873 |
| | 39,134 |
| | 1,635 |
|
Domestic Equity Securities | — |
| | — |
| | 120,065 |
| | 45,587 |
|
International Equity Securities | — |
| | — |
| | 28,804 |
| | 5,908 |
|
Cash and Cash Equivalents | — |
| | — |
| | 6,864 |
| | — |
|
Total | $ | 24,191 |
| | $ | 873 |
| | $ | 194,867 |
| | $ | 53,130 |
|
EL PASO ELECTRIC COMPANY
NOTES TO FINANCIAL STATEMENTS
(Unaudited)
|
| | | | | | | | | | | | | | | |
| March 31, 2019 | | December 31, 2018 |
| Fair Value | | Unrealized Gains | | Fair Value | | Unrealized Gains |
Description of Securities: | | | | | | | |
Federal Agency Mortgage Backed Securities | $ | 16,459 |
| | $ | 327 |
| | $ | 9,959 |
| | $ | 176 |
|
U.S. Government Bonds | 18,413 |
| | 419 |
| | 6,987 |
| | 149 |
|
Municipal Debt Obligations | 3,454 |
| | 189 |
| | 1,952 |
| | 120 |
|
Corporate Debt Obligations | 29,648 |
| | 888 |
| | 8,283 |
| | 222 |
|
Total Debt Securities | $ | 67,974 |
| | $ | 1,823 |
| | $ | 27,181 |
| | $ | 667 |
|
The Company's marketable securities include investments in mortgage backed securities, municipal, corporate and federal debt obligations. The contractual year forof maturity offor these available-for-sale debt securities as of March 31, 2018,2019, is as follows (in thousands):
| | | Total | | 2018 | | 2019 through 2022 | | 2023 through 2027 | | 2028 and Beyond | Total | | 2019 | | 2020 through 2023 | | 2024 through 2028 | | 2029 and Beyond |
Federal Agency Mortgage Backed Securities | $ | 25,840 |
| | $ | — |
| | $ | 16 |
| | $ | 261 |
| | $ | 25,563 |
| $ | 30,363 |
| | $ | — |
| | $ | 19 |
| | $ | 514 |
| | $ | 29,830 |
|
U.S. Government Bonds | 54,548 |
| | 1,894 |
| | 28,263 |
| | 11,415 |
| | 12,976 |
| 49,402 |
| | 2,356 |
| | 20,491 |
| | 21,282 |
| | 5,273 |
|
Municipal Debt Obligations | 12,331 |
| | 76 |
| | 5,483 |
| | 5,735 |
| | 1,037 |
| 9,548 |
| | 649 |
| | 3,446 |
| | 3,566 |
| | 1,887 |
|
Corporate Debt Obligations | 36,068 |
| | 213 |
| | 17,518 |
| | 7,151 |
| | 11,186 |
| 47,669 |
| | 940 |
| | 21,968 |
| | 11,488 |
| | 13,273 |
|
Total Available for Sale Debt Securities | | $ | 136,982 |
| | $ | 3,945 |
| | $ | 45,924 |
| | $ | 36,850 |
| | $ | 50,263 |
|
The Company's available for sale securities in the NDT are sold from time to time and the Company uses the specific identification basis to determine the amount to reclassify from AOCI into net income. The proceeds from the sale of these securities during the three and twelve months ended March 31, 20182019 and 2017,2018, and the related effects on pre-tax income are as follows (in thousands):
| | | Three Months Ended | | Twelve Months Ended | Three Months Ended | | Twelve Months Ended |
| March 31, | | March 31, | March 31, | | March 31, |
| 2018 | | 2017 | | 2018 | | 2017 | 2019 | | 2018 | | 2019 | | 2018 |
Proceeds from sales or maturities of available-for-sale securities | $ | 11,757 |
| | $ | 26,055 |
| | $ | 82,739 |
| | $ | 93,245 |
| $ | 15,771 |
| | $ | 11,757 |
| | $ | 29,969 |
| | $ | 82,739 |
|
Gross realized gains included in pre-tax income | $ | 9 |
| | $ | 2,587 |
| | $ | 9,195 |
| | $ | 9,968 |
| $ | 58 |
| | $ | 9 |
| | $ | 66 |
| | $ | 9,195 |
|
Gross realized losses included in pre-tax income | (527 | ) | | (396 | ) | | (1,278 | ) | | (1,329 | ) | (887 | ) | | (527 | ) | | (1,822 | ) | | (1,278 | ) |
Gross unrealized losses included in pre-tax income | — |
| | — |
| | — |
| | (196 | ) | |
Net gains included in pre-tax income | $ | (518 | ) | | $ | 2,191 |
| | $ | 7,917 |
| | $ | 8,443 |
| |
Net gains (losses) included in pre-tax income | | $ | (829 | ) | | $ | (518 | ) | | $ | (1,756 | ) | | $ | 7,917 |
|
EL PASO ELECTRIC COMPANY
NOTES TO FINANCIAL STATEMENTS
(Unaudited)
Upon the adoption of ASU 2016-01, Financial Instruments-Overall,Instruments - Overall, on January 1, 2018, the Company records, on a modified-retrospective basis, changes in fair market value for equity securities held in the NDT in the Statements of Operations. The unrealized gains and losses recognized during the three months ended March 31, 2019 and 2018, and related effects on pre-tax income are as follows (in thousands):
| | | | Three Months Ended |
| | | | March 31, |
| Three Months Ended | 2019 | | 2018 |
| March 31, 2018 | | | |
Net gains and (losses) recognized on equity securities | $ | (1,991 | ) | $ | 16,818 |
| | $ | (1,991 | ) |
Less: Net gains and (losses) recognized on equity securities sold | 1,790 |
| |
Less: Net gains recognized on equity securities sold | | 128 |
| | 1,790 |
|
Unrealized gains and (losses) recognized on equity securities still held at reporting date | $ | (3,781 | ) | $ | 16,690 |
| | $ | (3,781 | ) |
Fair Value Measurements. The FASB guidance requires the Company to provide expanded quantitative disclosures for financial assets and liabilities recorded on the balance sheet at fair value. Financial assets carried at fair value include the Company's decommissioning trust investments and investments in debt securities which are included in deferred charges and other assets on the Balance Sheets. The Company has no liabilities that are measured at fair value on a recurring basis. The FASB guidance establishes a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value into three levels as follows:
Level 1 – Observable inputs that reflect quoted market prices for identical assets and liabilities in active markets. Financial assets utilizing Level 1 inputs include the nuclear decommissioning trustNDT investments in active exchange-traded equity securities, mutual funds and U.S. Treasury securities that are in a highly liquid and active market. The Institutional Funds are valued using the Net Asset Value ("NAV") provided by the administrator of the fund. The NAV price is quoted on a
EL PASO ELECTRIC COMPANY
NOTES TO FINANCIAL STATEMENTS
(Unaudited)
restrictive market although the underlying investments are traded on active markets. The NAV used for determining the fair value of the Institutional Funds-International Equity investments have readily determinable fair values. Accordingly, such fund values are categorized as Level 1.
Level 2 – Inputs other than quoted market prices included in Level 1 that are observable for the asset or liability either directly or indirectly. Financial assets utilizing Level 2 inputs include the nuclear decommissioning trustNDT investments in fixed income securities. The fair value of these financial instruments is based on evaluated prices that reflect observable market information, such as actual trade information of similar securities, adjusted for observable differences.
Level 3 – Unobservable inputs using data that is not corroborated by market data and primarily based on internal Company analysis using models and various other analysis. Financial assets utilizing Level 3 inputs are the Company's investment in debt securities.
The securities in the NDT are valued using prices and other relevant information generated by market transactions involving identical or comparable securities. The FASB guidance identifies this valuation technique as the "market approach" with observable inputs. The Company analyzes available-for-sale securities to determine if losses are other than temporary.
EL PASO ELECTRIC COMPANY
NOTES TO FINANCIAL STATEMENTS
(Unaudited)
The fair value of the NDT and investments in debt securities at March 31, 20182019 and December 31, 2017,2018, and the level within the three levels of the fair value hierarchy defined by the FASB guidance are presented in the table below (in thousands):
|
| | | | | | | | | | | | | | | |
Description of Securities | Fair Value as of March 31, 2018 | | Quoted Prices in Active Markets for Identical Assets (Level 1) | | Significant Other Observable Inputs (Level 2) | | Significant Unobservable Inputs (Level 3) |
Trading Securities: | | | | | | | |
Investments in Debt Securities | $ | 1,726 |
| | $ | — |
| | $ | — |
| | $ | 1,726 |
|
Equity Securities: | | | | | | | |
Domestic | $ | 119,344 |
| | $ | 119,344 |
| | $ | — |
| | $ | — |
|
International | 28,542 |
| | 28,542 |
| | — |
| | — |
|
Total Equity Securities | 147,886 |
| | 147,886 |
| | — |
| | — |
|
Available for Sale Debt Securities: | | | | | | | |
Federal Agency Mortgage Backed Securities | 25,840 |
| | — |
| | 25,840 |
| | — |
|
U.S. Government Bonds | 54,548 |
| | 54,548 |
| | — |
| | — |
|
Municipal Debt Obligations | 12,331 |
| | — |
| | 12,331 |
| | — |
|
Corporate Debt Obligations | 36,068 |
| | — |
| | 36,068 |
| | — |
|
Total Available for Sale Debt Securities | 128,787 |
| | 54,548 |
| | 74,239 |
| | — |
|
Cash and Cash Equivalents | 7,409 |
| | 7,409 |
| | — |
| | — |
|
Total | $ | 284,082 |
| | $ | 209,843 |
| | $ | 74,239 |
| | $ | — |
|
EL PASO ELECTRIC COMPANY
NOTES TO FINANCIAL STATEMENTS
(Unaudited)
|
| | | | | | | | | | | | | | | |
Description of Securities | Fair Value as of March 31, 2019 | | Quoted Prices in Active Markets for Identical Assets (Level 1) | | Significant Other Observable Inputs (Level 2) | | Significant Unobservable Inputs (Level 3) |
Trading Securities: | | | | | | | |
Investments in Debt Securities | $ | 1,632 |
| | $ | — |
| | $ | — |
| | $ | 1,632 |
|
Equity Securities: | | | | | | | |
Domestic | $ | 127,450 |
| | $ | 127,450 |
| | $ | — |
| | $ | — |
|
International | 26,751 |
| | 26,751 |
| | — |
| | — |
|
Total Equity Securities | 154,201 |
| | 154,201 |
| | — |
| | — |
|
Available for Sale Debt Securities: | | | | | | | |
Federal Agency Mortgage Backed Securities | 30,363 |
| | — |
| | 30,363 |
| | — |
|
U.S. Government Bonds | 49,402 |
| | 49,402 |
| | — |
| | — |
|
Municipal Debt Obligations | 9,548 |
| | — |
| | 9,548 |
| | — |
|
Corporate Debt Obligations | 47,669 |
| | — |
| | 47,669 |
| | — |
|
Total Available for Sale Debt Securities | 136,982 |
| | 49,402 |
| | 87,580 |
| | — |
|
Cash and Cash Equivalents | 7,155 |
| | 7,155 |
| | — |
| | — |
|
Total | $ | 298,338 |
| | $ | 210,758 |
| | $ | 87,580 |
| | $ | — |
|
| | Description of Securities | Fair Value as of December 31, 2017 | | Quoted Prices in Active Markets for Identical Assets (Level 1) | | Significant Other Observable Inputs (Level 2) | | Significant Unobservable Inputs (Level 3) | Fair Value as of December 31, 2018 | | Quoted Prices in Active Markets for Identical Assets (Level 1) | | Significant Other Observable Inputs (Level 2) | | Significant Unobservable Inputs (Level 3) |
Trading Securities: | | | | | | | | | | | | | | |
Investments in Debt Securities | $ | 1,735 |
| | $ | — |
| | $ | — |
| | $ | 1,735 |
| $ | 1,656 |
| | $ | — |
| | $ | — |
| | $ | 1,656 |
|
Available for Sale: | | | | | | | | |
Equity Securities: | | | | | | | | |
Domestic | | $ | 111,325 |
| | $ | 111,325 |
| | $ | — |
| | $ | — |
|
International | | 24,540 |
| | 24,540 |
| | — |
| | — |
|
Total Equity Securities | | 135,865 |
| | 135,865 |
| | — |
| | — |
|
Available for Sale Debt Securities: | | | | | | | | |
Federal Agency Mortgage Backed Securities | $ | 20,732 |
| | $ | — |
| | $ | 20,732 |
| | $ | — |
| 30,713 |
| | — |
| | 30,713 |
| | — |
|
U.S. Government Bonds | 58,181 |
| | 58,181 |
| | — |
| | — |
| 47,607 |
| | 47,607 |
| | — |
| | — |
|
Municipal Debt Obligations | 16,584 |
| | — |
| | 16,584 |
| | — |
| 14,089 |
| | — |
| | 14,089 |
| | — |
|
Corporate Debt Obligations | 34,674 |
| | — |
| | 34,674 |
| | — |
| 41,773 |
| | — |
| | 41,773 |
| | — |
|
Subtotal, Debt Securities | 130,171 |
| | 58,181 |
| | 71,990 |
| | — |
| |
Domestic | 121,027 |
| | 121,027 |
| | — |
| | — |
| |
International | 28,804 |
| | 28,804 |
| | — |
| | — |
| |
Subtotal, Equity Securities | 149,831 |
| | 149,831 |
| | — |
| | — |
| |
Total Available for Sale Debt Securities | | 134,182 |
| | 47,607 |
| | 86,575 |
| | — |
|
Cash and Cash Equivalents | 6,864 |
| | 6,864 |
| | — |
| | — |
| 6,858 |
| | 6,858 |
| | — |
| | — |
|
Total | $ | 286,866 |
| | $ | 214,876 |
| | $ | 71,990 |
| | $ | — |
| $ | 276,905 |
| | $ | 190,330 |
| | $ | 86,575 |
| | $ | — |
|
There were no transfers in or out of Level 1 and Level 2 fair value measurements categories due to changes in observable inputs during the three and twelve months ended March 31, 20182019 and 2017.2018. There were no purchases, sales, issuances and settlements related to the assets in the Level 3 fair value measurement category during the three and twelve months ended March 31, 20182019 and 2017.2018.
EL PASO ELECTRIC COMPANY
NOTES TO FINANCIAL STATEMENTS
(Unaudited)
M. Long-Term Debt and Financing Obligations
Pollution Control Bonds. The Company had three series of tax-exempt unsecured PCBs in aggregate principal amount of $159.8 million as of December 31, 2018. The 2009 Series A 7.25% PCBs and the 2009 Series B 7.25% PCBs with an aggregate principal amount, together, of $100.6 million had optional redemptions beginning in February 2019 and April 2019, respectively.
The Company purchased in lieu of redemption all of the 2009 Series A 7.25% PCBs with an aggregate principal amount of $63.5 million, and all of the 2009 Series B 7.25% PCBs with an aggregate principal amount of $37.1 million, on February 1, 2019 and April 1, 2019, respectively, utilizing funds borrowed under the RCF. The Company is currently holding the PCBs and may remarket them or replace them with debt instruments of equivalent value at a future date depending on the Company's financing needs and market conditions, and in accordance with the Company's regulators' approvals.
Report of Independent Registered Public Accounting Firm
To the Shareholders and Board of Directors
El Paso Electric Company:
Results of Review of Interim Financial Information
We have reviewed the balance sheet of El Paso Electric Company (the "Company") as of March 31, 20182019, the related statements of operations and comprehensive operations for the three-month and twelve-month periods ended March 31, 20182019 and 2017,2018, the related statements of changes in common stock equity and cash flows for the three-month periods ended March 31, 20182019 and 2017,2018, and the related notes (collectively, the interim financial information). Based on our reviews, we are not aware of any material modifications that should be made to the interim financial information for it to be in conformity with U.S. generally accepted accounting principles.
We have previously audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the balance sheet of the Company as of December 31, 2017,2018, and the related statements of operations and comprehensive operations, changes in common stock equity, and cash flows for the year then ended (not presented herein); and in our report dated February 28, 2018,2019, we expressed an unqualified opinion on those financial statements. In our opinion, the information set forth in the accompanying balance sheet as of December 31, 2017,2018, is fairly stated, in all material respects, in relation to the balance sheet from which it has been derived.
Basis for Review Results
This interim financial information is the responsibility of the Company’s management. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our reviews in accordance with the standards of the PCAOB. A review of interim financial information consists principally of applying analytical procedures and making inquiries of persons responsible for financial and accounting matters. It is substantially less in scope than an audit conducted in accordance with the standards of the PCAOB, the objective of which is the expression of an opinion regarding the financial statements taken as a whole. Accordingly, we do not express such an opinion.
/s/ KPMG LLP
Houston, Texas
May 4, 20188, 2019
| |
Item 2. | Management’s Discussion and Analysis of Financial Condition and Results of Operations |
The information contained in this Item 2 updates, and should be read in conjunction with, the information set forth in Part II, Item 7 of the 20172018 Form 10-K.
FORWARD-LOOKING STATEMENTS
Certain matters discussed in this Quarterly Report on Form 10-Q, other than statements of historical fact, are “forward-looking statements.”statements” within the meaning of Section 27A of the Securities Act of 1933, as amended, (the "Securities Act"), and Section 21E of the Securities Exchange Act of 1934, as amended (the "Exchange Act"). Forward-looking statements often include words like "believe", "anticipate", "target", "project", "expect", "predict", "pro forma", "estimate", "intend", "will", "is designed to", "plan", and words of similar meaning, or are indicated by the Company's discussion of strategies or trends. Forward-looking statements describe the Company's future plans, objectives, expectations or goals. Although the Company believes that the expectations reflected in such forward-looking statements are reasonable, no assurances can be given that these expectations will prove to be correct. Such statements address future events and conditions and include, but are not limited to:
capital expenditures,
earnings,
liquidity and capital resources,
ratemaking/regulatory matters/compliance matters,
litigation,
accounting matters, including accounting for taxes and leases,
possible corporate restructurings, acquisitions and dispositions,
compliance with debt and other restrictive covenants,
interest rates and dividends,
environmental matters,
nuclear operations,
operation of the Company's generating units and its transmission and distribution systems,
the availability and costs of new and/or emerging technologies, and
the overall economy of the Company's service area.
These forward-looking statements are based on assumptions and analyses in light of the Company's experience and perception of historical trends, current conditions, expected future developments, and other factors the Company believes were appropriate in the circumstances when the statements were made. Forward-looking statements by their nature involve substantial risks and uncertainties that could significantly impact expected results, and actual future results could differ materially from those described in such statements. While it is not possible to identify all factors, the Company continues to face many risks and uncertainties. Factors that would cause or contribute to such differences include, but are not limited to:
decisions and actions of the Company's regulators and the resulting impact on the Company's operations, cost of capital, sales, and profitability,
the Company's ability to fully and timely recover its costs and earn a reasonable rate of return on its invested capital through the rates that it is permitted to charge,
rates, cost recovery mechanisms and other regulatory matters including the ability to recover fuel costs on a timely basis,
the ability of the Company's operating partners to maintain plant operations and manage operations and maintenance ("O&M&M") costs at Palo Verde and its related transmission, including costs to comply with any new or expanded regulatory or environmental requirements,
reductions in output at generation plants operated by the Company,
the size of the Company's construction program and its ability to complete construction on budget and on time,
the receipt of required approvals by regulators and other permits related to the Company’s construction programs,
the Company's reliance on significant customers,
the credit worthiness of the Company's customers,
unscheduled outages of generating units including outages at Palo Verde,
changes in customers' demand for electricity as a result of energy efficiency initiatives and emerging competing services and technologies, including distributed generation and battery storage,
individual customer groups, including distributed generation customers, may not pay their full cost of service, and other customers may or may not be required to pay the difference,
changes in, and the assumptions used for, pension and other post-retirement and post-employment benefit liability calculations, as well as actual and assumed investment returns on pension plan and other post-retirement plan assets,
the impact of changing cost escalation and other assumptions on the Company's nuclear decommissioning liability for Palo Verde, as well as actual and assumed investment returns on assets in the NDT,
disruptions in the Company's transmission system,and distribution systems, and in particular the lines that deliver power from its remote generating facilities,
the sufficiency of the Company's insurance coverage, including availability, cost, coverage and terms,
electric utility deregulation or re-regulation,
regulated and competitive markets,
ongoing municipal, state and federal activities,
cuts in military spending or prolonged shutdowns of the federal government that reduce demand for the Company's services from military and governmental customers,
political, legislative, judicial and regulatory developments,
homeland security considerations, including those associated with the U.S./Mexico border region and the energy industry,
changes in environmental laws and regulations and the enforcement or interpretation thereof, including those related to air, water or greenhouse gas emissions or other environmental matters,
economic, commercial bank, financial and capital market conditions,
increases in cost of capital,
the impact of changes in interest rates or rates of inflation,
actions by credit rating agencies,
changes in accounting requirements and other accounting matters,
changing weather trends and the impact of severe weather conditions,
possible physical or cyber attacks, intrusions or other catastrophic events,
the impact of lawsuits filed against the Company,
the impact of changes in interest rates or rates of inflation,
Texas, New Mexico and electric industry utility service reliability standards and service requirements,
uranium, natural gas, oil and wholesale electricity prices and availability,
possible income tax and interest payments as a result of audit adjustments proposed by the U.S. Internal Revenue Service ("IRS") or state taxing authorities,
the impact of recent changes to U.S. tax laws,
the impact of international trade and tariff negotiations,
the impact of U.S. health care reform legislation,
the effectiveness of the Company's risk management activities,
the Company's ability to successfully renegotiate its collective bargaining agreement,
loss of key personnel, the Company's ability to recruit and retain qualified employees and the Company's ability to successfully implement succession planning, and
other circumstances affecting anticipated operations, sales and costs.
These lists are not all-inclusive because it is not possible to predict all factors. A discussion of some of these factors is included in the 20172018 Form 10-K under the headings “Risk Factors”"Risk Factors" and “Management's"Management's Discussion and Analysis of Financial Condition and Results of Operations - Summary of Critical Accounting Policies and Estimates" and “Management's"Management's Discussion and Analysis of Financial Condition and Results of Operations - Liquidity and Capital Resources”Resources". This Quarterly Report on Form
10-Q should be read in its entirety. Management cautions against putting undue reliance on forward-looking statements or projecting any future results based on such statements or present or prior earnings levels. Any forward-looking statement speaks only as of the date such statement was made, and the Company is not obligated to update any forward-looking statement to reflect events or circumstances after the date on which such statement was made, except as required by applicable laws or regulations.
Summary of Critical Accounting Policies and Estimates
The preparation of our financial statements requires management to make estimates and assumptions that affect the amounts reported in the financial statements and related notes for the periods presented and actual results could differ in future periods from those estimates. Critical accounting policies and estimates are both important to the portrayal of our financial condition and results of operations and require complex, subjective judgments and are more fully described in the "Management's Discussion and Analysis of Financial Condition and Results of Operations" in the 20172018 Form 10-K.
Summary
The following is an overview of our results of operations for the three and twelve month-month periods ended March 31, 20182019 and 20172018. Net income (loss) and basic earnings (loss) per share for the three and twelve month-month periods ended March 31, 20182019 and 20172018, are shown below:
| | | Three Months Ended | | Twelve Months Ended | Three Months Ended | | Twelve Months Ended |
` | March 31, | | March 31, | |
| | March 31, | | March 31, |
| 2018 | | 2017 | | 2018 | | 2017 | 2019 | | 2018 | | 2019 | | 2018 |
Net income (loss) (in thousands) | $ | (6,966 | ) | | $ | (3,989 | ) | | $ | 95,285 |
| | $ | 98,587 |
| $ | 6,089 |
| | $ | (6,966 | ) | | $ | 97,370 |
| | $ | 95,285 |
|
Basic earnings (loss) per share | (0.17 | ) | | (0.10 | ) | | 2.35 |
| | 2.43 |
| 0.15 |
| | (0.17 | ) | | 2.39 |
| | 2.35 |
|
The following table shows the primary factors affecting the after-tax change in net income (loss) between the 20182019 and 20172018 periods presented (in thousands):
|
| | | | | | | | |
| | Three Months Ended | | Twelve Months Ended |
March 31, 2017 net income (loss) | | $ | (3,989 | ) | | $ | 98,587 |
|
Change in (net of tax): | | | | |
Decreased investment and interest income (a) | | (3,249 | ) | | (967 | ) |
Increased depreciation and amortization (b) | | (1,486 | ) | | (7,715 | ) |
Increased administrative and general expenses (c) | | (888 | ) | | (955 | ) |
Decreased operation and maintenance at fossil-fuel generating plants (d) | | 2,625 |
| | 4,015 |
|
Increased retail non-fuel base revenues (e) | | 258 |
| | 6,689 |
|
Increased (decreased) allowance for funds used during construction (f) | | 190 |
| | (3,187 | ) |
Decreased (increased) taxes other than income taxes (g) | | 176 |
| | (3,310 | ) |
Effective tax rate (h) | | 40 |
| | 3,408 |
|
Increased (decreased) wheeling revenues (i) | | 14 |
| | (2,990 | ) |
Palo Verde performance rewards, net (j) | | — |
| | 3,253 |
|
Other | | (657 | ) | | (1,543 | ) |
March 31, 2018 net income (loss) | | $ | (6,966 | ) | | $ | 95,285 |
|
|
| | | | | | | | |
| | Three Months Ended | | Twelve Months Ended |
March 31, 2018 net income (loss) | | $ | (6,966 | ) | | $ | 95,285 |
|
Change in (net of tax at 21%): | | | | |
Increased investment and interest income, NDT (a) | | 14,839 |
| | 63 |
|
Increased wheeling revenues (b) | | 1,358 |
| | 2,065 |
|
Increased retail non-fuel base revenues (c) | | 882 |
| | 104 |
|
Decreased Palo Verde operations and maintenance expenses (d) | | 657 |
| | 3,404 |
|
(Increased) decreased income tax expense-other (e) | | (1,327 | ) | | 15,344 |
|
Increased depreciation and amortization (f) | | (1,036 | ) | | (3,927 | ) |
Increased interest charges (credits) (g) | | (939 | ) | | (1,866 | ) |
Increased transmission and distribution operation and maintenance expenses (h) | | (781 | ) | | (2,374 | ) |
Decreased deregulated Palo Verde Unit 3 revenues (i) | | (456 | ) | | (1,512 | ) |
Increased operations and maintenance expenses at fossil-fuel generating plants (j) | | (416 | ) | | (5,559 | ) |
Palo Verde performance rewards, net (k) | | — |
| | (3,954 | ) |
Other | | 274 |
| | 297 |
|
March 31, 2019 net income | | $ | 6,089 |
| | $ | 97,370 |
|
______________
All information presented below is expressed in pre-tax amounts except when stated otherwise.
| |
(a) | Investment and interest income decreasedincreased for the three months ended March 31, 2018,2019, compared to the three months ended March 31, 2017,2018, primarily due to $3.8 million of net realized and unrealized investment losses fromgains on securities held in the NDT recognized in net income (loss) as required byNDT. Beginning on January 1, 2018, the Company adopted ASU 2016-01, Financial Instruments, which was adoptedand began recording unrealized gains and losses on equity securities held in the NDT directly in earnings. Refer to "Use of Non-GAAP Financial Measures" below for further details. |
| |
(b) | Wheeling revenues increased for the three and twelve months ended March 31, 2019, compared to the three and twelve months ended March 31, 2018, primarily due to an increase in short-term hourly transmission sales due to favorable market conditions. |
| |
(c) | Retail non-fuel base revenues, excluding the impact of rate changes, increased for the three months ended March 31, 2019, compared to the three months ended March 31, 2018, primarily due to increased revenues from residential customers of $1.2 million caused by increased kWh sales that resulted from an increase in the Company on January 1,average number of residential customers served and favorable weather compared to the three months ended March 31, 2018. |
| |
(d) | Decreased Palo Verde O&M expenses for the twelve months ended March 31, 2019, compared to the twelve months ended March 31, 2018, primarily due to (i) lower incentives, (ii) administrative and general ("A&G") benefits, and (iii) a $0.9 million decrease in realized gains on securities sold fromproperty insurance costs. |
| |
(e) | Increased income tax expense-other for the NDT.three months ended March 31, 2019, compared to the three months ended March 31, 2018, primarily due to differences in the annual effective tax rate and lower values of vested stock incentives. |
Investment and interestDecreased income decreasedtax expense-other for the twelve months ended March 31, 2018,2019, compared to the twelve months ended March 31, 2017,2018, primarily due to $3.8 million of net unrealized investment losses from the NDT recognized in net income as required by ASU 2016-01, Financial Instruments, which was adopted by the Company on January 1, 2018. Thisa decrease was partially offset by a $1.3 million increase in realized gains on securities sold from the NDT, and a $0.9 million increase in the expected return on plan assets held byfederal corporate income tax rate from 35% to 21%, excluding the Company's employee benefit plans. See Note Jtax impact of other items in the Notes to Financial Statements for the financial statement effect upon adoption of ASU 2017-07, Compensation - Retirement Benefits.table above, and other permanent differences.
| |
(b)(f) | Depreciation and amortization increased for the three and twelve months ended March 31, 2019, compared to the three and twelve months ended March 31, 2018, compared to the three months ended March 31, 2017, primarily due to increased plant balances. |
Depreciation and amortization
| |
(g) | Interest charges (credits) increased for the three months ended March 31, 2019, compared to the three months ended March 31, 2018, primarily due to interest expense on the $125.0 million aggregate principal amount of 4.22% Senior Notes due 2028 issued in June 2018, and an increase in the interest cost component of net periodic benefit cost of the Company’s employee benefit plans. These increases were partially offset by the purchase in lieu of redemption of $63.5 million principal amount of 2009 Series A 7.25% PCBs on February 1, 2019. |
Interest charges (credits) increased for the twelve months ended March 31, 2018,2019, compared to the twelve months ended March 31, 2017,2018, primarily due to interest expense on the $125.0 million aggregate principal amount of 4.22% Senior Notes due 2028 issued in June 2018. This increase was partially offset by (i) the purchase in lieu of redemption of $63.5 million principal amount of 2009 Series A 7.25% PCBs on February 1, 2019, (ii) increased plantallowance for borrowed funds used during construction ("ABFUDC") as a result of higher average balances of construction work in progress ("CWIP") and (ii) the cumulative adjustment of approximately $2.5
million, recordedan increase in the twelve months ended March 31, 2017, which related toABFUDC rate, and (iii) the first quarterredemption of 2016 resulting from reduced depreciation rates approved$33.3 million principal amount of 2012 Series A 1.875% PCBs in the 2016 PUCT Final Order.2017.
| |
(c)(h) | AdministrativeTransmission and general ("A&G") expensedistribution O&M expenses increased for the three months ended March 31, 2018, compared to the three months ended March 31, 2017, primarily due to an increase in pension and benefits expenses as a result of changes in actuarial assumptions used to calculate expenses for retirement benefit plans and an adjustment in estimated Four Corners pension and benefit costs recorded in the three months ended March 31, 2017. |
A&G expense increased for the twelve months ended March 31, 2018, compared to the twelve months ended March 31, 2017, primarily due to increased amortization of Texas rate case expenses and an annual merit increase.
| |
(d) | Operations and maintenance ("O&M") expenses at our fossil fuel generating plants decreased for the three months ended March 31, 2018, compared to the three months ended March 31, 2017, primarily due to planned outages at Newman Units 1, 3 and 4 in the three months ended March 31, 2017, partially offset by a planned outage at the Company's Rio Grande Power Station ("Rio Grande") Unit 8 in the three months ended March 31, 2018. |
O&M expenses at our fossil fuel generating plants decreased for the twelve months ended March 31, 2018, compared to the twelve months ended March 31, 2017, primarily due to (i) the sale of the Company's interest in Units 4 and 5 of Four Corners in July 2016 and the related post-closing purchase price adjustment in 2017, and (ii) planned outages at Newman Units 1, 3 and 4 in the twelve months ended March 31, 2017. These decreases were partially offset by a planned outage at Rio Grande Unit 8 in the twelve months ended March 31, 2018.
| |
(e) | Retail non-fuel base revenues increased for the three months ended March 31, 2018, compared to the three months ended March 31, 2017, primarily due to a $2.8 million non-fuel base rate increase approved in the 2017 PUCT Final Order, and increased revenues from residential customers of $1.6 million due to increased kWh sales that resulted from favorable weather and an increase in the average number of residential customers compared to the three months ended March 31, 2017. These increases were partially offset by a reserve to refund of approximately $4.1 million to Texas customers for the reduction in the federal tax rate for the period January 1, 2018 through March 31, 2018. |
Retail non-fuel base revenues increased for the twelve months ended March 31, 2018, compared to the twelve months ended March 31, 2017, primarily due to (i) a $9.7 million non-fuel base rate increase for the period from July 18, 2017 through March 31, 2018 approved in the 2017 PUCT Final Order, (ii) increased revenues from residential customers of $6.6 million due to increased kWh sales that resulted from an increase in the average number of residential customers, and (iii) increased revenues from small commercial and industrial customers of $2.0 million that resulted from an increase in the average number of small commercial and industrial customers. These increases were partially offset by (i) approximately $5.9 million of retail non-fuel base revenues for the first quarter of 2016, which were recognized when the 2016 PUCT Final Order was approved in August 2016 and (ii) a reserve to refund approximately $4.9 million to Texas customers for the reduction in the federal tax rate for the twelve months ended March 31, 2018.
| |
(f) | AFUDC decreased for the twelve months ended March 31, 2018,2019, compared to the twelve months ended March 31, 2017, due to (i) lower balances of construction work in progress ("CWIP"),2018, primarily due to MPS Units 3increases in payroll costs and 4 being placed in service in May and September 2016, respectively, and (ii) a reduction in the AFUDC rate effective January 2017. |
| |
(g) | Taxes other than income taxes increased for the twelve months ended March 31, 2018, compared to the twelve months ended March 31, 2017, primarilyPalo Verde transmission expenses due to increased property valuations in Texas as a result of MPS Units 3 and 4 being placed in service in 2016 and increased revenue related taxes in Texas. |
| |
(h) | The effective tax rate changed for the twelve months ended March 31, 2018, compared to the twelve months ended March 31, 2017, primarily due to a decrease in state taxes and tax benefits from stock incentive plans.storm repairs. |
| |
(i) | WheelingDeregulated Palo Verde Unit 3 revenues decreased for the twelve months ended March 31, 2018,2019, compared to the twelve months ended March 31, 2017,2018, primarily due to (i) a 12.4% decrease in proxy market prices, reflecting a decline in the expirationprice of natural gas, and (ii) a contract.decrease in generation of 7.6%, caused by a spring refueling outage at Unit 3 completed in May 2018, with no comparable outage in the twelve months ended March 31, 2018. |
| |
(j) | O&M expenses at our fossil-fuel generating plants increased for the twelve months ended March 31, 2019, compared to the twelve months ended March 31, 2018, primarily due to outage costs related to Newman Units 2 & 4 and increased maintenance costs at Newman, Montana, and Rio Grande Power Station ("Rio Grande") in the twelve months ended March 31, 2019. These increases were partially offset by outage costs at Rio Grande Unit 8 during the twelve months ended March 31, 2018. |
| |
(k) | Palo Verde performance rewards of $5.0 million, associated with the 2013 to 2015 performance periods, net of disallowed fuel and purchased power costs related to the resolution of the Texas fuel reconciliation proceeding designated as PUCT Docket No. 46308 for the period from April 2013 through March 2016, were recorded in the twelve months ended March 31, 2018June 2017, with no comparable amount in the twelve months ended March 31, 2017.2019. |
Impact of New Accounting Standard and Use of Non-GAAP Financial MeasureMeasures
Upon adoption ofAs required by ASU 2016-01, Financial Instruments - Recognition and Measurement of Financial Assets and Financial Liabilities, the Company recorded, as of January 1, 2018, a cumulative effect adjustment to retained earnings of $41.0 million, net of tax, for the unrealized gains (losses) related to equity securities held in the NDT. As required by ASU 2016-01, changes in the fair value of equity securities are now recognized in the Company's Statements of Operations. The adoption of the newThis standard added the potential for significant volatility to the Company's reported results of operations as changes in the fair value of equity securities may occur. Furthermore, the equity investments included in the NDT are significant and are expected to increase significantly during the remaining life (estimated to be 27 to 30 years) of Palo Verde. Accordingly, the Company has provided the following non-GAAP financial measure which reconciles GAAP net income (loss) to non GAAP adjusted net income (loss)measures to exclude the impact of changes in fair value of equity securities and realized gains (losses) from the sale of both equity and fixed income securities. Reconciliations of both non-GAAP financial measures to the most directly comparable financial information presented in accordance with GAAP are presented in the table below. Non-GAAP adjusted net income (loss) is reconciled to GAAP net income (loss), and non-GAAP adjusted basic earnings (loss) per share is reconciled to GAAP basic earnings (loss) per share.
| | | Three Months Ended | Three Months Ended |
| March 31, | March 31, |
| 2018 | | 2017 | 2019 | | 2018 |
| (in thousands) | (In thousands except for per share data) |
Net loss (GAAP) | $ | (6,966 | ) | | $ | (3,989 | ) | |
Net income (loss) (GAAP) | | $ | 6,089 |
| | $ | (6,966 | ) |
Adjusting items before income tax effects | | | | | | |
Unrealized losses, net | 3,781 |
| | — |
| |
Realized gains, net | (1,272 | ) | | (2,191 | ) | |
Unrealized (gains) losses, net | | (16,690 | ) | | 3,781 |
|
Realized (gains) losses, net | | 701 |
| | (1,272 | ) |
Total adjustments before income tax effects | 2,509 |
| | (2,191 | ) | (15,989 | ) | | 2,509 |
|
Income taxes on above adjustments | (502 | ) | | 438 |
| 3,198 |
| | (502 | ) |
Adjusting items, net of income taxes | 2,007 |
| | (1,753 | ) | (12,791 | ) | | 2,007 |
|
Adjusted net loss (non-GAAP) | $ | (4,959 | ) | | $ | (5,742 | ) | $ | (6,702 | ) | | $ | (4,959 | ) |
| | | | |
Basic earnings (loss) per share (GAAP) | | $ | 0.15 |
| | $ | (0.17 | ) |
Adjusted basic loss per share (non-GAAP) | | $ | (0.17 | ) | | $ | (0.12 | ) |
| | | Twelve Months Ended | Twelve Months Ended |
| March 31, | March 31, |
| 2018 | | 2017 | 2019 | | 2018 |
| (In thousands) | (In thousands except for per share data) |
Net income (GAAP) | $ | 95,285 |
| | $ | 98,587 |
| $ | 97,370 |
| | $ | 95,285 |
|
Adjusting items before income tax effects | | | | | | |
Unrealized losses, net | 3,781 |
| | — |
| |
Unrealized (gains) losses, net | | (1,870 | ) | | 3,781 |
|
Realized gains, net | (9,707 | ) | | (8,443 | ) | (3,661 | ) | | (9,707 | ) |
Total adjustments before income tax effects | (5,926 | ) | | (8,443 | ) | (5,531 | ) | | (5,926 | ) |
Income taxes on above adjustments | 1,185 |
| | 1,689 |
| 1,107 |
| | 1,185 |
|
Adjusting items, net of income taxes | (4,741 | ) | | (6,754 | ) | (4,424 | ) | | (4,741 | ) |
Adjusted net income (non-GAAP) | $ | 90,544 |
| | $ | 91,833 |
| $ | 92,946 |
| | $ | 90,544 |
|
| | | | |
Basic earnings per share (GAAP) | | $ | 2.39 |
| | $ | 2.35 |
|
Adjusted basic earnings per share (non-GAAP) | | $ | 2.28 |
| | $ | 2.23 |
|
Adjusted net income (loss) isand adjusted basic earnings (loss) per share are not a measuremeasures of financial performance under GAAP and should not be considered as an alternative to net income (loss). and earnings (loss) per share, respectively. Furthermore, the Company's presentation of any non-GAAP financial measure may not be comparable to similarly titled measures used by other
companies. The Company believes adjusted net income (loss) is aand adjusted basic earnings (loss) per share are useful financial measuremeasures for investors and analysts in understanding the Company's core operating performance because iteach measure removes the effects of variances reported in the Company's results of operations that are not indicative of fundamental changes in the earnings capacity of the Company. Non-GAAP financial information should be read together with, and is not an alternative or substitute for, the Company's financial results reported in accordance with GAAP.
Historical Results of Operations
The following discussion includes detailed descriptions of factors affecting individual line items in the results of operations. The amounts presented below are presented on a pre-tax basis.
Operating revenues
We realize revenue from the sale of electricity to retail customers at regulated rates and the sale of energy in the wholesale power market generally at market-based prices. Sales for resale to our sole full requirement customer (which are FERC regulatedFERC-regulated cost-based wholesale sales within our service territory) accounted for less than 1% of revenues.
Revenues from the sale of electricity include fuel costs that are recovered from our customers through fuel adjustment mechanisms. We record deferred fuel revenues for the difference between actual fuel costs and recoverable fuel revenues until such amounts are collected from or refunded to customers. "Non-fuel base revenues" refers to our revenues from the sale of electricity excluding such fuel costs.
No retail customer accounted for more than 3% of our non-fuel base revenues for the three and twelve months ended March 31, 2018.2019. Residential and small commercial customers represent approximately 78%79% of our non-fuel base revenues for the three and twelve months ended March 31, 2018.revenues. While this customer base is more stable, it is also more sensitive to changes in weather conditions. The current rate structures in Texas and New Mexico reflect higher base rates during the peak summer season of May through October and lower base rates during November through April for our residential and small commercial and industrial customers. As a result, our business is seasonal, with higher kWh sales and revenues during the summer cooling season.
Weather significantly impacts our residential, small commercial and industrial customers, and to a lesser extent, our sales to public authorities. Heating and cooling degree days can be used to evaluate the effect of weather on energy use. For each degree the average outdoor temperature varies from a standard of 65 degrees Fahrenheit, a degree day is recorded. For the three and twelve months ended March 31, 2018,2019, retail non-fuel base revenues were positively impacted by favorable weather when compared to the three months ended March 31, 2017. Heating degree days for the three months ended March 31, 2018 increased 19.1% when compared to the three months ended March 31, 2017. Weather had a minimal impact in theand twelve months ended March 31, 2018 when compared to the twelve months ended March 31, 2017.2018. The table below shows heating and cooling degree days compared to a 10-year average.average for the periods in 2019 and 2018.
| | | Three Months Ended | | Twelve Months Ended | Three Months Ended | | Twelve Months Ended |
| March 31, | | March 31, | March 31, | | March 31, |
| | | 10-Year | | | | 10-Year | | | 10-Year | | | | 10-Year |
| 2018 | | 2017 | | Average | | 2018 | | 2017 | | Average* | 2019 | | 2018 | | Average | | 2019 | | 2018 | | Average* |
Heating degree days | 965 |
| | 810 |
| | 1,113 |
| | 1,677 |
| | 1,607 |
| | 2,081 |
| 1,134 |
| | 965 |
| | 1,123 |
| | 2,106 |
| | 1,677 |
| | 2,056 |
|
Cooling degree days | 37 |
| | 72 |
| | 35 |
| | 2,882 |
| | 2,860 |
| | 2,773 |
| 36 |
| | 37 |
| | 35 |
| | 3,173 |
| | 2,882 |
| | 2,863 |
|
______________
* Calendar year basis.
Customer growth is a key driver of the growth of retail sales. The average number of retail customers grew 1.5% and 1.7%1.6% for the three and twelve months ended March 31, 2018, respectively,2019 when compared to the three and twelve months ended March 31, 2017.2018. See the tables presented on pages 3640 and 37,41, which provide detail on the average number of retail customers and the related revenues and kWh sales.
Retail non-fuel base revenues. Retail non-fuel base revenues for the three months ended March 31, 20182019 increased $0.3$1.1 million, or 0.3%1.0%, compared to the three months ended March 31, 2017, primarily due to a $2.8 million non-fuel base rate increase approved in the 2017 PUCT Final Order.2018. Retail non-fuel base revenues decreased by a reserveincreased primarily due to refund of approximately $4.1 million to Texas customers for the reduction in the federal tax rate for the period January 1, 2018 through March 31, 2018. Excluding the $2.8 million 2017 PUCT Final Order impact and the $4.1 million reserve to refund, retail non-fuel base revenues for the three months ended March 31, 2018, increased by $1.6 million, or 1.4%, compared to the three months ended March 31, 2017. This increase primarily includes a $1.6 million increase in revenues from residential customers due toof $1.2 million caused by a 2.6% increase in kWh sales, which were driven by an increase of 1.6% in the average number of residential customers served and favorable weather, compared to the three months ended March 31, 2018.
Retail non-fuel base revenues for the twelve months ended March 31, 2019 increased $0.1 million, compared to the twelve months ended March 31, 2018. Retail non-fuel base revenues, excluding the impact of rate changes, increased primarily due to (i) increased revenues from residential customers of $15.9 million caused by a 5.8% increase in kWh sales that resulted from favorable weather and a 1.7%1.6% increase in the average number of residential customers served, compared to the three months ended March 31, 2017.
For the twelve months ended March 31, 2018 retail non-fuel base revenues increased $8.5 million, or 1.4%, compared to the twelve months ended March 31, 2017, primarily due to (i) a $9.7 million non-fuel base rate increase for the period from July 18, 2017 through March 31, 2018 approved in the 2017 PUCT Final Order,and (ii) increased revenues from residential customers of $6.6 million due to increased kWh sales that resulted from an increase in the average number of residential customers, and (iii)
increased revenues from small commercial and industrial customers of $2.0$1.6 million caused by an increase in kWh sales that resulted from favorable weather and an increase in the average number of small commercial and industrial customers. These increases were partially offset by (i) approximately $5.9 million of retail non-fuel base revenues forcustomers served, compared to the first quarter of 2016, which were recognized whentwelve months ended March 31, 2018. For the 2016 PUCT Final Order was approved in August 2016, and (ii) a reservetwelve months ended March 31, 2019, rate changes included the refunds to refund approximately $4.9 million to Texas customers for the reduction in the federal corporate income tax rate due to the TCJA of approximately $29.2 million, compared to $4.9 million for the twelve months ended March 31, 2018.2018. The reduction in rates due to the TCJA was offset by non-fuel base rate increases of approximately $4.9 million related to the 2017 PUCT Final Order.
Fuel revenues. Fuel revenues consist of revenues collected from customers under fuel recovery mechanisms approved by the state commissions and the FERC, and deferred fuel revenues, which are comprised of the difference between fuel costs and fuel revenues collected from customers. In New Mexico, fuel and purchased power costs, net of the cost of off-system sales and related shared margins, are reconciled to actual costs on a monthly basis and recovered or refunded to customers the second succeeding month. Additionally, the RPS costs for New Mexico are recovered through a separate RPS Cost Rider, which is updated annually. In Texas, fuel and purchased power costs, net of shared margins on off-system sales, are recovered through a fixed fuel factor. We can seek to revise our fixed fuel factor based upon an approved formula at least four months after our last revision, except in the month of December. In addition, if we materially over-recover fuel costs, we must seek to refund the over-recovery, and if we materially under-recover fuel costs, we may seek a surcharge to recover those costs. Fuel over- and under-recoveries are defined as material when they exceed 4% of the previous twelve months' fuel costs.
In the three and twelve months ended March 31, 2018,2019, we over-recovered our fuel costs by $8.0$12.8 million and $16.6$9.5 million, respectively. In March 2018, and March 2017, $1.1 million and $1.4 million, respectively, werewas credited to customers through the applicable fuel adjustment clauses as the result of a reimbursement from the DOE related to spent nuclear fuel storage. At March 31, 2018,2019, we had a net fuel over-recovery balance of $14.2$23.8 million, including an over-recoveryover-recoveries of $13.3$19.3 million in our Texas, and $0.9$4.4 million in our New Mexico.Mexico and $0.1 million in our FERC jurisdictions. On October 13, 2017, we filed a request to decrease our Texas fixed fuel factor by approximately 19.0%19% to reflect decreased fuel expenses primarily related to a decrease in the price of natural gas used to generate power. The decrease in our Texas fixed fuel factor became effective beginning with the November 2017 billing month. On April 13, 2018, the Companywe filed a request with the PUCT which was assigned Docket No. 48264, to decrease theour Texas fixed fuel factor by approximately 29% to reflect decreased fuel expenses primarily related to a decrease in the price of natural gas used to generate power. On April 25, 2018, the Company'sour proposed fuel factors were approved by the PUCT on an interim basis effective for the first billing cycle of the May 2018 billing month. If no partyThe revised factor was approved and the docket closed on May 22, 2018. On October 15, 2018, we filed a request with the PUCT to decrease our Texas fixed fuel factor by approximately 6.99% to reflect decreased fuel expenses primarily related to a decrease in the case requests a hearing by May 14,price of natural gas used to generate power. On October 25, 2018, our fixed fuel factor was approved on an interim basis effective for the Company's fuel factors will become final as provided byfirst billing cycle of the PUCT's rules and no further actionNovember 2018 billing month. The revised factor was approved by the PUCT is required.and the docket closed on November 19, 2018. The Texas fixed fuel factor will continue thereafter until changed by the PUCT.
On April 29, 2019, we filed a petition with the PUCT, which was assigned PUCT Docket No. 49482, requesting authority to implement, beginning on June 1, 2019, a four-month, interim fuel refund of $19.4 million in fuel cost over-recoveries, including interest, for the period from April 2016 through March 2019. We cannot predict the outcome of this filing at this time.
Off-system sales. Off-system sales are wholesale sales into wholesale markets outside our service territory. Off-system sales are primarily made in off-peak periods when we have competitive generation capacity available after meeting our regulated service obligations. We have shared 100% of margins on non-arbitrage sales (as defined by the settlement in PUCT Docket No. 41852) and 50% of margins on arbitrage sales with our Texas customers since April 1, 2014. We are currently sharing 90% of off-system sales margins with our New Mexico customers (as reaffirmed in NMPRC Case No. 09-00171-UT), and 25% of our off-system sales margins with our sales for resale - full requirement customer under the terms of theirits contract. Palo Verde's availability is an important factor in realizing these off-system sales margins.
Off-system sales revenuesrevenue increased $8.9$11.9 million, or 62.4%51.7%, for the three months ended March 31, 2018, when2019 compared to the three months ended March 31, 2017,2018, as a result of a 44.8% increase in kWh sales due to additional available power, and higher average market prices for power. Off-system sales revenuesrevenue increased $19.3$30.5 million, or 39.9%45.0%, for the twelve months ended March 31, 2018,2019, when compared to the twelve months ended March 31, 2017,2018, as a result of an 18.7%a 15.2% increase in kWh sales due to additional available power, and higher average market prices for power.
| | Comparisons of kWh sales and operating revenues are shown below (in thousands): | Comparisons of kWh sales and operating revenues are shown below (in thousands): | | | | | Comparisons of kWh sales and operating revenues are shown below (in thousands): | | | | |
| | | | | Increase (Decrease) | | | | | Increase (Decrease) |
Three Months Ended March 31: | 2018 | | 2017 | | Amount | | Percent | 2019 | | 2018 | | Amount | | Percent |
kWh sales: | | | | | | | | | | | | | | |
Retail: | | | | | | | | | | | | | | |
Residential | 559,563 |
| | 545,128 |
| | 14,435 |
| | 2.6 | % | 574,089 |
| | 559,563 |
| | 14,526 |
| | 2.6 | % |
Commercial and industrial, small | 498,675 |
| | 500,590 |
| | (1,915 | ) | | (0.4 | ) | 496,367 |
| | 498,675 |
| | (2,308 | ) | | (0.5 | ) |
Commercial and industrial, large | 248,285 |
| | 252,998 |
| | (4,713 | ) | | (1.9 | ) | 252,056 |
| | 248,285 |
| | 3,771 |
| | 1.5 |
|
Sales to public authorities | 328,329 |
| | 335,563 |
| | (7,234 | ) | | (2.2 | ) | 331,947 |
| | 328,329 |
| | 3,618 |
| | 1.1 |
|
Total retail sales | 1,634,852 |
| | 1,634,279 |
| | 573 |
| | — |
| 1,654,459 |
| | 1,634,852 |
| | 19,607 |
| | 1.2 |
|
Wholesale: | | | | | | | | | | | | | | |
Sales for resale | 11,730 |
| | 10,921 |
| | 809 |
| | 7.4 |
| |
Sales for resale - full requirement customer | | 11,770 |
| | 11,730 |
| | 40 |
| | 0.3 |
|
Off-system sales | 864,216 |
| | 596,762 |
| | 267,454 |
| | 44.8 |
| 837,162 |
| | 864,216 |
| | (27,054 | ) | | (3.1 | ) |
Total wholesale sales | 875,946 |
| | 607,683 |
| | 268,263 |
| | 44.1 |
| 848,932 |
| | 875,946 |
| | (27,014 | ) | | (3.1 | ) |
Total kWh sales | 2,510,798 |
| | 2,241,962 |
| | 268,836 |
| | 12.0 |
| 2,503,391 |
| | 2,510,798 |
| | (7,407 | ) | | (0.3 | ) |
Operating revenues: | | | | | | | | | | | | | | |
Non-fuel base revenues: | | | | | | | | | | | | | | |
Retail: | | | | | | | | | | | | | | |
Residential | $ | 53,292 |
| | $ | 51,310 |
| | $ | 1,982 |
| | 3.9 | % | $ | 54,452 |
| | $ | 53,292 |
| | $ | 1,160 |
| | 2.2 | % |
Commercial and industrial, small | 33,297 |
| | 33,785 |
| | (488 | ) | | (1.4 | ) | 33,004 |
| | 33,297 |
| | (293 | ) | | (0.9 | ) |
Commercial and industrial, large | 7,126 |
| | 7,900 |
| | (774 | ) | | (9.8 | ) | 7,246 |
| | 7,126 |
| | 120 |
| | 1.7 |
|
Sales to public authorities | 17,156 |
| | 17,550 |
| | (394 | ) | | (2.2 | ) | 17,285 |
| | 17,156 |
| | 129 |
| | 0.8 |
|
Total retail non-fuel base revenues (2)(1) | 110,871 |
| | 110,545 |
| | 326 |
| | 0.3 |
| 111,987 |
| | 110,871 |
| | 1,116 |
| | 1.0 |
|
Wholesale: | | | | | | | | | | | | | | |
Sales for resale | 476 |
| | 463 |
| | 13 |
| | 2.8 |
| |
Sales for resale - full requirement customer | | 546 |
| | 476 |
| | 70 |
| | 14.7 |
|
Total non-fuel base revenues | 111,347 |
| | 111,008 |
| | 339 |
| | 0.3 |
| 112,533 |
| | 111,347 |
| | 1,186 |
| | 1.1 |
|
Fuel revenues: | | | | | | | | | | | | | | |
Recovered from customers during the period | 39,944 |
| | 47,620 |
| | (7,676 | ) | | (16.1 | ) | 28,545 |
| | 39,944 |
| | (11,399 | ) | | (28.5 | ) |
Over collection of fuel (3)(2) | (7,950 | ) | | (8,530 | ) | | 580 |
| | 6.8 |
| (12,758 | ) | | (7,950 | ) | | (4,808 | ) | | (60.5 | ) |
Total fuel revenues (4) | 31,994 |
| | 39,090 |
| | (7,096 | ) | | (18.2 | ) | |
Off-system sales (5) | 23,055 |
| | 14,200 |
| | 8,855 |
| | 62.4 |
| |
Total fuel revenues (3)(4) | | 15,787 |
| | 31,994 |
| | (16,207 | ) | | (50.7 | ) |
Off-system sales (4)(5) | | 34,979 |
| | 23,055 |
| | 11,924 |
| | 51.7 |
|
Wheeling revenues (6) | 4,286 |
| | 4,267 |
| | 19 |
| | 0.4 |
| 6,005 |
| | 4,286 |
| | 1,719 |
| | 40.1 |
|
Energy efficiency cost recovery (7) | 1,916 |
| | — |
| | 1,916 |
| | — |
| 2,508 |
| | 1,916 |
| | 592 |
| | 30.9 |
|
Miscellaneous (6) | 2,459 |
| | 1,852 |
| | 607 |
| | 32.8 |
| 2,010 |
| | 2,459 |
| | (449 | ) | | (18.3 | ) |
Total revenues from customers | 175,057 |
| | 170,417 |
| | 4,640 |
| | 2.7 |
| 173,822 |
| | 175,057 |
| | (1,235 | ) | | (0.7 | ) |
Other (6) | 656 |
| | 918 |
| | (262 | ) | | (28.5 | ) | 541 |
| | 656 |
| | (115 | ) | | (17.5 | ) |
Total operating revenues | $ | 175,713 |
| | $ | 171,335 |
| | $ | 4,378 |
| | 2.6 |
| $ | 174,363 |
| | $ | 175,713 |
| | $ | (1,350 | ) | | (0.8 | ) |
Average number of retail customers (8): | | | | | | | | |
Average number of retail customers (7): | | | | | | | | |
Residential | 371,351 |
| | 365,311 |
| | 6,040 |
| | 1.7 | % | 377,396 |
| | 371,351 |
| | 6,045 |
| | 1.6 | % |
Commercial and industrial, small | 42,205 |
| | 42,076 |
| | 129 |
| | 0.3 |
| 42,222 |
| | 42,205 |
| | 17 |
| | — |
|
Commercial and industrial, large | 48 |
| | 49 |
| | (1 | ) | | (2.0 | ) | 48 |
| | 48 |
| | — |
| | — |
|
Sales to public authorities | 5,592 |
| | 5,433 |
| | 159 |
| | 2.9 |
| 6,204 |
| | 5,592 |
| | 612 |
| | 10.9 |
|
Total | 419,196 |
| | 412,869 |
| | 6,327 |
| | 1.5 |
| 425,870 |
| | 419,196 |
| | 6,674 |
| | 1.6 |
|
| |
(1) | 2019 and 2018 includes a $2.8include $5.1 million and $4.1 million, respectively, base rate increasedecreases related to the 2017 PUCT Final Order received in December 2017. |
| |
(2) | The 2017 PUCT Final Order included a provision to pass through tax savings to Texas customers for the reduction in federal statutory income tax rate enacted under the TCJA. 2018 includes a $4.1 million reserve, pending the PUCT's final approval of the refund tariff. |
| |
(3)(2) | Includes2018 includes the portion of the DOE refunds related to spent fuel storage of $1.1 million and $1.4 million in 2018 and 2017, respectively, that werewas credited to customers through the applicable fuel adjustment clauses. |
| |
(4)(3) | Includes deregulated Palo Verde Unit 3 revenues for the New Mexico jurisdiction of $1.9 million and $2.4 million in 2019 and $2.8 million2018, respectively. |
| |
(4) | Off-system sales increased due to favorable market conditions and lower gas prices, which resulted in 2018 and 2017, respectively.increased margins credited to customers through the fuel adjustment clause. |
| |
(5) | Includes retained margins of $0.9 million and $0.6 million in 2019 and $0.5 million in 2018, and 2017, respectively. |
| |
(6) | Represents revenuesrevenue with no related kWh sales. |
| |
(7) | The Company implemented ASU 2014-09, Revenue from Contracts with Customers, in the first quarter of 2018, and as required by the standard, revenues related to reimbursed costs of energy efficiency programs approved by the Company's regulators are reported in operating revenues from customers. Related expenses are reported in operations and maintenance expenses. |
| |
(8) | The number of retail customers presented is based on the number of service locations. |
| | Comparisons of kWh sales and operating revenues are shown below (in thousands): | Comparisons of kWh sales and operating revenues are shown below (in thousands): | | | | | Comparisons of kWh sales and operating revenues are shown below (in thousands): | | | | |
| | | | | Increase (Decrease) | | | | | Increase (Decrease) |
Twelve Months Ended March 31: | 2018 | | 2017 | | Amount | | Percent | 2019 | | 2018 | | Amount | | Percent |
kWh sales: | | | | | | | | | | | | | | |
Retail: | | | | | | | | | | | | | | |
Residential | 2,837,694 |
| | 2,781,832 |
| | 55,862 |
| | 2.0 | % | 3,003,221 |
| | 2,837,694 |
| | 165,527 |
| | 5.8 | % |
Commercial and industrial, small | 2,408,795 |
| | 2,403,811 |
| | 4,984 |
| | 0.2 |
| 2,429,612 |
| | 2,408,795 |
| | 20,817 |
| | 0.9 |
|
Commercial and industrial, large | 1,040,606 |
| | 1,038,817 |
| | 1,789 |
| | 0.2 |
| 1,054,605 |
| | 1,040,606 |
| | 13,999 |
| | 1.3 |
|
Sales to public authorities | 1,557,436 |
| | 1,561,838 |
| | (4,402 | ) | | (0.3 | ) | 1,566,845 |
| | 1,557,436 |
| | 9,409 |
| | 0.6 |
|
Total retail sales | 7,844,531 |
| | 7,786,298 |
| | 58,233 |
| | 0.7 |
| 8,054,283 |
| | 7,844,531 |
| | 209,752 |
| | 2.7 |
|
Wholesale: | | | | | | | | | | | | | | |
Sales for resale | 63,696 |
| | 61,166 |
| | 2,530 |
| | 4.1 |
| |
Sales for resale - full requirement customer | | 59,031 |
| | 63,696 |
| | (4,665 | ) | | (7.3 | ) |
Off-system sales | 2,310,338 |
| | 1,945,597 |
| | 364,741 |
| | 18.7 |
| 2,660,907 |
| | 2,310,338 |
| | 350,569 |
| | 15.2 |
|
Total wholesale sales | 2,374,034 |
| | 2,006,763 |
| | 367,271 |
| | 18.3 |
| 2,719,938 |
| | 2,374,034 |
| | 345,904 |
| | 14.6 |
|
Total kWh sales | 10,218,565 |
| | 9,793,061 |
| | 425,504 |
| | 4.3 |
| 10,774,221 |
| | 10,218,565 |
| | 555,656 |
| | 5.4 |
|
Operating revenues: | | | | | | | | | | | | | | |
Non-fuel base revenues: | | | | | | | | | | | | | | |
Retail: | | | | | | | | | | | | | | |
Residential | $ | 289,866 |
| | $ | 282,341 |
| | $ | 7,525 |
| | 2.7 | % | $ | 298,757 |
| | $ | 289,866 |
| | $ | 8,891 |
| | 3.1 | % |
Commercial and industrial, small | 198,311 |
| | 196,587 |
| | 1,724 |
| | 0.9 |
| 194,048 |
| | 198,311 |
| | (4,263 | ) | | (2.1 | ) |
Commercial and industrial, large | 37,629 |
| | 38,877 |
| | (1,248 | ) | | (3.2 | ) | 35,040 |
| | 37,629 |
| | (2,589 | ) | | (6.9 | ) |
Sales to public authorities | 97,496 |
| | 97,031 |
| | 465 |
| | 0.5 |
| 95,589 |
| | 97,496 |
| | (1,907 | ) | | (2.0 | ) |
Total retail non-fuel base revenues (1)(2) | 623,302 |
| | 614,836 |
| | 8,466 |
| | 1.4 |
| 623,434 |
| | 623,302 |
| | 132 |
| | — |
|
Wholesale: | | | | | | | | | | | | | | |
Sales for resale | 2,743 |
| | 2,501 |
| | 242 |
| | 9.7 |
| |
Sales for resale - full requirement customer | | 2,850 |
| | 2,743 |
| | 107 |
| | 3.9 |
|
Total non-fuel base revenues | 626,045 |
| | 617,337 |
| | 8,708 |
| | 1.4 |
| 626,284 |
| | 626,045 |
| | 239 |
| | — |
|
Fuel revenues: | | | | | | | | | | | | | | |
Recovered from customers during the period | 210,704 |
| | 190,536 |
| | 20,168 |
| | 10.6 |
| 145,094 |
| | 210,704 |
| | (65,610 | ) | | (31.1 | ) |
(Over) under collection of fuel (3) | (16,553 | ) | | 10,466 |
| | (27,019 | ) | | — |
| |
Over collection of fuel (3) | | (9,544 | ) | | (16,553 | ) | | 7,009 |
| | 42.3 |
|
Total fuel revenues (4)(5) | 194,151 |
| | 201,002 |
| | (6,851 | ) | | (3.4 | ) | 135,550 |
| | 194,151 |
| | (58,601 | ) | | (30.2 | ) |
Off-system sales (6) | 67,841 |
| | 48,495 |
| | 19,346 |
| | 39.9 |
| 98,342 |
| | 67,841 |
| | 30,501 |
| | 45.0 |
|
Wheeling revenues (7) | 18,133 |
| | 21,917 |
| | (3,784 | ) | | (17.3 | ) | 20,745 |
| | 18,133 |
| | 2,612 |
| | 14.4 |
|
Energy efficiency cost recovery (8) | 1,916 |
| | — |
| | 1,916 |
| | — |
| 9,480 |
| | 1,916 |
| | 7,564 |
| | — |
|
Miscellaneous (7) | 8,836 |
| | 7,715 |
| | 1,121 |
| | 14.5 |
| 7,739 |
| | 8,836 |
| | (1,097 | ) | | (12.4 | ) |
Total revenue from customers | 916,922 |
| | 896,466 |
| | 20,456 |
| | 2.3 |
| |
Total revenues from customers | | 898,140 |
| | 916,922 |
| | (18,782 | ) | | (2.0 | ) |
Other (7)(9) | 4,253 |
| | 3,996 |
| | 257 |
| | 6.4 |
| 4,113 |
| | 4,253 |
| | (140 | ) | | (3.3 | ) |
Total operating revenues | $ | 921,175 |
| | $ | 900,462 |
| | $ | 20,713 |
| | 2.3 |
| $ | 902,253 |
| | $ | 921,175 |
| | $ | (18,922 | ) | | (2.1 | ) |
Average number of retail customers (10): | | | | | | | | | | | | | | |
Residential | 369,554 |
| | 363,454 |
| | 6,100 |
| | 1.7 | % | 375,649 |
| | 369,554 |
| | 6,095 |
| | 1.6 | % |
Commercial and industrial, small | 42,010 |
| | 41,398 |
| | 612 |
| | 1.5 |
| 42,354 |
| | 42,010 |
| | 344 |
| | 0.8 |
|
Commercial and industrial, large | 48 |
| | 49 |
| | (1 | ) | | (2.0 | ) | 48 |
| | 48 |
| | — |
| | — |
|
Sales to public authorities | 5,571 |
| | 5,319 |
| | 252 |
| | 4.7 |
| 5,898 |
| | 5,571 |
| | 327 |
| | 5.9 |
|
Total | 417,183 |
| | 410,220 |
| | 6,963 |
| | 1.7 |
| 423,949 |
| | 417,183 |
| | 6,766 |
| | 1.6 |
|
| |
(1) | 2019 and 2018 includes a $9.7 millioninclude base rate increase for the period from July 18, 2017 through March 31, 2018 related to the 2017 PUCT Final Order.Order effective July 18, 2017. |
| |
(2) | The 2017 PUCT Final Order included a provision2019 and 2018 include $29.2 million and $4.9 million (for the period January 1, 2018 through March 31, 2018), respectively, base rate decreases related to pass through tax savings to Texas customers for the reduction in federal statutory income tax rate enacted under the TCJA. 2018 includes a $4.9 million reserve, pending the PUCT's approval of the refund tariff. |
| |
(3) | Includes2018 includes the portion of the DOE refunds related to spent fuel storage of $1.1 million and $1.4 million in 2018 and 2017, respectively, that was credited to customers through the applicable fuel adjustment clauses. |
| |
(4) | 2018 includes $5.0 million related to the Palo Verde performance rewards, net. |
| |
(5) | Includes deregulated Palo Verde Unit 3 revenues for the New Mexico jurisdiction of $7.6 million and $9.4 million in 2019 and $9.3 million in 2018, and 2017, respectively. |
| |
(6) | Includes retained margins of $2.4 million and $1.8 million in 2019 and $1.2 million for 2018, and 2017, respectively. |
| |
(7) | Represents revenuesrevenue with no related kWh sales. |
| |
(8) | The Company implemented ASU 2014-09, Revenue from Contracts with Customers, in the first quarter ofJanuary 1, 2018, and as required byfollowing the adoption of the standard, revenues related to reimbursed costs of energy efficiency programs approved by the Company's regulators are reported in operating revenues from customers. Related expenses are reported in operations and maintenanceO&M expenses. |
| |
(9) | Includes energy efficiency bonuses of $1.3 million and $1.2 million in 2019 and $0.8 million in 2018, and 2017, respectively. |
| |
(10) | The number of retail customers presented is based on the number of service locations. |
Energy expensesFuel and purchased power expense
Our sources of energy include electricity generated from our nuclear and natural gas generating plants and purchased power. Palo Verde represents approximately 30% of our net dependable generating capacity and approximately 58%60% and 54%50% of our Company-generated energy for the three and twelve months ended March 31, 2018 and 2017,2019, respectively. Fluctuations in the price of natural gas, which also is the primary factor influencing the price of purchased power, have had a significant impact on our cost of energy.
Energy expenses increased $1.9Fuel and purchased power expense decreased $3.9 million, or 3.8%7.4%, for the three months ended March 31, 2018, when2019 compared to the three months ended March 31, 2017,2018, primarily due to increaseda decrease in natural gas costs of $5.0$8.9 million primarily due to a 72.6% increase in Megawatt-hours ("MWhs") generated with natural gas partially offset by a 30.9%23.1% decrease in the average cost of megawatt-hours ("MWhs") generated and a 7.1% decrease in MWhs generated.generated with natural gas. This increase in energy expensesdecrease was partially offset by (i) decreasedincreased total purchased power costs of $2.5$3.8 million primarily due to a 32.3% decrease in the MWhs purchased partially offset by a 20.3%20.2% increase in the average cost of MWhs purchased and a 11.8% increase in the MWhs purchased and (ii) decreasedincreased nuclear costs of $0.5$1.2 million primarily due to a 6.7% decrease in the average cost of MWhs generated and a 1.2% decrease in MWhs generated with nuclear fuel partially offset by a $0.4$1.2 million reduction in the 2018 DOE refund compared to 2017.received in 2018 with no comparable activity in 2019.
| | | Three Months Ended March 31, | Three Months Ended March 31, |
| 2018 | | 2017 | 2019 | | 2018 |
Fuel Type | Cost | | MWh | | Cost per MWh | | Cost | | MWh | | Cost per MWh | Cost | | MWh | | Cost per MWh | | Cost | | MWh | | Cost per MWh |
| (in thousands) | | | | | | (in thousands) | | | | | (in thousands) | | | | | | (in thousands) | | | | |
Natural gas | $ | 31,145 |
| | 985,107 |
| | $ | 31.62 |
| | $ | 26,106 |
| | 570,825 |
| | $ | 45.73 |
| $ | 22,279 |
| | 915,521 |
| | $ | 24.33 |
| | $ | 31,145 |
| | 985,107 |
| | $ | 31.62 |
|
Coal (a) | 165 |
| | — |
| | — |
| | 208 |
| | — |
| | — |
| 165 |
| | — |
| | — |
| | 165 |
| | — |
| | — |
|
Nuclear (b) | 9,744 |
| | 1,346,507 |
| | 8.12 |
| | 10,292 |
| | 1,363,527 |
| | 8.70 |
| 10,919 |
| | 1,364,307 |
| | 8.00 |
| | 9,744 |
| (b) | 1,346,507 |
| | 8.12 |
|
Total | 41,054 |
| | 2,331,614 |
| | 18.12 |
| | 36,606 |
| | 1,934,352 |
| | 19.73 |
| 33,363 |
| | 2,279,828 |
| | 14.63 |
| | 41,054 |
| | 2,331,614 |
| | 18.12 |
|
Purchased power: | | | | | | | | | | | | | | | | | | | | | | |
Photovoltaic | 5,024 |
| | 61,570 |
| | 81.60 |
| | 5,298 |
| | 64,735 |
| | 81.84 |
| 4,793 |
| | 58,768 |
| | 81.56 |
| | 5,024 |
| | 61,570 |
| | 81.60 |
|
Other | 6,110 |
| | 228,244 |
| | 26.77 |
| | 8,375 |
| | 363,375 |
| | 23.05 |
| 10,170 |
| | 265,303 |
| | 38.33 |
| | 6,110 |
| | 228,244 |
| | 26.77 |
|
Total purchased power | 11,134 |
| | 289,814 |
| | 38.42 |
| | 13,673 |
| | 428,110 |
| | 31.94 |
| 14,963 |
| | 324,071 |
| | 46.17 |
| | 11,134 |
| | 289,814 |
| | 38.42 |
|
Total energy | $ | 52,188 |
| | 2,621,428 |
| | 20.36 |
| | $ | 50,279 |
| | 2,362,462 |
| | 21.95 |
| |
Total fuel and purchased power | | $ | 48,326 |
| | 2,603,899 |
| | 18.56 |
| | $ | 52,188 |
| | 2,621,428 |
| | 20.36 |
|
___________________________________
(a) Costs related to amortization of deferred coal mine reclamation obligations.
(b) CostsCost includes a DOE refund related to spent fuel storage of $1.2 million and $1.6 million recorded in March 2018 and 2017, respectively.2018. Cost per MWh excludes these refunds.this refund.
Energy expenses increased $6.9Fuel and purchased power expense decreased $21.4 million, or 2.9%8.7%, for the twelve months ended March 31, 2018, when2019 compared to the twelve months ended March 31, 2017,2018, primarily due to increased(i) decreased natural gas costs of $18.5$26.5 million primarily due to a 22.1% increase in in MWhs generated with natural gas partially offset by a 6.4% decrease in the average cost of MWhs generated. This increase in energy expenses was partially offset by (i) decreased total purchased power costs of $6.6 million due to a 17.9% decrease in MWhs purchased partially offset by a 9.1% increase in the average cost of MWhs purchased, (ii) decreased coal costs of $3.2 million as a result of the sale of our interest in Four Corners, a coal-fired generation station, on July 6, 2016, and (iii) decreased nuclear costs of $1.8 million due to a 5.1%29.7% decrease in the average cost of MWhs generated, partially offset by a 16.6% increase in the MWhs generated with natural gas, (ii) decreased nuclear costs of $1.4 million primarily due to a reduction in the price of uranium and a 3.2% decrease in the MWhs generated with nuclear fuel.fuel, offset by a $1.2 million DOE refund received in 2018 with no comparable activity in 2019, and (iii) increased total purchased power costs of $6.4 million primarily due to a 12.3% increase in the average cost of MWhs purchased.
|
| | | | | | | | | | | | | | | | | | | | | |
| Twelve Months Ended March 31, |
| 2019 | | 2018 |
Fuel Type | Cost | | MWh | | Cost per MWh | | Cost | | MWh | | Cost per MWh |
| (in thousands) | | | | | | (in thousands) | | | | |
Natural gas | $ | 120,717 |
| | 4,960,277 |
| | $ | 24.34 |
| | $ | 147,266 |
| | 4,255,832 |
| | $ | 34.60 |
|
Coal (a) | 661 |
| | — |
| | — |
| | 532 |
| | — |
| | — |
|
Nuclear | 40,293 |
| | 4,931,658 |
| | 8.17 |
| | 41,719 |
| (b) | 5,092,305 |
| | 8.43 |
|
Total | 161,671 |
| | 9,891,935 |
| | 16.34 |
| | 189,517 |
| | 9,348,137 |
| | 20.40 |
|
Purchased power: | | | | | | | | | | | |
Photovoltaic | 21,997 |
| | 272,767 |
| | 80.64 |
| | 23,510 |
| | 288,992 |
| | 81.35 |
|
Other | 41,579 |
| | 1,116,799 |
| | 37.23 |
| | 33,633 |
| | 1,113,553 |
| | 30.20 |
|
Total purchased power | 63,576 |
| | 1,389,566 |
| | 45.75 |
| | 57,143 |
| | 1,402,545 |
| | 40.74 |
|
Total fuel and purchased power | $ | 225,247 |
| | 11,281,501 |
| | 19.97 |
| | $ | 246,660 |
| | 10,750,682 |
| | 23.05 |
|
_____________
|
| | | | | | | | | | | | | | | | | | | | | |
| Twelve Months Ended March 31, |
| 2018 | | 2017 |
Fuel Type | Cost | | MWh | | Cost per MWh | | Cost | | MWh | | Cost per MWh |
| (in thousands) | | | | | | (in thousands) | | | | |
Natural gas | $ | 147,266 |
| | 4,255,832 |
| | $ | 34.60 |
| | $ | 128,776 |
| | 3,484,299 |
| | $ | 36.96 |
|
Coal (a) | 532 |
| | — |
| | — |
| | 3,727 |
| | 94,252 |
| | 39.54 |
|
Nuclear (b) | 41,719 |
| | 5,092,305 |
| | 8.43 |
| | 43,522 |
| | 5,076,874 |
| | 8.88 |
|
Total | 189,517 |
| | 9,348,137 |
| | 20.40 |
| | 176,025 |
| | 8,655,425 |
| | 20.52 |
|
Purchased power: | | | | | | | | | | | |
Photovoltaic | 23,510 |
| | 288,992 |
| | 81.35 |
| | 23,203 |
| | 286,771 |
| | 80.91 |
|
Other | 33,633 |
| | 1,113,553 |
| | 30.20 |
| | 40,551 |
| | 1,420,669 |
| | 28.54 |
|
Total purchased power | 57,143 |
| | 1,402,545 |
| | 40.74 |
| | 63,754 |
| | 1,707,440 |
| | 37.34 |
|
Total energy | $ | 246,660 |
| | 10,750,682 |
| | 23.05 |
| | $ | 239,779 |
| | 10,362,865 |
| | 23.29 |
|
_____________(a) The sale of our interest in Four Corners, coal-fired generation station, closed on July 6, 2016. The costs include theCosts related to amortization of deferred
coal mine reclamation obligations.
(b) Costs includeCost includes a DOE refund related to spent fuel storage of $1.2 million and $1.6 million recorded in March 2018 and 2017, respectively.
2018. Cost per MWh excludes these refunds.this refund.
Operations and maintenance expense
Operations and maintenance expense increased $1.0$0.3 million, or 1.2%0.3%, for the three months ended March 31, 2018,2019, compared to the three months ended March 31, 2017,2018, primarily due to increases of (i) $1.9$1.0 million relatedin transmission and distribution expenses and (ii) $0.6 million due to the timing of energy efficiency program costs. These increases were partially offset by decreases of (i) $0.8 million in A&G expense primarily due to changes in actuarial assumptions used to calculate expenses for retirement benefit plans and decreases in costs for employee benefits and (ii) $0.8 million in O&M expenses at Palo Verde.
Operations and maintenance expense increased $13.9 million, or 4.3%, for the twelve months ended March 31, 2019, compared to the twelve months ended March 31, 2018, primarily due to increases of (i) $7.6 million primarily due to energy efficiency program costs previously offset by the related revenues prior to the adoption of ASU 2014-09, (ii) $1.1$6.6 million due to an adjustment in estimated Four Corners pensionoutage costs at Newman Units 2 and benefit4, (iii) $4.9 million in increased maintenance costs recorded in the three months ended March 31, 2017, (iii) $0.6at Newman and Montana, (iv) $3.0 million in transmission and distribution expense primarily due to increases in payroll costs and wheeling expense,Palo Verde transmission expenses due to storm repairs, and (iv) $0.5(v) $0.8 million in Four Corners operating expenses due to post-closing purchase price adjustments recorded in the twelve months ended March 31, 2018. These increases were partially offset by decreases of (i) $4.3 million in O&M expenses at Palo Verde. These increases were partially offset by a $3.3Verde and (ii) $3.1 million decrease in O&M expenses at our fossil fuel generating plants primarily due to planned outages at Newman Units 1, 3 and 4 in the three months ended March 31, 2017, offset by a planned outage costs at Rio Grande Unit 8 in the three months ended March 31, 2018.
Operations and maintenance expense increased $3.7 million, or 1.2%, for the twelve months ended March 31, 2018, compared to the twelve months ended March 31, 2017, primarily due to increases of (i) $3.8 million in O&M expenses primarily due to a $3.0 million adjustment to A&G expenses at Palo Verde, (ii) $1.9 million related to energy efficiency programs expense reported in operations and maintenance expense as required by ASU 2014-09, (iii) $1.6 million in transmission expense primarily due to increases in payroll costs and wheeling expense, and (iv) $1.5 million in A&G expense primarily due to increased amortization of Texas rate case expenses and an annual merit increase. These increases were partially offset by a $4.8 million decrease in O&M expenses due to the sale of the Company's interest in Units 4 and 5 of Four Corners in July 2016.8.
Depreciation and amortization expense
Depreciation and amortization expense increased $1.9$1.3 million, or 8.6%5.5%, and $5.0 million, or 5.4%, for the three and twelve months ended March 31, 2019, compared to the three and twelve months ended March 31, 2018, compared to the three months ended March 31, 2017, primarily due to increased plant balances.
Depreciation and amortization expense increased $9.8 million, or 11.8%, for the twelve months ended March 31, 2018, compared to the twelve months ended March 31, 2017, primarily due to (i) increased plant balances and (ii) the cumulative adjustment of approximately $2.5 million, recorded in the twelve months ended March 31, 2017, which related to the first quarter of 2016 resulting from reduced depreciation rates approved in the 2016 PUCT Final Order.
Taxes other than income taxes
Taxes other than income taxes remained relatively unchangedincreased $0.7 million, or 4.4%, for the three months ended March 31, 2018,2019, compared to the three months ended March 31, 2017. 2018, primarily due to increased property valuations and tax rates in Texas.
Taxes other than income taxes increased $4.2$1.0 million, or 6.3%1.5%, for the twelve months ended March 31, 20182019, compared to the twelve months ended March 31, 2017,2018, primarily due to increased property valuations and tax rates in Texas, as a result of MPS Units 3 and 4 being placed in service in 2016 and increased billed revenuespartially offset by decreased revenue related taxes in Texas.
Other income (deductions)
Other income (deductions) decreased $3.7increased $18.9 million, or 36.2%292.7%, for the three months ended March 31, 2018,2019 compared to the three months ended March 31, 2017,2018, primarily due to decreased investmenta $18.5 million increase in net realized and interest income as we recorded net losses of $3.8 million related to equityunrealized gains on securities held at March 31, 2018 in the NDT as a result of adopting ASU 2016-01. See Note A, Principles of Preparation - New Accounting Standards Adopted, for additional information.NDT.
Other income (deductions) decreased $2.3increased $2.9 million, or 5.5%7.6%, for the twelve months ended March 31, 2018,2019 compared to the twelve months ended March 31, 2017,2018, primarily due to (i) decreased investmenta $1.8 million increase in the expected return on benefit plan assets, (ii) a $0.5 million increase in dividends and interest income as we recorded net losses of $3.8 million related to equity securities held at March 31, 2018 in the NDT as a result of adopting ASU 2016-01, partially offset by higher realized gains in the NDT, and (ii) decreased(iii) a $0.4 million increase in allowance for equity funds used during construction ("AEFUDC") resulting from lower average balancesdue to increased amounts of CWIP subject to AEFUDC and a reductionto an increase in the AEFUDC rate. These decreasesincreases were partially offset by increased miscellaneous other income primarily due to an increasea $0.4 million decrease in realized and unrealized net gains on securities held in the expected returnNDT.
Beginning on assets component of net periodic benefit cost.January 1, 2018, the Company adopted ASU 2016-01, Financial Instruments, and began recording unrealized gains and losses on equity securities held in the NDT directly in earnings. Further details are shown below (in thousands):
|
| | | | | | | | | | | | | | | |
| Three Months Ended March 31, | | Twelve Months Ended March 31, |
| 2019 | | 2018 | | 2019 | | 2018 |
Allowance for equity funds used during construction | $ | 1,001 |
| | $ | 920 |
| | $ | 3,534 |
| | $ | 3,130 |
|
Investment and interest income, net: | | | | | | | |
NDT unrealized gains (losses), net | 16,690 |
| | (3,781 | ) | | 1,870 |
| | (3,781 | ) |
NDT realized gains (losses), net | (701 | ) | | 1,272 |
| | 3,661 |
| | 9,707 |
|
NDT dividends and interest income | 1,788 |
| | 1,678 |
| | 7,337 |
| | 6,806 |
|
Expected returns on benefit plans (ASU 2017-07) | 5,913 |
| | 5,928 |
| | 23,496 |
| | 21,746 |
|
Other | 17 |
| | 58 |
| | 565 |
| | 267 |
|
| 23,707 |
| | 5,155 |
| | 36,929 |
| | 34,745 |
|
Miscellaneous non-operating income | 3,048 |
| | 3,136 |
| | 12,735 |
| | 12,292 |
|
Miscellaneous non-operating deductions | (2,357 | ) | | (2,743 | ) | | (11,594 | ) | | (11,494 | ) |
Total other income (deductions) | $ | 25,399 |
| | $ | 6,468 |
| | $ | 41,604 |
| | $ | 38,673 |
|
Interest charges (credits)
Interest charges (credits) remained relatively unchangedincreased by $1.2 million, or 5.8%, for the three months ended March 31, 2018,2019, compared to the three months ended March 31, 2017. 2018, primarily due to interest expense on the $125.0 million aggregate principal amount of 4.22% Senior Notes due 2028 issued in June 2018, and an increase in the interest cost component of net periodic benefit cost of the Company's employee benefit plans. These increases were partially offset by the purchase in lieu of redemption of $63.5 million principal amount of 2009 Series A 7.25% PCBs on February 1, 2019.
Interest charges (credits) increased by 1.7$2.4 million, or 2.1%2.8%, for the twelve months ended March 31, 2018,2019, compared to the twelve months ended March 31, 2017,2018, primarily due to interest expense on the $125.0 million aggregate principal amount of 4.22% Senior Notes due 2028 issued in June 2018. This increase was partially offset by (i) an increasethe purchase in short-term borrowings for working capital purposes andlieu of redemption of $63.5 million principal amount of 2009 Series A 7.25% PCBs on February 1, 2019, (ii) decreasedincreased allowance for borrowed funds used during construction ("ABFUDC")ABFUDC as a result of lowerhigher average balances of CWIP and a reductionan increase in the ABFUDC rate. These increases were partially offset by a decrease due to the retirement at maturity of the $50.0 million Series B 4.47% Senior Notesrate, and (iii) the redemption of $33.3 million principal amount of 2012 Series A 1.875% Pollution Control Bonds during the third quarter ofPCBs in 2017.
Income tax expense (benefit)
Income tax benefitexpense increased $0.8$5.0 million, or 33.4%162.3%, for the three months ended March 31, 2018,2019, compared to the three months ended March 31, 2017,2018, primarily due to an increase in the pre-tax lossincome, lower values of stock incentives vested and an increase in tax benefits related to stock incentive plans, partially offset by a decrease in the federal income tax rate.other permanent differences.
Income tax expense decreased $4.6$18.9 million, or 8.3%37.7%, for the twelve months ended March 31, 2018,2019, compared to the twelve months ended March 31, 2017, primarily2018, due to (i) a decreasethe change in state taxes, (ii)the federal income tax rate and a decrease in pre-tax income partially offset by an increase in state tax reserves and (iii) tax benefits from stock incentive plans.other permanent differences.
New Accounting Standards
See Part I, Item 1, Financial Statements, Note A of Notes to Financial Statements Note A for a discussion of new accounting standards.standards adopted and to be adopted in the future.
Inflation
For the last several years, inflation has been relatively low and, therefore, has had minimal impact on our results of operations and financial condition.
Liquidity and Capital Resources
We continue to maintain a strongAt March 31, 2019, our capital structure, in whichincluding common stock, equity represented 43.9% of our capitalization (common stock equity, long-term debt, current maturities of long-term debt, and short-term borrowings under the RCF) asour RCF, consisted of 43.1% common stock equity and 56.9% debt. As of March 31, 2018. At March 31, 2018,2019, we had a balance of $2.6$8.5 million in cash and cash equivalents.equivalents and $38.4 million in restricted cash to purchase in lieu of redemption all of the 2009 Series B 7.25% PCBs. Based on current projections, we believe that we will have adequate liquidity through the issuance of long-term debt, our current cash balances, cash from operations, and available borrowings under the RCF, and debt or equity issuances in the capital markets to meet all of our anticipated cash requirements forover the next twelve months.
Our principal liquidity requirements in the near-term are expected to consist of capital expenditures to expand and support electric service obligations, expenditures for nuclear fuel inventory, interest payments on our indebtedness, cash dividend payments, operating expenses including fuel costs, maintenance costs cyber-security, security, compliance initiatives and taxes.
Capital Requirements. During the three months ended March 31, 2018,2019, our primary capital requirements were forrelated to the construction and purchase of electric utility plant, payment of common stock dividends and purchases of nuclear fuel. Capital expenditures for new electric utility plant were $52.4 million in the three months ended March 31, 2019, compared to $66.9 million in the three months ended March 31, 2018 compared to $53.9 million in the three months ended March 31, 2017.2018. Capital expenditures for 20182019 are expected to be approximately $236$249 million. Capital requirements for purchases of nuclear fuel were $9.5 million in the three months ended March 31, 2019 compared to $9.3 million in the three months ended March 31, 2018 compared to $10.9 million in the three months ended March 31, 2017.2018.
On March 30, 2018,29, 2019, we paid a quarterly cash dividend of $0.335$0.36 per share, or $13.6$14.7 million, to shareholders of record as of the close of business on March 16, 2018.15, 2019. We expect to continue paying quarterly cash dividends in 2018.2019. We expect our board of directors to conduct its annual review theof our dividend policy in the second quarter of 2018.2019. In addition, while we do not currently anticipate repurchasing shares of our common stock in 2018,2019, we mayare authorized to repurchase shares of our common stock in the future. Under our repurchase program, purchases can be made at open market prices or in private transactions, and repurchased shares are available for issuance under employee benefit and stock incentive plans, or may be retired. No shares of common stock were repurchased during the three months ended March 31, 2018.2019. As of March 31, 2018,2019, a total of 393,816 shares remain eligible for repurchase under the repurchase program.
We expect to continue to maintain a prudent level of liquidity and monitor market conditions for debt and equity securities. Our liquidity needs can fluctuate quickly based on fuel prices and other factors and we are continuing to make investments in new electric plant and other assets in order to reliably serve our customers.
Our cash requirements for federal and state income taxes vary from year to year based on taxable income, which is influenced by the timing of revenues and expenses recognized for income tax purposes. The following summary describes the major impacts of the TCJA on our liquidity. We continue to evaluate the TCJA and have made assumptions based on information currently available.
The TCJA discontinued bonus depreciation for regulated utilities which reduced tax deductions previously available to us for 2017, 2018 and 2019. The decrease in tax deductions will resultresults in the utilization of our Net Operating Lossnet operating loss carryforwards ("NOL carryforwards") and other carryforwards approximately two yearsone year earlier than previously anticipated and is expected to result in higher income tax payments beginning in 2019,2020, after the full utilization of NOL and other carryforwards. However, due to the lower federal corporate income tax rate enacted by the TCJA, our future federal corporate income tax payments will be made at the reduced rate of 21% beginning in 2018.. Due to NOL carryforwards, minimal tax payments are expected for 2018,2019, which are mostly related to state income taxes.
The effect of the TCJA on our rates will beis beneficial to our customers. Following the enactment of the TCJA and the reduction of the federal corporate income tax rate, revenues collected from our customers in 2018 arewere reduced in anby $28.2 million, which negatively impacted our cash flows. A comparable amount that approximates the savings in tax expense. This reduction in revenues is expected to negatively impact our cash flows by approximately $26 million to $31 million during 2018.2019.
We continually evaluate our funding requirements related to our retirement plans, other post-retirement benefit plans and the NDT. During the three months ended March 31, 2018,2019, we contributed $2.9$3.0 million and $0.1$0.2 million to our retirement plans and other post-retirement benefits plan, respectively, and $0.5 million to the NDT. We are in compliance with the funding requirements of the federal government for our benefit plans. In addition, with respect to our nuclear plant decommissioning trust, we are in compliance with the funding requirements of the federal law and the ANPP Participation Agreement. We will continue to review our funding for these plans in order to meet our future obligations.
Capital Resources. Cash provided by operations, $26.4 million for the three months ended March 31, 2019 and $26.2 million for the three months ended March 31, 2018, and $26.1 million for the three months ended March 31, 2017, is a significant source for funding capital requirements. A component of cash flows from operations is the change in net over-collection and under-collection of fuel revenues. The difference between fuel revenues collected and fuel expense incurred is deferred to be either refunded (over-recoveries) or surcharged (under-recoveries) to customers in the future. During the three months ended March 31, 2018,2019, we had fuel over-recoveries of $8.0$12.8 million compared to over-
recoveriesover-recoveries of fuel costs of $8.5$8.0 million during the three months ended March 31, 2017.2018. At March 31, 2018,2019, we had a net fuel over-recoveryover-
recovery balance of $14.2$23.8 million, including an over-recoveryover-recoveries of $13.3$19.3 million in our Texas, and an over-recovery of $0.9$4.4 million in our New Mexico.Mexico and $0.1 million in our FERC jurisdictions. On April 13,October 15, 2018, we filed a request with the PUCT to decrease our Texas fixed fuel factor by approximately 29%6.99% to reflect decreased fuel expenses primarily related to a decrease in the price of natural gas used to generate power. On AprilOctober 25, 2018, the Company's proposedfixed fuel factors werefactor was approved on an interim basis effective for the first billing cycle of the MayNovember 2018 billing month. If no party to the case requests a hearing by May 14, 2018, the Company's fuel factors will become final as provided by the PUCT's rules and no further actionThe revised factor was approved by the PUCT is required.and the docket closed on November 19, 2018. The Texas fixed fuel factor will continue thereafter until changed by the PUCT. On April 29, 2019, the Company filed a petition with the PUCT, which was assigned PUCT Docket No. 49482, requesting authority to implement, beginning on June 1, 2019, a four-month interim fuel refund of $19.4 million in fuel cost over-recoveries, including interest, for the period from April 2016 through March 2019. The Company cannot predict the outcome of this filing at this time.
We maintainreceived approval from the NMPRC on October 7, 2015, to guarantee the issuance of up to $65.0 million of long-term debt by the RGRT to finance future purchases of nuclear fuel and to refinance existing nuclear fuel debt obligations. We received additional approval from the NMPRC on October 4, 2017, to amend and extend the RCF, issue up to $350.0 million in long-term debt and to redeem and refinance the $63.5 million 2009 Series A 7.25% PCBs and the $37.1 million 2009 Series B 7.25% PCBs, which are subject to optional redemption in 2019. The NMPRC approval to issue up to $350.0 million in long-term debt supersedes its prior approval. We received approval from the FERC on October 31, 2017, to issue up to $350.0 million in long-term debt, to guarantee the issuance of up to $65.0 million of long-term debt by the RGRT, and to continue to utilize our existing RCF with the ability to amend and extend the RCF at a future date, and to redeem, refinance and/or replace the 2009 Series A 7.25% PCBs and 2009 Series B 7.25% PCBs with debt of equal face value. The authorization approved by the FERC is effective from November 15, 2017 through November 14, 2019, and supersedes its prior approvals.
Under these authorizations, on June 28, 2018, the Company issued $125.0 million in aggregate principal amount of 4.22% Senior Notes due August 15, 2028, and guaranteed the issuance by the RGRT of $65.0 million in aggregate principal amount of 4.07% Senior Guaranteed Notes due August 15, 2025. The net proceeds from the sale of these senior notes were used to repay outstanding short-term borrowings under the RCF, which included borrowings made for working capital, and general corporate purposes and financingthe purchase of nuclear fuel throughfuel. Also, under these authorizations, on September 13, 2018, the RGRT. TheCompany and RGRT the trust through whichentered into a third amended and restated credit agreement where we finance our portion of nuclear fuel for Palo Verde, is consolidated in our financial statements. Thehave available a $350.0 million RCF haswith a term ending on January 14, 2020. The maximum aggregate unsecured borrowing currently available under the RCF is $350.0 million.September 13, 2023. We may increase the RCF by up to $50.0 million (to a total of $400.0 million) during the term of the RCF, upon the satisfaction of certain conditions more fully set forth in the agreement, including obtaining commitments from lenders or third party financial institutions. We also have the option toIn addition, we may extend the termmaturity date of the RCF by oneup to two times, in each case for an additional yearone-year period upon the satisfaction of certain conditions. Additionally, the Company is preparing for potential transactions related to January 14, 2021,the 2009 Series A 7.25% PCBs and 2009 Series B 7.25% PCBs. On February 1, 2019, the Company purchased in lieu of redemption all of the 2009 Series A 7.25% PCBs utilizing funds borrowed under the RCF. On April 1, 2019, the Company purchased in lieu of redemption all of the 2009 Series B 7.25% PCBs utilizing funds borrowed under the RCF. The Company is currently holding the PCBs and may remarket them or replace them with debt instruments of equivalent value at a future date depending on the Company's financing needs and market conditions, and in accordance with FERC approval in April 2019 in response to the termsCompany's most recent FERC application (see below).
On March 27, 2019, the NMPRC issued a final order approving the Company's request to issue shares of common stock, including the agreement.reissuance of treasury shares, in an amount up to $200.0 million in one or more transactions. On April 18, 2019, the Company received approval from the FERC to issue shares of common stock, including the reissuance of treasury shares, in an amount up to $200.0 million in one or more transactions; to utilize the existing RCF for short-term borrowing not to exceed $400.0 million at any one time; to issue up to $225.0 million in new long-term debt; and to remarket the $63.5 million principal amount of 2009 Series A 7.25% PCBs and the $37.1 million principal amount of 2009 Series B 7.25% PCBs in the form of replacement bonds or senior notes of equivalent value, not to exceed $100.6 million. The authorization approved by the FERC is effective from April 18, 2019 through April 18, 2021, and supersedes its prior approvals.
We maintain the RCF for working capital and general corporate purposes and financing of nuclear fuel through the RGRT. The RGRT, the trust through which we finance our portion of nuclear fuel for Palo Verde, is consolidated in our financial statements. The total amount borrowed for nuclear fuel by the RGRT, excluding debt issuance costs, was $134.1$140.0 million at March 31, 2018,2019, of which $89.1$30.0 million had been borrowed under the RCF, and $45.0$110.0 million was borrowed through the issuance of senior notes. Borrowings by the RGRT for nuclear fuel, excluding debt issuance costs, were $135.2$134.1 million as of March 31, 2017,2018, of which $40.2$89.1 million had been borrowed under the RCF and $95.0$45.0 million was borrowed through the issuance of senior notes. Interest costs on borrowings to finance nuclear fuel are accumulated by the RGRT and charged to us as fuel is consumed and recovered through fuel recovery charges. At March 31, 2018, $144.02019, $173.0 million was outstanding under the RCF for working capital and general corporate purposes, which may include funding capital expenditures.purposes. At March 31, 2017, $94.02018, $144.0 million was outstanding under the RCF for working capital and general corporate purposes. Total aggregate borrowings under the RCF at March 31, 20182019, were $233.1$203.0 million with an additional $116.9$146.9 million available to borrow.
We received approval from the NMPRC on October 7, 2015, to guarantee the issuance of up to $65.0 million of long-term debt by the RGRT to finance future purchases of nuclear fuel and to refinance existing nuclear fuel debt obligations, which remains effective. We received additional approval from the NMPRC on October 4, 2017 to amend and extend the RCF, issue up to $350.0 million in long-term debt and to redeem and refinance the $63.5 million 2009 Series A 7.25% Pollution Control Bonds and the $37.1 million 2009 Series B 7.25% Pollution Control Bonds, which are subject to optional redemption in 2019. The NMPRC approval to issue up to $350.0 million in long-term debt supersedes prior approval. We requested similar approval from the FERC on September 1, 2017 and received approval on October 31, 2017. The FERC approval also includes permission to guarantee the issuance of up to $65.0 million of long-term debt by the RGRT and to continue to utilize our existing RCF with the ability to amend and extend the RCF at a future date. The authorization approved by the FERC is effective from November 15, 2017 through November 14, 2019 and supersedes prior approvals.
Off-Balance Sheet Arrangements
We have no off-balance sheet arrangements that have or are reasonably likely to have a current or future effect on our financial condition, changes in financial condition, revenues or expenses, results of operations, liquidity, capital expenditures or capital resources.
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Item 3. | Quantitative and Qualitative Disclosures About Market Risk |
We are exposed to market risk due to changes in interest rates, equity prices and commodity prices. See the 20172018 Form 10-K, Item 7A, "Quantitative and Qualitative Disclosures About Market Risk," for a complete discussion of the market risks we face and our market risk sensitive assets and liabilities. As of March 31, 20182019, there have been no material changes in the market risks we face or the fair values of assets and liabilities disclosed in Item 7A, "Quantitative and Qualitative Disclosures About Market Risk," in the 20172018 Form 10-K.
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Item 4. | Controls and Procedures |
Evaluation of disclosure controls and procedures. Under the supervision and with the participation of our management, including our chief executive officer and our chief financial officer, we conducted an evaluation pursuant to Rule 13a-15(b) under the Exchange Act of our disclosure controls and procedures as defined in Rule 13a-15(e) under the Exchange Act. Based on that evaluation, our chief executive officer and our chief financial officer concluded that, as of March 31, 20182019, our disclosure controls and procedures are effective.were effective to provide reasonable assurance that information required to be disclosed in the Company's reports filed or submitted under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SEC's rules and forms and such information is accumulated and communicated to management, including our chief executive officer and our chief financial officer, as appropriate to allow timely decisions regarding disclosure.
Changes in internal control over financial reporting. There were no changes in our internal control over financial reporting in connection with the evaluation required by paragraph (d) of the Exchange Act Rules 13a-15 or 15d-15, that occurred during the quarter ended March 31, 20182019, that materially affected, or that were reasonably likely to materially affect, our internal control over financial reporting.
PART II. OTHER INFORMATION
We hereby incorporate by reference the information set forth in Part I of this report under Notes D and IJ of the Notes to Financial Statements.
The following statements highlight risk factors that may affect our financial condition and results of operations. These are not intended to be an exhaustive discussion for all such risks, and the statements below must be read together withThere have been no material changes from the risk factors discussed in the 2017 Form 10-K anddisclosed in our other filings with the SEC.2018 Form 10-K.
Security Breaches, Criminal Activity, Terrorist Attacks and Other Disruptions to Our Infrastructure Could Interfere With Our Operations, Could Expose Us or Our Customers or Employees to a Risk of Loss, and Could Expose Us to Liability, Regulatory Penalties, Reputational Damage and Other Harm to Our Business
We rely upon our infrastructure to manage or support a variety of business processes and activities, including the generation, transmission and distribution of electricity, supply chain functions, and the invoicing and collection of payments from our customers. We also use information technology systems for human resources management, internal accounting purposes and to comply with financial reporting, legal and tax requirements. Our information technology networks and infrastructure may be vulnerable to damage, disruptions or shutdowns due to attacks by hackers, breaches due to employee error or malfeasance, system failures, computer viruses, natural disasters, a physical attack on our facilities, or other catastrophic events. The occurrence of any of these events could impact the reliability of our generation, transmission and distribution systems and energy marketing and trading functions; could expose us or our customers or employees to a risk of loss or misuse of confidential information; and could result in legal claims or proceedings, liability or regulatory penalties against us, damage our reputation or otherwise harm our business. A significant theft, loss or fraudulent use of the personally identifiable information we maintain, or of our data, by cyber-crime or otherwise could adversely impact our reputation and could result in significant costs, fines and litigation. In addition, we may be required to incur significant costs to prevent or respond to damage caused by these disruptions or security breaches in the future.
Additionally, we cannot predict the impact that any future information technology or terrorist attack may have on the energy industry in general. The effects of such attacks against us or others in the energy industry could increase the cost of regulatory compliance, increase the cost of insurance coverage or result in a decline in the U.S. economy which could negatively affect our results of operations and financial condition. Ongoing and future governmental efforts to regulate cybersecurity in the energy industry could lead to increased regulatory compliance costs.
We may incur additional capital and operating costs in connection with the physical security and cyber security of new technologies.
We operate in a highly regulated industry that requires the continued operation and development of sophisticated information technology systems and network infrastructure. The introduction of new technology and the emergence of new industry standards and technological hurdles can create unanticipated difficulties, including failures or inadequacy of equipment or software, difficulties in integrating the various components of the equipment, changes in technology, cybersecurity issues and factors outside our control, which could negatively affect our results of operations and financial condition. As we continue to develop new technology to keep up with the demands of the industry and the needs of our customers, we may be required to expend significant capital and other resources to protect against security breaches or to alleviate problems caused by security breaches.
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Item 2. | Unregistered Sales of Equity Securities and Use of Proceeds |
| |
(c) | Issuer Purchases of Equity Securities. |
|
| | | | | | | | | | | | | |
Period | | Total Number of Shares Purchased (a) | | Average Price Paid per Share (Including Commissions) | | Total Number of Shares Purchased as Part of a Publicly Announced Program | | Maximum Number of Shares that May Yet Be Purchased Under the Plans or Programs |
January 1 to January 31, 2018 | | 20,389 |
| | $ | 52.20 |
| | — |
| | 393,816 |
|
February 1 to February 28, 2018 | | — |
| | — |
| | — |
| | 393,816 |
|
March 1 to March 31, 2018 | | — |
| | — |
| | — |
| | 393,816 |
|
|
| | | | | | | | | | | | | |
Period | | Total Number of Shares Purchased (a) | | Average Price Paid per Share (Including Commissions) | | Total Number of Shares Purchased as Part of a Publicly Announced Program | | Maximum Number of Shares that May Yet Be Purchased Under the Plans or Programs |
January 1 to January 31, 2019 | | 12,425 |
| | $ | 51.24 |
| | — |
| | 393,816 |
|
February 1 to February 28, 2019 | | — |
| | — |
| | — |
| | 393,816 |
|
March 1 to March 31, 2019 | | — |
| | — |
| | — |
| | 393,816 |
|
_____________________
(a) Represents shares of common stock delivered to us as payment of withholding taxes due upon the vesting of
restricted stock held by our employees, not considered part of the Company's repurchase program.
Investors should note that we announce material financial information in SEC filings, press releases and public conference calls. Based on new guidance from the SEC, we may also use the Investor Relations section of our website (www.epelectric.com) to communicate with investors about our company. It is possible that the financial and other information we post there could be deemed to be material information. The information on our website is not part of this document.
|
| | | |
Exhibit Number | | Exhibit |
| | |
#10.01 |
| |
|
| | |
#10.02 |
| |
|
| | |
#10.03 |
| |
|
| | |
#10.04 |
| |
|
| | |
15 |
| | |
| | |
31.01 |
| | |
| | |
32.01 |
| | |
| | |
101.INS |
| | XBRL Instance Document |
| | |
101.SCH |
| | XBRL Taxonomy Extension Schema Linkbase Document |
| | |
101.CAL |
| | XBRL Taxonomy Extension Calculation Linkbase Document |
| | |
101.DEF |
| | XBRL Taxonomy Extension Definition Linkbase Document |
| | |
101.LAB |
| | XBRL Taxonomy Extension Label Linkbase Document |
| | |
101.PRE |
| | XBRL Taxonomy Extension Presentation Linkbase Document |
| | |
| | |
| | |
SIGNATURES
Pursuant to the requirements 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.
|
| |
| |
| EL PASO ELECTRIC COMPANY |
| |
By: | /s/ NATHAN T. HIRSCHI |
| Nathan T. Hirschi |
| Senior Vice President - Chief Financial Officer |
| (Duly Authorized Officer and Principal Financial Officer) |
Dated: May 4, 20188, 2019