Investor Highlights // AUGUST 2019 Enable Midstream Overview Large - - PDF document
Investor Highlights // AUGUST 2019 Enable Midstream Overview Large - - PDF document
Investor Highlights // AUGUST 2019 Enable Midstream Overview Large scale, fully integrated midstream platform Critical link between growing production and downstream markets Long-term relationships with large-cap producers, LDCs and
- Large scale, fully integrated
midstream platform
- Critical link between growing
production and downstream markets
- Long-term relationships with large-cap
producers, LDCs and electric utilities
- Signifjcant fee-based and
demand-fee margin
- Substantial distribution coverage
- Investment-grade credit metrics
- Proven track record
- Compelling value opportunity
13,900 Miles
Gathering Pipelines
10,100 Miles
Interstate/Intrastate Pipelines
84.5 Bcf
Natural Gas Storage Capacity
2.6 Bcf/d
Processing Capacity
44 Active Rigs
On Enable’s Footprint1
Enable Midstream Overview
Note: Map as of July 30, 2019; Stats as of Dec. 31, 2018; Pipeline miles are approximate and interstate/intrastate pipeline miles include ~7,800 miles of interstate pipeline (including SESH) and ~2,300 miles of intrastate pipeline
1Rigs drilling wells expected to be connected to Enable’s gathering systems; per DrillingInfo as of Aug. 5, 2019
2 | Investor Highlights 1
Fully Integrated Midstream Platform Across Leading Basins Generates Unique Growth Opportunities
T&S Segment 2019 Highlights
- Contracted or extended over
600,000 Dth/d of transportation capacity during the second quarter
- f 2019
- Enable and CenterPoint Energy
Resources Corp. (CERC) previously signed precedent agreements outlining terms and conditions for extending EGT pipeline contracts that currently expire on March 31, 2021; CERC has received the required regulatory approvals, and EGT is working with CERC to fjnalize the defjnitive agreements
- The MRT rate case hearing date that
was originally set for November 2019 has been rescheduled to early 2020; MRT remains focused on ensuring that the pipeline’s rates appropriately refmect historical investments and current costs
- T&S segment provides signifjcant,
fee-based margin and is well- positioned to support natural gas demand growth in the Mid-continent, Gulf Coast and Southeast regions
G&P Segment 2019 Highlights
- Rig activity remains strong around
Enable’s gathering footprint with 44 rigs2 currently drilling wells expected to be connected to Enable’s gathering systems
- DUC count is building in the Williston
Basin as a result of third-party natural gas infrastructure constraints that are expected to be alleviated as new infrastructure come online later this year
- Crude oil and condensate volumes
gathered reached 119 MBbl/d in the second quarter 2019 driven by Enable’s recent crude oil and condensate gathering system acquisition in the Anadarko Basin and growth in the Williston Basin
- Producer activity in the Ark-La-Tex
Basin continues to drive gathered volumes, and the scale of the Ark-La- Tex Basin assets has allowed Enable to benefjt from opportunistic short- term offmoad agreements
1As of Dec. 31, 2018; excludes SESH which is reported as an equity method investment 2Rigs per DrillingInfo as of Aug. 5, 2019
Active Rigs on Enable’s Footprint2 T&S Gross Margin1
STACK SCOOP Granite Wash Ark-La-Tx Williston
EGT 54% MRT 13% EOIT 21%
88% Derived from Firm Contracts
4 | Investor Highlights 3
Market-Leading Anadarko Basin Position
Gulf Run Pipeline Extends Enable’s Midstream Platform
Significant natural gas and crude oil midstream infrastructure positions Enable to capitalize on changing rig activity The Gulf Run Pipeline, backed by cornerstone shipper Golden Pass LNG, will provide access to some of the most prolific natural gas producing regions in the U.S.
- #1 in Processing Capacity in the SCOOP and STACK1
- 51% of all active rigs in the SCOOP and STACK are drilling wells expected to be connected to Enable’s
gathering systems2
- Enable expects to gather crude and condensate from 73% of the active rigs on Enable’s Andarko footprint2
- Operators have reduced the number of days it takes to drill a well in the SCOOP and STACK by an average
- f 11% between fjrst and second quarter 20193
- As part of the FERC pre-fjling process, Enable hosted public open houses for stakeholders in May 2019
- In June 2019, the commission conducted public scoping meetings for the project
- Enable remains in active discussions with customers for additional capacity commitments and anticipates
fjnalizing the scope of the project and fjling a formal certifjcate application in early 2020
- The project is expected to be completed by late 2022 and is subject to FERC approval
1Processing capacity per Bentek as of Aug. 7, 2019 2Rigs per DrillingInfo as of Aug. 1, 2019 3Source: DrillingInfo
Note: SCOOP counties are designated as Caddo, Carter, Garvin, Grady, McClain and Stephens and STACK counties are designated as Blaine, Canadian, Custer, Dewey, Kingfisher, Major and Woodward counties of Oklahoma Note: Maps as of Aug. 1, 2019
2019 2018 2021 2022
Project Announcement Open Season Golden Pass FID Survey Work FERC Pre- Filing Public Open Houses FERC Scoping Meetings FERC 7(c) Filing FERC Approval Begin Construction Project Completed Right of Way Acquisition 6 | Investor Highlights 5
Responsible Operator, Community Partner
Environmental Stewardship Community Focused
Signatory to INGAA’s
Methane Emissions Commitment
to minimize methane emissions Member of EPA’s voluntary
Natural Gas STAR
program since 2003 Focus on
Species Conservation
including Lesser Prairie Chicken and American Burying Beetle Enable received the
Corporate Conservation Partnership Award
by the Arkansas Game and Fish Commission Enable employees served
20,925 Hours
in local communities in 2018 Enable honored
6 Emergency Responders
through the Enable Safety Partner Program in 2018 Partnered with the OKC Thunder to build
4 Basketball Courts
in Oklahoma communities 311 employees volunteered to provide
198,000 Meals
through food banks across Enable’s footprint
National Wild Turkey Federation presented Enable with the prestigious Energy for Wildlife National Achievement Award Enable and its employees donated $560,000 to United Way agencies across the company’s footprint in 2018
Key Enable Highlights
- Critical link between growing production and downstream markets
- Diversifjed asset base with proven value, scale and upside
- Favorable contract structures with signifjcant fee-based and demand-fee margin
- Financial fmexibility with signifjcant liquidity and investment-grade credit metrics
- Proven track record of consistent operational and fjnancial growth
Strong Business Performance ~96% Fee-Based or Hedged Margin4
Commodity-Based Hedged Volume Dependant Demand Commodity-Based Unhedged
1Results from 2016 through 2018 2Calculation is based off of 2019E midpoint 32019E is based on the 2019 Outlook provided on Nov. 7, 2018, reaffirmed Aug. 6, 2019 4Gross margin profile represents hedges as of July 10, 2019 and Enable’s current 2019 forecast and price assumptions
2016 2015 $873 $801 $924 $1,074 Adjusted EBITDA ($ in mm) 2017 2018 2019E3
$1,180
$1,180 $1,090 +9% CAGR2
Enable’s Results Check All of the Boxes1
- Investment-Grade Credit Metrics
- Strong Distribution Coverage
- Signifjcant Scale
- Improved Returns on Invested Capital
Enable: Built for the Long-term
8 | Investor Highlights 7
Non-GAAP Reconciliations Forward-looking Statements
Reconciliation of Adjusted EBITDA and DCF to net income attributable to limited partners and calculation of Distribution coverage ratio: Three Months Ended June 30, Year Ended December 31, 2019 2018 2018 2017 2016 2015 (In millions, except Distribution coverage ratio) Net income attributable to limited partners $ 124 $ 95 $ 521 $ 436 $ 312 $ (752) Depreciation and amortization expense 110 96 398 366 338 318 Interest expense, net of interest income 47 36 152 120 99 90 Income tax expense — — (1) (1) 1 — Distributions received from equity method affjliate in excess of equity earnings — 1 7 5 15 13 Non-cash equity-based compensation 5 3 16 15 13 9 Change in fair value of derivatives1 (11) 10 (26) (28) 60 8 Other non-cash losses2 6 4 7 11 26 1 Impairments — — — — 9
1,134
Non-controlling Interest Share of Adjusted EBITDA — — — — —
(20)
Adjusted EBITDA $ 281 $ 245 $ 1,074 $ 924 $ 873 $ 801 Series A Preferred Unit distributions3 (9) (9) (36) (36) (31) — Distributions for phantom and performance units4 — (1) (5) (2) — — Adjusted interest expense (49) (38) (159) (123) (103)
(102)
Maintenance capital expenditures (26) (26) (114) (101) (101) (160) Current income taxes — — — (2) 1
(1)
DCF $ 197 $ 171 $ 760 $ 660 $ 639 $ 538 Distributions related to common and subordinated unitholders5 $ 144 $ 138 $ 552 $ 551 $ 539 $ 534 Distribution coverage ratio 1.37 1.24 1.38 1.20 1.18
1.01
Reconciliation of Adjusted EBITDA to net cash provided by operating activities: Three Months Ended June 30, Year Ended December 31, 2019 2018 2018 2017 2016 2015 (In millions) Net cash provided by operating activities $ 212 $ 239 $ 924 $ 834 $ 721 $ 726 Interest expense, net of interest income 47 36 152 120 99 90 Net income attributable to noncontrolling interest — — (2) (1) (1) 19 Current income taxes 1 — — 2 (1) 1 Other non-cash items5 4 5 7 4 12 (2) Proceeds from insurance — 1 2 2 — — Changes in operating working capital which (provided) used cash: Accounts receivable (28) 35 11 28 (4) (15) Accounts payable 57 (41) (6) (54) 40 29 Other, including changes in noncurrent assets and liabilities (1) (41) 5 12 (68) (43) Return of investment in equity method affjliate — 1 7 5 15 8 Change in fair value of derivatives (11) 10 (26) (28) 60 8 Non-controlling Interest Share of Adjusted EBITDA — — — — — (20) Adjusted EBITDA $ 281 $ 245 $ 1,074 $ 924 $ 873 $ 801
1Change in fair value of derivatives includes changes in the fair value of derivatives that are not designated as hedging instruments 2Other non-cash losses includes loss on sale of assets and write-downs of materials and supplies 3This amount represents the quarterly cash distributions on the Series A Preferred Units declared for the periods presented. The year-ended 2016
amount includes the prorated quarterly cash distribution on the Series A Preferred Units declared on April 26, 2016. In accordance with the Partnership Agreement, the Series A Preferred Unit distributions are deemed to have been paid out of available cash with respect to the quarter immediately preceding the quarter in which the distribution is made
4Distributions for phantom and performance units represent distribution equivalent rights paid in cash. Phantom unit distribution equivalent rights
are paid during the vesting period and performance unit distribution equivalent rights are paid at vesting
5Represents cash distributions declared for common units outstanding as of each respective period. All outstanding subordinated units converted
into common units on a one-for-one basis on Aug. 30, 2017
Some of the information in this presentation may contain forward-looking statements. Forward-looking statements give our current expectations, contain projections of results of operations or of fjnancial condition, or forecasts of future events. Words such as “could,” “will,” “should,” “may,” “assume,” “forecast,” “position,” “predict,” “strategy,” “expect,” “intend,” “plan,” “estimate,” “anticipate,” “believe,” “project,” “budget,” “potential,” or “continue,” and similar expressions are used to identify forward-looking
- statements. Without limiting the generality of the foregoing, forward-looking statements contained in this presentation include
- ur expectations of plans, strategies, objectives, growth and operational performance, including revenue projections, capital
expenditures and tax position. Forward-looking statements can be affected by assumptions used or by known or unknown risks or
- uncertainties. Consequently, no forward-looking statements can be guaranteed.
A forward-looking statement may include a statement of the assumptions or bases underlying the forward-looking statement. We believe that we have chosen these assumptions or bases in good faith and that they are reasonable. However, when considering these forward-looking statements, you should keep in mind the risk factors and other cautionary statements in this presentation and in our Annual Report on Form 10-K for the year ended December 31, 2018 (“Annual Report”). Those risk factors and other factors noted throughout this presentation and in our Annual Report could cause our actual results to differ materially from those disclosed in any forward-looking statement. You are cautioned not to place undue reliance on any forward-looking statements. Forward-looking statements speak only as of the date on which they are made. We expressly disclaim any obligation to update or revise any forward-looking statement, whether as a result of new information, future events or otherwise, except as required by law.
Non-GAAP Financial Measures
Adjusted EBITDA, Distributable cash fmow and Distribution coverage ratio are not fjnancial measures presented in accordance with GAAP. Enable has included these non-GAAP fjnancial measures in this presentation based on information in its consolidated fjnancial statements. Adjusted EBITDA, Distributable cash fmow and Distribution coverage ratio are supplemental fjnancial measures that management and external users of Enable’s fjnancial statements, such as industry analysts, investors, lenders and rating agencies may use, to assess:
- Enable’s operating performance as compared to those of other publicly traded partnerships in the midstream
energy industry, without regard to capital structure or historical cost basis;
- The ability of Enable’s assets to generate suffjcient cash fmow to make distributions to its partners;
- Enable’s ability to incur and service debt and fund capital expenditures; and
- The viability of acquisitions and other capital expenditure projects and the returns on investment
- f various investment opportunities.
This presentation includes a reconciliation of Adjusted EBITDA and Distributable cash fmow to net income attributable to limited partners and Adjusted EBITDA to net cash provided by operating activities, the most directly comparable GAAP fjnancial measures, as applicable, for each of the periods indicated. Distribution coverage ratio is a fjnancial performance measure used by management to refmect the relationship between Enable’s fjnancial operating performance and cash distributions. Enable believes that the presentation of Adjusted EBITDA, Distributable cash fmow and Distribution coverage ratio provides information useful to investors in assessing its fjnancial condition and results of operations. Adjusted EBITDA, Distributable cash fmow and Distribution coverage ratio should not be considered as alternatives to net income, operating income, revenue, cash fmow from operating activities or any other measure of fjnancial performance or liquidity presented in accordance with GAAP. Adjusted EBITDA, Distributable cash fmow and Distribution coverage ratio have important limitations as analytical tools because they exclude some but not all items that affect the most directly comparable GAAP measures. Additionally, because Adjusted EBITDA, Distributable cash fmow and Distribution coverage ratio may be defjned differently by other companies in Enable’s industry and Enable’s defjnitions of these measures may not be comparable to similarly titled measures of other companies, thereby diminishing their utility.
10 | Investor Highlights 9
Investor Relations
(405) 558-4600 ir@enablemidstream.com Investors.EnableMidstream.com