We are energy in motion
Investor presentation September 2019
We are energy in motion Investor presentation September 2019 - - PowerPoint PPT Presentation
We are energy in motion Investor presentation September 2019 Forward-looking statements and use of non-GAAP measures This presentation contains forward-looking statements within the meaning of the Private Securities Litigation Reform Act of
Investor presentation September 2019
This presentation contains forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995. Our forward- looking statements in this presentation speak only as of today, and we assume no duty to update them. Forward-looking statements are typically identified by words such as, but not limited to: “estimates,” “expects,” “anticipates,” “intends,” and similar expressions. Although our forward-looking statements are based on reasonable assumptions, various uncertainties and risk factors may cause future performance or results to be different than those anticipated. More complete descriptions and listings of these uncertainties and risk factors can be found in our annual (Form 10-K) and quarterly (Form 10-Q) filings with the Securities and Exchange Commission. This presentation also includes “net economic earnings,” “net economic earnings per share,” “contribution margin,” “adjusted EBITDA,” and “adjusted long-term capitalization,” non-GAAP measures used internally by management when evaluating the Company’s performance and results of
energy-related transactions, the impacts of acquisition, divestiture, and restructuring activities and the largely non-cash impacts of other non- recurring or unusual items such as certain regulatory, legislative, or GAAP standard-setting actions. In fiscal 2018, these items included the revaluation of deferred tax assets and liabilities due to the Tax Cuts and Jobs Act, and the write-off of certain long-standing assets as a result of disallowances in our Missouri rate proceedings. The fair value and timing adjustments, which primarily impact the Gas Marketing segment, include net unrealized gains and losses on energy-related derivatives resulting from the current changes in fair value of financial and physical transactions prior to their completion and settlement, lower of cost or market inventory adjustments, and realized gains and losses on economic hedges prior to the sale of the physical commodity. Management believes that excluding these items provides a useful representation of the economic impact of actual settled transactions and overall results of ongoing operations by facilitating comparisons of year-over-year results. Contribution margin is defined as
as operating income or net income. Adjusted EBITDA is earnings before interest, income taxes, depreciation and amortization, plus largely non-cash write-offs related to Missouri rate cases. Reconciliations of net income to net economic earnings and of contribution margin to operating income are contained in our SEC filings and in the Appendix to this presentation. Reconciliations of adjusted EBITDA to net income are also contained in the Appendix. Note: Years shown in this presentation are fiscal years ended September 30, unless otherwise indicated.
Investor Relations contact:
Scott W. Dudley Jr. Managing Director, Investor Relations 314-342-0878 Scott.Dudley@SpireEnergy.com
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Our mission
Answer every challenge, advance every community and enrich every life through the strength of our energy.
Our strategic priorities
technology
3 3 Spire | Investor presentation – September 2019
natural gas company serving 1.7 million homes and businesses across Alabama, Mississippi and Missouri
– Spire Marketing – Spire STL Pipeline – Spire Storage
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Delivering growth
Financial strength
Superior investor returns
1For FY17 through first half FY19.
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8,167 8,141 9,498 10,937 11,159 11,397 4,000 8,000 12,000
2014 2015 2016 2017 2018 2019
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business and economic development
– YTD FY19 new business investment up $10M (~19%) from a year ago – Growing new premise activations – Expanding into new service areas
– Customer growth – Balanced and constructive regulatory outcomes
O&M expenses per customer2
112-months ending June 2019. 2Operation and maintenance (O&M) expenses and customers for Spire Missouri,
Spire Alabama and Spire Gulf for all years. Expenses in orange for 2018 and 2019 exclude Missouri rate case items.
New premise activations
1
$270 $252 $244 $241 $255 $263 $250 $230 $240 $250 $260 $270 2014 2015 2016 2017 2018 2019 $253
1
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– Pipeline upgrades over next 15-18 years – Drives 6% long-term rate base growth – Utility spend ~80% recovered with minimal lag or reflected in earnings
– Up $40M to reflect higher utility spend – $25M incremental Storage spend – $25M for Pipeline pushed to FY20
(thru 2023) from $2.6B (thru 2022)
– Higher investment across all businesses – Diversified across our utilities
(Millions)
393 430 63 100 43 250 $0 $250 $500 $750 FY18 actual FY19 forecast
$780 $499
Capital expenditures
430 395 400 405 410 100 90 90 100 100 250 75 30 10 10
2019 2020 2021 2022 2023
Utility, with minimal lag and new business
5-year forecast: $2.9B
Pipelines and storage Other utility
$780 $560 $520 $515 $520
(Millions)
information technology modernization
databases for
– New business development – Targeting growth opportunities – Improving workload planning
connect with Spire via My Account
inspect/repair distribution pipelines
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174.0 141.9 99.7 75.6 63.0 2015 2016 2017 2018 2019
Strengthening system integrity
Leaks per 1,000 system miles
Investment in infrastructure upgrades, technology and our people are driving improved safety, system integrity and service.
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3.66 3.65 3.22 2.63 2.00 2015 2016 2017 2018 2019
Reducing employee injuries
OSHA DART1 rate 4.84 4.76 4.78 4.24 3.84 2015 2016 2017 2018 2019
Improving pipeline safety
Damage rate per 1,000 locates 32.4 28.9 28.4 26.8 25.2 2015 2016 2017 2018 2019
Enhancing service and safety
Average leak response time (minutes)
1Days away, restricted time. 2Twelve-months ending June 2019.
2 2 2 2
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Renewal
Safety Act
Missouri
– Current ISRS annualized revenues of $8M effective October 18 – Additional ISRS revenues of $13.2M authorized on May 3 – On July 15 requested $11M and $3.4M for disputed plastic materials Alabama
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Spire Marketing’s operational reach
in the central and southern U.S.
customers (by net dollar exposure)
providing physical delivery of gas
– Delivering gas on 35+ pipelines – Optimizing our portfolio of commodity, transportation and storage contracts – Operating with a strong team in Houston – Expanding geographically and increasing customer base and volumes
net economic earnings of $17.8M
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supply to the St. Louis region
– Enhances supply diversity, reliability, and resiliency – Capacity of 400 MMcf/day with Spire Missouri contracted for 350 MMcf/day
and Missouri Rivers
– Updated construction costs to $262M – Spire MO negotiated rate expected to increase to $0.25 per dekatherm (up $0.02) – Commercial in-service targeted by early December (start of winter heating season)
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development and capital deployment
– Completing several targeted capital projects to ensure reliable operations during upcoming winter – Approximately $25M of incremental capex in the remainder of FY19 – Total investment to date1 of $139M, including $56M in base gas
customers to better understand their needs and assess market opportunities
EBITDA contribution in 2H FY20
1Through June 2019.
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– Gas utility spend $405M, up 35% – $123M for Spire STL Pipeline – $81M for Spire Storage ($56M for base gas)
– Reflecting MO rate design change, other positive regulatory adjustments and modest customer growth – Higher O&M costs as reset in MO rate cases1
– Higher volumes from geographic expansion – Good market conditions, although less
Net economic earnings (NEE)2
Nine months ended June 30, 2018 2019 Gas Utility $208.1 $220.7 Gas Marketing 18.2 17.8 Other (16.0) (19.7) Total $210.3 $218.8 NEE per share $4.30 $4.27 Average shares 48.8 50.8
Capital expenditures
270 341 29 64 35 204 $0 $100 $200 $300 $400 $500 $600 $700 9 mos. FY18 9 mos. FY19 $609
Utility, with minimal lag and new business Pipelines and storage Other utility
$334
(Millions) (Millions)
1After removing non-recurring MO rate case adjustments and reclass of benefit costs. 2See Net economic earnings (non-GAAP) reconciliation in Appendix.
$467 $478 $300 $350 $400 $450 $500 9 mos. FY18 9 mos. FY19
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and commercial paper program
capitalization2 of 53.1% equity
stock
– Net proceeds of $242M – Expected to fund $125M Spire debt maturing Aug. 15
program
– Issued ~60k shares in June quarter – $4.9M in net proceeds
1Adjusted EBITDA is earnings before interest, income taxes, depreciation and amortization,
plus largely non-cash write-offs related to Missouri rate cases.
2See Adjusted long-term capitalization [non-GAAP] reconciliation in the Appendix.
Adjusted EBITDA1
(Millions)
53.1% 46.9%
Equity Debt
Adjusted long-term capitalization2
(at June 30, 2019)
1Quarterly dividend of $0.5925 per share effective January 3, 2019, annualized. 2Based on $2.37 per share dividend and SR average closing stock price of $83.60 for period April 1-August 27. 3Prorated amount reflecting May 21 issuance of preferred shares.
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‒ 5.3% annualized growth in 2019 ‒ 16 consecutive years of increases; 74 years of continuous payment ‒ Conservative payout ratio and target range of 55% - 65%
Dividend yield 2.8%2
Dividend payout ratio Dividend per share
Annualized common stock dividend per share
Dividend payout ratio
1
Capital expenditures
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to $2.9B reflecting FY19 update
– Higher utility spend well-diversified across utilities – Driving long-term 6% rate base growth – ~80% of utility spend recovered with minimum lag or reflected in earnings (new business)
– Operating company long-term debt – Common and preferred equity Long-term financing forecast
275-300 50-100 100-150 100-150 150-200 100-200 100-200 100-200
2019 2020 2021 2022
Common and preferred equity
($ Millions)
Operating company long-term debt
430 395 400 405 410 100 90 90 100 100 250 75 30 10 10
2019 2020 2021 2022 2023
Utility, with minimal lag and new business
5-year forecast: $2.9B
Pipelines and storage Other utility
$780 $560 $520 $515 $520
(Millions)
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Our communities Our people Our leadership Our environment
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In our CSR Report, you’ll see how we’ve used our energy for good, influencing each
year of our CSR efforts. We’re committed to driving positive and significant change in the communities we serve. Learn more at CSRReport2018.SpireEnergy.com
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Suzanne Sitherwood
President and Chief Executive Officer
B
Steve Lindsey
Executive Vice President, Chief Executive Officer, Gas Utilities and Distribution Operations
Steve Rasche
Executive Vice President, Chief Financial Officer
Mark Darrell
Senior Vice President, General Counsel and Chief Compliance Officer
Mike Geiselhart
Senior Vice President, Strategic Planning and Corporate Development
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E
Scott Carter
President, Spire Missouri
Joe Hampton
President, Spire Alabama and Mississippi
Scott Jaskowiak
President, Spire STL Pipeline and Spire Storage
Pat Strange
President, Spire Marketing
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Alabama Gulf Mississippi Missouri Primary office Birmingham Mobile Hattiesburg
Employees1 861 123 33 2,321 Customers1 420,600 83,900 18,500 1,169,900 Pipeline miles ~23,000 ~4,300 ~1,200 ~30,000 Rate base (Millions) $5092 $922 $243 $2,2174 Return on equity 10.40%5 10.70% 10.36% 9.80% Equity capitalization 55.5%5 55.5% 50.0% 54.2%
1Employees and customers as of September 30, 2018. 2The Rate Stabilization and Equalization (RSE) mechanism uses avg. common equity for year ended 9/30/18 for Alabama and Gulf utilities, rather than rate base, for ratemaking purposes. 3Mississippi net assets less deferred taxes for Rate Stabilization Adjustment (RSA) purposes effective 3/1/19. 4Estimated FY18 year-end rate base at Spire Missouri reflecting growth since amended MoPSC order dated March 7, 2018, establishing rate base in MO East of $1,221M and MO West
5Terms of renewed RSE, effective 10/1/18 through 9/30/22.
Estimated replacement miles remaining
As of 12/31/18
Steel1 Cast iron Vintage plastic Total replacement miles Total system miles Missouri 1,740 720 2,460 30,000 Alabama 540 570 280 1,390 27,300 Total 2,280 1,290 280 3,850 57,300 % of total 59% 34% 7% 100%
1Includes hard copper services inside bare steel, and threaded and coupled steel in Missouri.
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191 247 243 294 356 382 100 200 300 400 2013 2014 2015 2016 2017 2018
Miles of pipeline replaced
and Equalization (RSE) metrics
structures across Alabama
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Current Prior Current Prior Return on Equity (ROE) Range 10.15% - 10.65% 10.50% - 10.95% 10.45% - 10.95% 10.45% - 10.95% Adjusting point 10.40% 10.80% 10.70% 10.80% Equity capitalization 55.50% 56.50% 55.50% 56.00% Infrastructure incentive AIM: +/-10 bps ROE CIMFR: 75% eq ratio > baseline thru 2019 Cost Control Measure (CCM) Metric O&M / customer Total O&M O&M / customer Total O&M Base year 2018 2007 2017 2014 +/- band 1.50% 1.75% 1.50% 1.75% Spire Alabama Spire Gulf
– Cost-of-service, rate base and capital structure determined using historical test year – Both utilities have weather mitigated rate designs and mechanisms to address purchased gas costs, pensions and energy efficiency investments
– Enables recovery of (and on) infrastructure investment with minimal regulatory lag – In effect since 2003
(also appoints the Chairman)
– William P. Kenney (R) – Jan. 2019 – Maida J. Coleman (D) – Aug. 2021 – Daniel Y. Hall (D) – Sept. 2019 – Ryan A. Silvey (R), Chair – Jan. 2024 – Scott T. Rupp (R) – Apr. 2020
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1RRA is Regulatory Research Associates.
economic and workforce development
since rate cases concluded April 2018
– $8.0M effective October 18, 2018 – $13.2M effective May 3, 2019 – Non-ISRS eligible amounts recoverable in next rate case – July 15 filed for $11.0M additional ISRS for new investment, plus $3.4M for disputed costs of plastic materials
legislative strategy to achieve more progressive and timely rate review
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– RSE parameters evaluated every four years – Annual rate-setting process with forward-year budget and quarterly reviews – Rates set based on retained shareholders’ equity
– Includes current recovery on planned capital spend
– Incentive to manage O&M costs relative to target benchmark – Sharing with customers outside of band
– Gas costs, weather normalization and certain other non-recurring costs – Opportunity for enhanced return for pipeline replacement (Spire Alabama’s AIM) and certain infrastructure investments (Spire Gulf’s CIMFR)
– Twinkle Andress Cavanaugh, President (R) – 2020 – Chris “Chip” Beeker (R) – 2022 – Jeremy H. Oden (R) – 2022 Spire Alabama
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– RSA provides for annual rate performance reviews rather than periodic rate cases
‒ 50% of the amount over the allowed return going to a rate reduction, or ‒ 75% of the deficiency toward a rate increase
– Fixed rate structure and weather normalization mechanism effective with 2018-19 heating season
– Program through Oct. 2021 for up to $5M in investment – Qualified industrial development projects earn a 10-year supplemental return at 12.0% ROE
– Brandon Presley, Chair (D) – 2020 (Northern District) – Cecil Brown, Vice Chair (D) – 2020 (Central District) – Sam Britton (R) – 2020 (Southern District)
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– Base is run-rate FY18 NEEPS – Removes 17¢ of Spire Marketing NEEPS driven by market conditions not expected to recur
Net economic earnings per share
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1Run-rate adjustment is an estimate of Spire Marketing results of $0.17 in 2018 not anticipated to recur.
1
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– Reflect ~$70 million in cost savings from our transformative growth – Authorized 9.8% ROE, utility LT capital structure and $2.0B rate base – Aligns MO rate design: higher volumetric component and full residential weather normalization
Impact (Millions) Customer rates Earnings Base rate increase $ 66.2 $ 66.2 Rate reduction for tax benefits (33.0) Current ISRS reset to zero (49.0) (49.0)
(23.1) Total $ (15.8) $ (5.9)
Q2 FY18 write-offs from the Missouri rate cases
(Millions, except per share amounts)
Gross Net of tax Per share
Disputed pension contributions (prior to 1997) $ (28.8) $ (17.7) NBV of property sold in 2014 (1.8) (1.1) GAAP write-offs added back to NEE $ (30.6) $ (18.8) $ (0.39) Earnings or equity-based incentives (Jan 2016 on) $ (6.9) $ (4.2) Portion of rate case expenses (0.9) (0.6) GAAP write-offs reflected in NEE $ (7.8) $ (4.8) $ (0.10) Total impact $ (38.4) $ (23.6)
greater AFUDC income in the current year driving a larger tax benefit
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1Accumulated Deferred Income Taxes.
(Millions)
2019 2018 2019 2018 GAAP expense (benefit) before ADIT1 amortization (0.8) $ 5.7 $ 51.5 $ (8.5) $ Amortization of excess ADIT (2.1) — (6.3) — GAAP income tax expense (benefit) (2.9) $ 5.7 $ 45.2 $ (8.5) $ — — — 54.0 Other tax adjustments — 1.6 — 3.5 Run rate income tax expense (2.9) $ 7.3 $ 45.2 $ 49.0 $ Effective tax rate NM 23.1% 17.1% 21.1% Benefit from revaluation of net deferred tax liabilities (TCJA) Quarter ended June 30, Nine months ended June 30,
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1Income tax effect is calculated by applying federal, state, and local income tax rates applicable to ordinary income to the amounts of the pre-tax reconciling items and then
adding any estimated effects of enacted state or local income tax laws for periods before the related effective date.
2Net economic earnings per share is calculated by replacing consolidated net income with consolidated net economic earnings in the GAAP diluted EPS calculation, which
includes reductions for cumulative preferred dividends and participating shares.
(Millions, except per share amounts)
Gas Utility Gas Marketing Other Total Per diluted common share2 Three months ended June 30, 2019 Net Income (Loss) [GAAP] 7.6 $ (4.7) $ (5.9) $ (3.0) $ (0.09) $ Adjustments, pre-tax: Unrealized loss on energy-related derivatives . 8.0 . 8.0 0.16 Lower of cost or market inventory adjustments . 2.7 . 2.7 0.05 Income tax effect of adjustments1 . (2.7) . (2.7) (0.05) Net Economic Earnings (Loss) [Non-GAAP] 7.6 $ 3.3 $ (5.9) $ 5.0 $ 0.07 $ Three months ended June 30, 2018 Net Income (Loss) [GAAP] 18.5 $ 16.2 $ (8.8) $ 25.9 $ 0.52 $ Adjustments, pre-tax: Unrealized gain on energy-related derivatives . (16.0) . (16.0) (0.32) Acquisition, divestiture and restructuring activities . . 3.3 3.3 0.07 Income tax effect of adjustments1 (1.6) 4.2 (0.6) 2.0 0.04 Net Economic Earnings (Loss) [Non-GAAP] 16.9 $ 4.4 $ (6.1) $ 15.2 $ 0.31 $
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1Income tax effect is calculated by applying federal, state, and local income tax rates applicable to ordinary income to the amounts of the pre-tax reconciling items and then
adding any estimated effects of enacted state or local income tax laws for periods before the related effective date.
2Net economic earnings per share is calculated by replacing consolidated net income with consolidated net economic earnings in the GAAP diluted EPS calculation, which
includes a reduction for cumulative preferred stock dividends and participating shares.
(Millions, except per share amounts)
Gas Utility Gas Marketing Other Total Per diluted common share2 Nine months ended June 30, 2019 Net Income (Loss) [GAAP] 220.7 $ 18.2 $ (20.0) $ 218.9 $ 4.27 $ Adjustments, pre-tax: Unrealized gain on energy-related derivatives . (3.3) . (3.3) (0.06) Lower of cost or market inventory adjustments . 2.7 . 2.7 0.05 Acqusition, divestiture and restructuring activities . . 0.4 0.4 0.01 Income tax effect of adjustments1 . 0.2 (0.1) 0.1 . Net Economic Earnings (Loss) [Non-GAAP] 220.7 $ 17.8 $ (19.7) $ 218.8 $ 4.27 $ Nine months ended June 30, 2018 Net Income [GAAP] 166.2 $ 20.0 $ 53.9 $ 240.1 $ 4.91 $ Adjustments, pre-tax: Missouri regulatory adjustments 30.6 . . 30.6 0.63 Unrealized gain on energy-related derivatives . (3.4) . (3.4) (0.07) Realized gain on economic hedges prior to the sale of the physical commodity . (0.3) . (0.3) (0.01) Acquisition, divestiture and restructuring activities 0.2 . 6.8 7.0 0.14 Income tax effect of adjustments1 (9.2) 1.0 (1.5) (9.7) (0.20) Effect of the Tax Cuts and Jobs Act 20.3 0.9 (75.2) (54.0) (1.10) Net Economic Earnings (Loss) [Non-GAAP] 208.1 $ 18.2 $ (16.0) $ 210.3 $ 4.30 $
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(Millions)
Gas Utility Gas Marketing Other Eliminations Consolidated
Three months ended June 30, 2019 Operating Income (Loss) [GAAP]
25.3 $ (7.0) $ (5.0) $ $ 13.3 $
Operation and maintenance
113.4 3.2 8.4 (2.6) 122.4
Depreciation and amortization
45.1 0.7 45.8
Taxes, other than income taxes
29.7 0.1 0.4 30.2
Less: Gross receipts tax expense
(18.2) (18.2)
Contribution Margin [non-GAAP]
195.3 (3.7) 4.5 (2.6) 193.5
Natural and propane gas costs
88.1 22.0 0.1 (0.6) 109.6
Gross receipts tax expense
18.2 18.2
Operating Revenues
301.6 $ 18.3 $ 4.6 $ (3.2) $ 321.3 $
Three months ended June 30, 2018 Operating Income (Loss) [GAAP]
41.5 $ 21.6 $ (4.2) $ $ 58.9 $
Operation and maintenance
101.4 2.0 7.7 (2.6) 108.5
Depreciation and amortization
40.5 0.5 41.0
Taxes, other than income taxes
33.5 0.1 0.3 33.9
Less: Gross receipts tax expense
(20.4) (20.4)
Contribution Margin [non-GAAP]
196.5 23.7 4.3 (2.6) 221.9
Natural and propane gas costs
117.9 (9.3) (0.3) 108.3
Gross receipts tax expense
20.4 20.4
Operating Revenues
334.8 $ 14.4 $ 4.3 $ (2.9) $ 350.6 $
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(Millions)
Gas Utility Gas Marketing Other Eliminations Consolidated
Nine months ended June 30, 2019 Operating Income (Loss) [GAAP]
317.2 $ 22.3 $ (11.6) $ $ 327.9 $
Operation and maintenance
330.3 8.5 22.3 (8.2) 352.9
Depreciation and amortization
133.2 1.7 134.9
Taxes, other than income taxes
126.3 0.6 1.2 128.1
Less: Gross receipts tax expense
(87.5) (0.1) (87.6)
Contribution Margin [non-GAAP]
819.5 31.3 13.6 (8.2) 856.2
Natural and propane gas costs
746.6 38.2 0.7 (2.5) 783.0
Gross receipts tax expense
87.5 0.1 87.6
Operating Revenues
1,653.6 $ 69.6 $ 14.3 $ (10.7) $ 1,726.8 $
Nine months ended June 30, 2018 Operating Income (Loss) [GAAP]
293.2 $ 27.7 $ (7.9) $ $ 313.0 $
Operation and maintenance
339.8 5.1 17.8 (7.5) 355.2
Depreciation and amortization
121.9 1.0 122.9
Taxes, other than income taxes
128.2 0.2 0.4 128.8
Less: Gross receipts tax expense
(87.0) (0.1) (87.1)
Contribution Margin [non-GAAP]
796.1 32.9 11.3 (7.5) 832.8
Natural and propane gas costs
784.5 22.3 0.2 (1.1) 805.9
Gross receipts tax expense
87.0 0.1 87.1
Operating Revenues
1,667.6 $ 55.3 $ 11.5 $ (8.6) $ 1,725.8 $
1Includes redeemable non-controlling interest of $6.5M.
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(Millions)
2019 2018 Net Income [GAAP] 218.9 $ 240.1 $ Add back: Interest charges 79.1 74.0 Regulatory asset write-offs !! 38.4 Income tax expense (benefit) 45.2 (8.5) Depreciation & amortization 134.9 122.9 Adjusted EBITDA [non-GAAP] 478.1 $ 466.9 $ Nine months ended June 30,
(Millions)
Equity Debt Total Equity1 Debt Total Capitalization 2,612.6 $ 2,042.3 $ 4,654.9 $ 2,314.2 $ 2,024.5 $ 4,338.7 $ Current portion of long-term debt — 165.0 165.0 — 155.5 155.5 Long-term Capitalization [GAAP] 2,612.6 $ 2,207.3 $ 4,819.9 $ 2,314.2 $ 2,180.0 $ 4,494.2 $ % of long-term capitalization 54.2% 45.8% 100.0% 51.5% 48.5% 100.0% Reclassify 50% of preferred stock (121.0) 121.0 — — — — Expected repayment August 15, 2019 — (125.0) (125.0) — — — Adjusted Long-term Capitalization [non-GAAP] 2,491.6 $ 2,203.3 $ 4,694.9 $ 2,314.2 $ 2,180.0 $ 4,494.2 $ % of adjusted long-term capitalization 53.1% 46.9% 100.0% June 30, 2019 June 30, 2018