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First Quarter 2018 Earnings Call May 2018 www.nblmidstream.com - - PowerPoint PPT Presentation
First Quarter 2018 Earnings Call May 2018 www.nblmidstream.com - - PowerPoint PPT Presentation
First Quarter 2018 Earnings Call May 2018 www.nblmidstream.com Forward Looking Statements This presentation contains certain forward -looking statements within the meaning of federal securities law. Words such as anticipates,
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Forward Looking Statements
This presentation contains certain “forward-looking statements” within the meaning of federal securities law. Words such as “anticipates”, “believes”, “expects”, “intends”, “will”, “should”, “may”, “estimates”, and similar expressions may be used to identify forward-looking statements. Forward-looking statements are not statements of historical fact and reflect the Partnership’s current views about future events. No assurances can be given that the forward-looking statements contained in this news release will occur as projected and actual results may differ materially from those projected. Forward-looking statements are based on current expectations, estimates and assumptions that involve a number of risks and uncertainties that could cause actual results to differ materially from those projected. These risks include, without limitation, our customers’ ability to meet their drilling and development plans, changes in general economic conditions, competitive conditions in the Partnership’s industry, actions taken by third-party operators, gatherers, processors and transporters, the demand for crude oil and natural gas gathering and processing services, the Partnership’s ability to successfully implement its business plan, the Partnership’s ability to complete internal growth projects on time and on budget, the price and availability of debt and equity financing, the availability and price of crude oil and natural gas to the consumer compared to the price of alternative and competing fuels, and other risks inherent in the Partnership’s business, including those described under “Risk Factors” and “Forward-Looking Statements” in the Partnership's most recent Annual Report on Form 10-K and in other reports on we file with the Securities and Exchange Commission (“SEC”). These reports are also available from the Partnership’s office or website, www.nblmidstream.com. Forward- looking statements are based on the estimates and opinions of management at the time the statements are made. Noble Midstream does not assume any obligation to update forward-looking statements should circumstances, management’s estimates, or opinions change.
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Strong Execution
Gathering Throughput & Fresh Water Delivery In-line or Exceeding Guidance
First Quarter 2018 Highlights
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Recent Developments
- May Black Diamond Nominations of 58 MBbl/d
- May Nominations at Advantage of 120 MBbl/d
- Collier CGF in Delaware Basin Nearing
Completion
DPU Growth
4.7% Increase Above 4Q17 24% Increase Over 1Q17 36% Above MQD
Financial Discipline
1Q Distribution Coverage Ratio 2.3x 2 1Q Annualized Leverage 2.0x 2, 3 Credit Facility Upsized to $800 MM Plus $350 MM Accordion
Growth Projects Delivered
Delaware CGFs On Schedule:
- Coronado Completed March 30
- Billy Miner II Online April 20
- FWD Delivered at Green River in DJ Basin in March
1Q1 Volumes vs 4Q:
- Oil, Gas & Produced Water Gathering +22%
- Fresh Water Delivery +24%
- Throughput from Advantage Pipeline +47%
1. Oil gathering reflects two months contribution from acquisition of Black Diamond Gathering which closed on 1/31/18 2. Distribution Coverage Ratio and Leverage are Non-GAAP measures, see definition provided in appendix hereto 3. Defined as 1Q Debt / 1Q EBITDA * 4 ($435 million / $54 million *4)
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First Quarter 2018 Results
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In-line or exceeding guidance across the majority of categories
1. Figures are Non-GAAP, see definition provided in appendix hereto 2. 2.2x as reported; 2.4x adjusted for December equity issuance and prior to any Black Diamond acquisition contribution
Actuals 1Q Guidance 1Q v 4Q Gross Volumes: 4Q17 1Q18 Oil Gathered (MBbl/d) 93 130 120
- 135
40% Gas Gathered (MMcf/d) 175 191 190
- 200
9% MBoe/d 122 162 152
- 168
33% PW Gathered (MBw/d) 49 47 42
- 50
- 4%
FW Delivered (MBw/d) 135 168 130
- 150
24% Net Income ($MM) 46 39 42
- 48
- 15%
Gross EBITDA ($MM)¹ 52 58 55
- 61
12% Net EBITDA ($MM)¹ 48 54 52
- 58
13% DCF ($MM)¹ 43 47 44
- 50
9% Distribution Coverage Ratio 2.2x/2.4x² 2.3x 2.1x
- 2.4x
Gross Capex ($MM) 136 249 225
- 250
Net Capex ($MM) 62 128 110
- 125
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40 54
$40
Gathering EBITDA =G2 Total EBITDA
Peer-Leading Distribution Coverage1 Continues
Gathering EBITDA
1Q 2018 NBLX Net EBITDA and Distribution Coverage 1,2
Total EBITDA Implied Distribution Coverage of 4Q Distribution x
2.3x
1. Figures are Non-GAAP; see definition in Appendix hereto 2. G&A allocated to gathering and freshwater delivery based on proportionate share of EBITDA; coverage figures reflect full net maintenance capital totals 3. Assumes 20% distribution growth target
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1.6x
- 1Q Gathering Net EBITDA1 of $40 MM, an 8% Increase Above 4Q
- 1.6x Distribution Coverage Ratio1 excluding Fresh Water
- Gathering net EBITDA represented 74% of total net EBITDA
- Full-Year 2018 Guidance: 20% Distribution Growth with Distribution Coverage Ratio1 of 1.9x –
2.1x1
$ in millions
Fresh Water Delivery EBITDA
Gathering volumes driving growth
2.1x 1.9x - 2.1x
$1.81 $2.19
0.00 0.50 1.00 1.50 2.00 2.50 .x .5x 1.x 1.5x 2.x 2.5x 3.x 3.5x 4.x 4.5x 2017 2018E
Distribution Coverage Ratio1,3 & DPU
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Strong Execution Driving Visible Growth
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89 200 - 235 162 190 - 210 50 100 150 200 250 300 2017 2018E 1Q18 2Q18E
Oil and Gas Gathering
MBoe/d
24 80 -110 47 75 - 90 10 20 30 40 50 60 70 80 90 100 110 120 130 2017 2018E 1Q18 2Q18E
Produced Water Gathering
MBw/d
156 130 -190 168 110 - 130 50 100 150 200 2017 2018E 1Q18 2Q18E
Fresh Water Delivery
MBw/d
Close and Integrate Black Diamond Gathering Consistent milestones and catalysts throughout the year
Begin Mustang Fresh Water Delivery at Green River DevCo Start-up Coronado CGF in Delaware Basin
Commence Operations at Billy Miner II CGF in Delaware Basin
Commence Delaware Basin Compression Services for NBL
Complete Collier CGF in Delaware Basin in May
On Track
Start-up Green River Spec Oil, Gas and Water System by Mid-year
On Track
Operational Scorecard
Expand Advantage Capacity to 200 MBbl/d by end of 3Q18
On Track
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- Net Income Guidance of $175 - $210, or 17% Above 2017
- Revised net income reflects higher expected DD&A due to Black Diamond Gathering acquisition
- 45% Annual Adjusted Net EBITDA1 Growth Anticipated at Guidance Midpoint ($215 - $235 MM)
- Decline in Adjusted Net EBITDA1 from 1Q18E to 2Q18E due to development timing, continued conservatism forecasting FWD
volumes and customer completion operations shift from Colorado River (100% owned) to Green River (25% owned)
- ~20% Increase in Net EBITDA1 in 2H18 Compared to 1H18 Provides Visibility and Momentum into 2019
- 2H18 vs. 2H17 net EBITDA1 anticipated to be up 30%
1H18
2H18E
2018E Gross Capital
1H18 Capital Drives Expected Robust 2H18 Performance
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2H18 expected growth reflects growth project and customer activity timing
1. Figures are Non-GAAP, see definition provided in appendix; 2018 EBITDA estimates adjusted for $7.5 million in Black Diamond Gathering transaction expenses expected in 1H18E
First Half Weighted Capital Drives Momentum into 2019
$94 $115 - $130 10 20 30 40 50 60 70 80 90 100 110 120 130 140 150 2H17 2H18E +30%
Net Adjusted EBITDA ($MM)¹
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DJ Basin Delaware Basin DevCo % Ownership Colorado River 100% Laramie River² 100% Green River 25% Blanco River 40% Trinity River 100% Expected 2018 Capital Investment
- Gathering system
well connections
- New Wells Ranch
gas offload
- Gathering system
well connections
- Multiple DSU’s for
FWD
- Black Diamond
capital
- Completion of
Mustang backbone infrastructure
- Gathering system
well connections
- Buildout of 3 CGFs
- Gathering system
well connections
- Expansion of
Advantage throughput capacity to 200 MBbl/d
- Compression
2018 Capital Budget Detail
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Colorado River 4% Laramie River² 29% Green River 13%
Other
Blanco River 45% Trinity River 8%
Gross Capital1 $500 - 535 MM
1. Excludes acquisition capital 2. Includes Black Diamond Gathering capital
Colorado River 8% Laramie River² 37% Green River 6%
Other
Blanco River 34% Trinity River 15%
Net Capital1
(attributable to the Partnership)
$270 - 285 MM Growth capital focused on Blanco River and Laramie River DevCos
No Impact to 2018 Budget from U.S. Steel Tariff
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- 90 MBbl/d of Crude Oil Capacity (115 MBoe/d)
from 5 CGFs Planned to be Operational by Mid-2018
- 5th planned CGF, Collier, nearing
completion
- CGF Capacity at Mid-Year Provides Long
Runway for Sponsor Planned Volume Growth
- All CGFs Connected and Flowing Through
Advantage Pipeline
- Substantial Capital Efficiency Expected in 2019
Once Backbone Infrastructure is Complete
Near-Term Delaware Basin CGF Projects Daily Capacity Oil
(MBbl/d)
Gas
(MMcf/d)
PW
(MBw/d)
Est. Online #1 Billy Miner I 15 30 30 Online #2 Jesse James 15 30 30 Online #3 Coronado * 20 30 60 Online #4 Billy Miner II 20 30 60 Online #5 Collier * 20 30 60 1H 2018
Delaware Basin: Blanco River
* expandable to 30 MBbl/d and 60 MMcf/d with minimal equipment additions
Significant 2018 growth driver
Blanco River Activity 4Q17 1Q18 Oil & Gas Gathered (MBoe/d) 15 19 PW Gathered (MBw/d) 24 26 FW Delivered (MBw/d)
- Gross Organic Capital ($MM)
95 154 Net Organic Capital ($MM) 38 62 Well Connections 9 9 Average Lateral Length (ft) ~6,400 ~7,700
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Delaware Basin: Trinity River
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- April Nominations of 108 MBbl/d; May
Nominations of ~120 MBbl/d
- 2018 Volumes Now Anticipated to Average in
Excess of 100 MBbl/d
- Additional Upside Opportunities Currently Being
Negotiated
- Opportunities for additional acreage dedications and
volume commitments
- Leverage asset footprint with minimal capital
required
- Advantage Pipeline Positioned to Benefit from
Tightness in Delaware Basin Takeaway Capacity
- Additional pump ordered to expand system capacity
to 200 MBbl/d by end of 3Q18
- New Build Compression Started at Coronado and
Billy Miner II, Installation at Collier Under Way
- 18,000 HP of owned compression installed
by mid-year
30 60 88 >100 20 40 60 80 100 120 Apr-17 4Q17 1Q18 2018E
Value creation continues at Advantage with record volumes
Advantage Pipeline
Additional upside
- pportunities
under negotiation
Advantage Pipeline Oil Throughput (MBbl/d) Trinity River Activity 4Q17 1Q18 Gross Organic Capital ($MM) 27 Net Organic Capital ($MM) 27 Advantage Throughput* (MBbl/d) 60 88 Owned Compression HP 6,000 12,000 Compression
*Excluded from total throughput due to accounting treatment as investment income
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DJ Basin: Laramie River
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- Successful Integration of Black Diamond Gathering
Operations
- Tallgrass Outlet In-Service, Completing Connectivity to
Every DJ Downstream Takeaway Option
- Realizing Operational and Financial Synergies
- Connection of wholly owned system at Lucerne Terminal
complete
- Planned Green River connection at Milton Terminal
- Potential addition of complementary services, including
storage
- Significant Undedicated Acreage in Catchment Area
Remaining
- 2018 Exit Volumes Expected to be Higher than
Acquisition Case
- May nominations of 58 MBbl/d
- Planning for Significant 2H18 Activity and Throughput
Ramp
- Planned System Integration with Downstream Outlets
and Black Diamond Gathering Significant third-party activity acceleration underway
Laramie River Activity 4Q17 1Q18 Oil & Gas Gathered (MBoe/d) 16 49 PW Gathered (MBw/d) 4.5 5 FW Delivered (MBw/d) 34 44 Gross Organic Capital ($MM) 11 41 Net Organic Capital ($MM) 11 31 Well Connections 12 74 Average Lateral Length (ft) ~6,800 ~7,600
Black Diamond Gathering Wholly Owned Infrastructure
* Includes two months of contribution from Black Diamond Gathering
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DJ Basin: Colorado River
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- DevCo Represents 4% of Gross 2018E
Capital Budget and ~55% of 2018E Gross EBITDA1
- Backbone infrastructure in place
- Activity highly focused on capital
efficient well connects
- Total NBLX Wells Ranch System Capacity
Expanded to 200 MMcf/d
- Upstream Results Continue to Perform
Well Versus NBLX Expectations
- No Fresh Water Delivery Volumes in
2Q18 Due to NBL Activity Shift to Mustang (Green River)
- Mature Infrastructure Highlights Capital
Efficiency: $3 MM in 1Q18 Capital for 31 Well Connections for Oil, Gas, and Produced Water
Significant free cash generation
Colorado River Activity 4Q17 1Q18 Oil & Gas Gathered (MBoe/d) 92 94 PW Gathered (MBw/d) 20 16 FW Delivered (MBw/d) 67 102 Gross Organic Capital ($MM) 7 3 Net Organic Capital ($MM) 7 3 Well Connections 21 31 Average Lateral Length (ft) ~9,500 ~7,400
Wells Ranch Infrastructure
1. Figures are Non-GAAP; see definition in Appendix
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DJ Basin: Green River
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- Fresh Water Delivery Began in March
- Two NBL completion crews operating in
Mustang during 2Q18
- Spec Oil, Gas and Produced Water Backbone
Gathering Infrastructure On Track for Mid-Year Startup
- Gathering volumes anticipated mid-year
2018
- Planned Oil Connection into Black Diamond
Milton Terminal
- Development Drilling and Row Concept in
Southern Portion of Mustang Drives Highly Efficient Infrastructure Spend from the Start
- Full Infrastructure Build Out Includes ~250 Miles
- f Pipelines (Oil, Gas, PW and FW)
- ~$500 MM Total Development Capital Over 10
Years
- Anticipate 4.5x to 5.5x organic build
multiples
Mustang Infrastructure Design
Infrastructure build out to support NBL’s Mustang Area
Green River Activity 4Q17 1Q18 Oil & Gas Gathered (MBoe/d)
- PW Gathered (MBw/d)
- FW Delivered (MBw/d)
- 22
Gross Organic Capital ($MM) 23 24 Net Organic Capital ($MM) 6 6 Well Connections
- Average Lateral Length (ft)
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Fresh Water Mix Creates Quarterly Fluctuations in Net Financials
1. Figures are Non-GAAP; see definition in Appendix
- Enhanced Completions Continue to Drive Robust Fresh Water Demand per Well
- NBL Mustang and Wells Ranch standard design of 1,800 lbs/ft
- Future Volumes and Net EBITDA1 will Reflect Mix Shift to Green River (25% Owned) from Colorado River (100%
Owned)
- Fresh Water Delivery to NBL’s Mustang Development Commenced in March
- Two NBL completion crews in Mustang (Green River) in 2Q18
- Balance between Wells Ranch (Colorado River) and Mustang (Green River) in 2H18
- No fresh water delivery activity at East Pony (San Juan River) currently forecasted for 2018
Zero Colorado River fresh water delivery volumes anticipated in 2Q18
Colorado River San Juan River Laramie River
2017
Colorado River Green River Laramie River
2018
Gross Fresh Water Volume Mix by DevCo
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Forecasted FWD Completion Crews 1Q18 2Q18E 3Q18E 4Q18E Colorado River (100% Owned) 1.7 1.3 1.5 Green River (25% Owned) 0.3 2.0 1.3 1.5 Laramie River (100% Owned) 1.0 1.0 1.5 2.0
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2Q18 and 2018 Guidance Detail
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Quarterly Full Year 1Q¹ Actuals 2Q Estimate¹ 2017 Actuals Updated 2018E¹ Gross Volumes Oil Gathered (MBbl/d) 130 160 - 175 66 165 - 190 Gas Gathered (MMcf/d) 191 195 - 215 139 215 - 265 Oil and Gas Gathered (MBoe/d) 162 190 - 210 89 200 - 235 Produced Water Gathered (MBw/d) 47 75 - 90 24 80 - 110 Fresh Water Delivered (MBw/d) 168 110 - 130 156 130 - 190 Financials ($MM) (1) Net Income 39 34 - 39 164 175 - 210 Adjusted Gross EBITDA2,3 58 58 - 63 179 275 - 315 Adjusted EBITDA2,3 54 46 - 51 155 215 - 235 Distributable Cash Flow2 47 37 - 42 138 180 - 195 Distribution Coverage Ratio 2,4 2.3x 1.7x – 1.9x 2.1x 1.9x - 2.1x Gross Capex5 249 145 - 165 390 500 - 535 Net Capex 5 128 60 - 70 225 270 - 285
1. Black Diamond Gathering contribution included for period following January 31, 2018 close 2. Includes Non-GAAP measures; see definition in Appendix hereto 3. 1Q18 , 2Q18 and 2018 Adjusted for in Black Diamond transaction expenses not capitalized 4. Estimates include forecasted DPU growth of 4.7% quarterly, or 20% annual 5. Excludes acquisition capital
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Leading Long-Term Outlook
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Organic – No Drop Downs
2017-2020E 2018E 2019-2022E
Old New New Distribution per Unit 20% 20% 20% Coverage (in all years) (1) > 1.3x 1.9 – 2.1x > 1.3x Leverage (in all years) < 2.5x < 2.5x < 2.0x ROACE (1, 3) NA > 15% 13 – 16% DCF Funding % of Capex and Distributions (4) NA ~50% ~90% (cumulative)
1. Non-GAAP measures, definition provided in appendix 2. Reflects combined Black Diamond, Advantage, and 2017 drop-down net acquisition cost divided by net EBTIDA; definition of EBITDA provided in appendix 3. Return on average capital employed: earnings before interest and taxes divided by (average total assets – average current liabilities); see definition provided in appendix 4. % of distributions + capex funded by distributable cash flow
Substantial organic growth with large existing drop-down inventory
Material Upside to Improved Outlook
- Prudent Commodity Price View:
Based on $50/Bbl and $3/Mcf Price Deck vs. Current Strip
- Continued Business
Development Success, Leveraging Asset Footprints
- Permian Crude / Y-Grade
Project and Other Long-Haul
- Significant and Growing Drop-
Down Inventory
~90%
% of distributions + capex covered by DCF¹ 2019-2022E (cumulative) in organic base plan
~6x(2)
combined adjusted EBITIDA¹ acquisition multiple by 2020E
ROACE(1,3)
2018: >15% Long-Term: 13 - 16%
Extending and improving long-term distribution growth, coverage, and leverage
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Steel Tariff and FERC Tax Allowance Policy Change: Immaterial Impact
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- Current Tariff: 25% on Steel, 10% on Aluminum
- Domestic and foreign line pipe pricing increase following announcement
- Remaining uncertainty around permanent exemptions
- No Impact to 2018 Budget Expected:
- Steel for DJ Basin and Delaware Basin capital projects procured in late 2017/early 2018
prior to tariff announcement
- Beyond 2018, Worst Case Sensitivity Analysis Indicates Just ~3-5% Increase in Overall Project
Costs U.S. Steel Tariff FERC Income Tax Allowance Policy Change
- FERC Ruled to No Longer Allow Income Taxes to be Included in Cost-of-Service Rates for
Interstate Pipelines Structured as Partnerships
- Immaterial Impact as Noble Midstream Does Not Have Cost-of-Service Pipeline Rates
- Current NBLX rate structure: negotiated rates
- Gathering Systems and Advantage Pipeline are Under State Regulation or Operate Under FERC
Waivers
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Appendix
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NBLX Asset Map: DJ Basin
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Black Diamond (54.4%) 1 Dedicated Acres: 141k2 Laramie River DevCo (100%)
- Oil Gathering
Area: East Pony Dedicated Acres: 44k Colorado River DevCo (100%)
- Oil Gathering
San Juan River DevCo (25%)
- FW Delivery
Area: Mustang Dedicated Acres: 75k Green River DevCo (25%)
- Oil Gathering
- Gas Gathering
- PW Gathering
- FW Delivery
Area: Wells Ranch Dedicated Acres: 78k Colorado River DevCo (100%)
- Oil Gathering
- Gas Gathering
- PW Gathering
- FW Delivery
Area: Greeley Crescent Dedicated Acres: 65k Laramie River DevCo (100%)
- Oil Gathering
- PW Gathering
- FW Delivery
Area: Bronco Dedicated Acres: 36k Gunnison River DevCo (5%)
- Oil Gathering
- PW Gathering
- FW Delivery
1. Acquisition closed January 31, 2018 2. Reflects expansion of PDC Energy acreage dedication to Black Diamond Gathering system
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NBLX Asset Map: Delaware Basin
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Area: Delaware Basin Dedicated Acres: 111k Blanco River DevCo (40%)
- Oil Gathering
- Gas Gathering
- PW Gathering
Trinity River DevCo (100%)
- HP Gas Compression
Advantage JV (50%) NBL Dedicated Acres: 47k Trinity River DevCo (100%)
- Oil Transmission
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50%
NBLX Structure
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Green River San Juan River Gunnison River Colorado River Laramie River Trinity River Blanco River Controlling Interest Noble Midstream Services, LLC Public Unitholders (LP) White Cliffs Pipeline L.L.C. ROFR Assets:
- East Pony Gas Gathering
- East Pony Gas Processing
- Eagle Ford Shale Midstream
- Additional DJ Acreage
- Additional Delaware Basin
Services Noble Energy NYSE: NBL Noble Midstream Partners LP NYSE: NBLX Noble Midstream GP LLC 45.5% Limited Partner Interest 100% 100% 100% 100% 5% 25% 25% 40% 75% 95% 3.33% Non-Operating Membership Interest 54.5% Limited Partner Interest 100% Non-Economic General Partner Interest Advantage JV 60% 75% Black Diamond Non-Controlling Interest 54.4%
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Non-GAAP Financial Measures
22 This presentation includes Adjusted EBITDA, Distributable Cash Flow, Distribution Coverage Ratio and ROACE, all of which are non-GAAP measures which may be used periodically by management when discussing our financial results with investors and analysts. We define Adjusted EBITDA as net income before income taxes, net interest expense, depreciation and amortization and unit-based compensation. Adjusted EBITDA is used as a supplemental financial measure by management and by external users of our financial statements, such as investors, industry analysts, lenders and ratings agencies, to assess: our
- perating performance as compared to those of other companies in the midstream energy industry, without regard to financing methods, historical cost basis or capital structure; the
ability of our assets to generate sufficient cash flow to make distributions to our partners; our 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 of various investment opportunities. We define Distributable Cash Flow as Adjusted EBITDA less estimated maintenance capital expenditures and cash interest expense. Distributable Cash Flow is used by management to evaluate our overall performance. Our partnership agreement requires us to distribute all cash on a quarterly basis, and Distributable Cash Flow is one of the factors used by the board of directors of our general partner to help determine the amount of available cash that is available to our unitholders for a given period. We calculate our Distribution Coverage Ratio as Distributable Cash Flow divided by total distributions declared. The Distribution Coverage Ratio is used by management to illustrate our ability to make our distributions each quarter. We define ROACE as earnings before interest and taxes divided by (average total assets – average current liabilities). ROACE is used by management to measure the efficiency of the utilization of the capital that we employ. We believe that the presentation of Adjusted EBITDA, Distributable Cash Flow, Distribution Coverage Ratio and ROACE provide information useful to investors in assessing our financial condition and results of operations. The GAAP measure most directly comparable to Adjusted EBITDA, Distributable Cash Flow, Distribution Coverage Ratio and ROACE is Net Income. Adjusted EBITDA, Distributable Cash Flow, Distribution Coverage Ratio and ROACE should not be considered alternatives to net income or any other measure of financial performance
- r liquidity presented in accordance with GAAP. Adjusted EBITDA, Distributable Cash Flow, Distribution Coverage Ratio and ROACE exclude some, but not all, items that affect net
income, and these measures may vary from those of other companies. As a result, Adjusted EBITDA, Distributable Cash Flow, Distribution Coverage Ratio and ROACE as presented herein may not be comparable to similarly titled measures of other companies. Noble Midstream does not provide guidance on the reconciling items between forecasted Net Income, forecasted Adjusted EBITDA, forecasted Distributable Cash Flow and forecasted Distribution Coverage Ratio due to the uncertainty regarding timing and estimates of these items. Noble Midstream provides a range for the forecasts of Net Income, Adjusted EBITDA, Distributable Cash Flow and Distribution Coverage Ratio to allow for the variability in timing and uncertainty of estimates of reconciling items between forecasted Net Income, forecasted Adjusted EBITDA, forecasted Distributable Cash Flow and forecasted Distribution Coverage Ratio. Therefore, the Partnership cannot reconcile forecasted Net Income to forecasted Adjusted EBITDA, forecasted Distributable Cash Flow or forecasted Distribution Coverage Ratio without unreasonable effort. In addition to Net Income, the GAAP measure most directly comparable to Adjusted EBITDA and Distributable Cash Flow is net cash provided by operating activities. Adjusted EBITDA and Distributable Cash Flow should not be considered alternatives to net income, net cash provided by operating activities or any other measure of financial performance or liquidity presented in accordance with GAAP. Due to the forward-looking nature of net cash provided by operating activities, management cannot reliably predict certain of the necessary components of the most directly comparable forward-looking GAAP measures, such as future impairments and future changes in working capital. Accordingly, Noble Midstream is unable to present a quantitative reconciliation of the aforementioned forward-looking non-GAAP financial measures to net cash provided by operating activities. Amounts excluded from these non-GAAP measures in future periods could be significant.
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Non-GAAP Reconciliation
23
$ in millions
1Q 2Q 3Q 4Q FY 1Q 2QE FY Net Income 35 $ 39 $ 44 $ 46 $ 164 $ 39 34 - 39 175 - 210 Add: Depreciation and Amortization 2 2 4 4 13 11 19 75 - 80 Add: Interest Expense, Net of Amount Capitalized 1 1 1 1 3 15 - 16 Add: Income Tax Provision
- (0)
0.1
- Add: Unit-Based Compensation
1 0.3 0.3 2 Add: Transaction Expenses 6 1.5 7.5 EBITDA 37 $ 42 $ 48 $ 52 $ 179 $ 58 58 - 63 275 - 315 Less: EBITDA Attributable to Noncontrolling Interests 11 8 2 3 24 4 12 60 - 80 EBITDA Attributable to NBLX 26 $ 34 $ 46 $ 48 $ 155 $ 54 46 - 51 215 - 235 Less: Maintenance Capital Expenditures & Cash Interest 3 4 5 5 17 7 9 35-40 DCF Attributable to NBLX 24 $ 30 $ 41 $ 43 $ 138 $ 47 37 - 42 180- 195 Distribution Coverage 1.8x 1.9x 2.4x 2.2x 2.1x 2.3x 1.7x - 1.9x 1.9x - 2.1x 2017 2018
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1001 Noble Energy Way Houston, TX 77070
Contact Information
Megan Repine Investor Relations megan.repine@nblmidstream.com 832.639.7380