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Presentation TitlePresentation Subtitle
Crestwood Midstream Partners LP Crestwood Equity Partners LP
Connections for America’s Energy™
™
Presentation TitlePresentation Subtitle
Crestwood Midstream Partners LP Crestwood Equity Partners LP
Connections for America’s Energy™
™
Presentation TitlePresentation Subtitle
Crestwood Midstream Partners LP Crestwood Equity Partners LP
Connections for America’s Energy™
™
12/4/2017
Presentation TitlePresentation Subtitle
Crestwood Midstream Partners LP Crestwood Equity Partners LP
Connections for America’s Energy™
™
Presentation TitlePresentation Subtitle
Crestwood Midstream Partners LP Crestwood Equity Partners LP
Connections for America’s Energy™
™Connections for America’s Energy™
™
Investor Presentation
December 2017
Connections for America’s Energy™ ™™ ™™ ™
The statements in this communication regarding future events, occurrences, circumstances, activities, performance,outcomes and results are forward-looking statements. Although these statements reflect the current views, assumptionsand expectations of Crestwood’s management, the matters addressed herein are subject to numerous risks anduncertainties which could cause actual activities, performance, outcomes and results to differ materially from thoseindicated. Such forward-looking statements include, but are not limited to, statements about the benefits that may resultfrom the merger and statements about the future financial and operating results, objectives, expectations and intentionsand other statements that are not historical facts. Factors that could result in such differences or otherwise materially affectCrestwood’s financial condition, results of operations and cash flows include, without limitation, the possibility thatexpected cost reductions will not be realized, or will not be realized within the expected timeframe; fluctuations in crude oil,natural gas and NGL prices (including, without limitation, lower commodity prices for sustained periods of time); the extentand success of drilling efforts, as well as the extent and quality of natural gas and crude oil volumes produced withinproximity of Crestwood assets; failure or delays by customers in achieving expected production in their oil and gasprojects; competitive conditions in the industry and their impact on our ability to connect supplies to Crestwood gathering,processing and transportation assets or systems; actions or inactions taken or non-performance by third parties, includingsuppliers, contractors, operators, processors, transporters and customers; the ability of Crestwood to consummateacquisitions, successfully integrate the acquired businesses, realize any cost savings and other synergies from anyacquisition; changes in the availability and cost of capital; operating hazards, natural disasters, weather-related delays,casualty losses and other matters beyond Crestwood’s control; timely receipt of necessary government approvals andpermits, the ability of Crestwood to control the costs of construction, including costs of materials, labor and right-of-wayand other factors that may impact Crestwood’s ability to complete projects within budget and on schedule; the effects ofexisting and future laws and governmental regulations, including environmental and climate change requirements; theeffects of existing and future litigation; and risks related to the substantial indebtedness, of either company, as well asother factors disclosed in Crestwood’s filings with the U.S. Securities and Exchange Commission. You should read filingsmade by Crestwood with the U.S. Securities and Exchange Commission, including Annual Reports on Form 10-K and themost recent Quarterly Reports and Current Reports for a more extensive list of factors that could affect results. Readersare cautioned not to place undue reliance on forward-looking statements, which reflect management’s view only as of thedate made. Crestwood does not assume any obligation to update these forward-looking statements.
Company Information
2
Forward-Looking Statements
Contact Information
Corporate Headquarters811 Main Street
Suite 3400
Houston, TX 77002
(1) Market data as of 12/1/2017. (2) Unit count and balance sheet data as of 9/30/2017.
Crestwood Equity Partners LP
NYSE Ticker CEQP
Market Capitalization ($MM)(1,2) $1,719
Enterprise Value ($MM)(2) $4,015
Annualized Distribution $2.40
Investor [email protected]
(713) 380-3081
No IDRs
Corporate Structure
Connections for America’s Energy™ ™™ ™™ ™ 3
Well-Positioned for DCF per Unit Growth
Connections for America’s Energy™ ™™ ™™ ™
Key Investor Highlights
4
• Focused on execution
• Attractive balance sheet
• Strong distribution coverage
• Disciplined growth strategy
• Self-funded capital program
• Significant insider ownership
Increased 2017E guidance reaffirmed
Long-termLeverage Ratio <4.0x
1.2x-1.3x Long-termCoverage Ratio
No equity required to fund ’17/’18 capital programs
~32% LP units; alignment of interest with LP’s
Bakken, Delaware Basin, PRB Niobrara, Marcellus
Connections for America’s Energy™ ™™ ™™ ™
Diversified Assets in Active Basins
5
Crestwood assets offer operating scale, fixed-fee services & DCF growth
• 5-Yr Growth Strategy Driven by 4 Core Growth Areas− Bakken – 2018+− Delaware Basin – 2019+− PRB – 2019+− Marcellus Shale – 2020+
• Remaining portfolio of assets provide stable cash flows, optimization alternatives and upside optionality
Bakken
Northeast MarcellusPRB
Niobrara
DelawareBasin
Connections for America’s Energy™ ™™ ™™ ™
Balanced Portfolio; High Quality Customers
CEQP Contract Portfolio
66
Variable Rate Contracts
15%
Take-or-Pay and Fixed-Fee Contracts
85%
~85% of Crestwood 2017 EBITDA from take-or-pay and fixed-fee contracts; Key assets protected from commodity volatility and volume declines
Long-Term Contract Profile With High Quality Customers(1)
2017 Forecasted EBITDA
(1) Not inclusive of all Crestwood customers.
Stable cash flows supported by fixed-fee contracts, top-tier customer base and balanced commodity exposure by volume and EBITDA
G&P assets backed by 1.1 million acreage; High quality producer mix
Top-tier NE Gas Storage & Transportation franchise; Largely investment grade
Diversified NGL Marketing, Supply & Logistics business
60% 20%
20%
48%
29%
23%
Gas Oil NGLs
Volumes by Commodity
EBITDA by Commodity
Connections for America’s Energy™ ™™ ™™ ™
0
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7
SW Marcellus• +42% YTD volume growth• 21 DUCs completed in 2017• 10%/yr PDP decline rate in 2018(1)
Improved Fundamentals Drive Volume Growth
System DriversKey Asset Volumes Since FY 2016
Barnett• 4% YTD modest volume decline• Active workover program in 1H:17• 5-10%/yr PDP decline rate in 2018
Bakken• +31%/13% YTD oil/gas volume growth• 100-110 well connects in 2017• 20-25% volume growth in 2018
Delaware Basin• +215% YTD volume growth• 2-3 active rigs in 2017• >20% volume growth in 2018
2017 YTD oil, gas and water volumes up 31%, 27% & 33%; continued growth expected from 2018 drilling plans
PRB Niobrara• +43% YTD volume growth• 3 active rigs in 2017• 4 rigs forecasted in 2018
BarnettSW Marcellus
Delaware Basin PRB Niobrara
Bakken – Natural GasBakken – Oil
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Third-party curtailments
+31% +13%
+215%
+42%
+43%
(4%)
(1) MVCs through 2018 term; however, all current and future cash flow reflective of actual throughput and rate (no cash flow cliff).
Connections for America’s Energy™ ™™ ™™ ™ 8
Disciplined Organic Growth Strategy
Project Region Key Customer(s) 2017-2018 Capital ($MM) In-Service
Date
Nautilus System Delaware Basin Shell $130MM/~$32MM net to CEQP IN-SERVICE
Arrow Debottlenecking – Phase 1 Bakken Arrow Producers $45MM IN-SERVICE
Bear Den Processing Plant - Phase 1 Bakken Arrow Producers $115MM IN-SERVICE
Arrow Debottlenecking – Phase 2 Bakken Arrow Producers $85MM 2018 / 2019
Orla Processing Plant and Pipeline Delaware Basin Multiple(1) $170MM/$10MM net to CEQP(2) Q3 2018
Bear Den Processing Plant - Phase 2 Bakken Arrow Producers ~$185MM Q2 2019
Incremental Annual Cash Flow Impact from Capital Projects
Committed high return expansion projects drive accretive DCF growth in 2017-2021
(1) Current customers include Concho, Mewbourne, Matador, Cimarex, Marathon and ExxonMobil. Significant third party customers within close proximity of the Orla Plant’s anticipated location.
(2) Assumes First Reserves covers $160 million of plant capital in return for a 50% ownership in the Willow Lake gathering and processing assets.
Highlights
• High-grading organic expansion around core assets; focused on driving greatest DCF per unit accretion
• High rate of return project build multiples of 5x to 7x
• ~$120MM+ expected EBITDA contribution from current projects by 2021
Focused on 5x to 7x organic build multiples vs 12x to 15x M&A multiples
$0
$20
$40
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Increm
ental A
nnua
l Cash Flow
($US Millions)
Bakken Delaware Basin
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Self-Funded 2017 and 2018 Capital Programs
US Salt Divestiture
Crestwood is committed to maintaining a strong balance sheet and excess distribution coverage as it pursues organic growth projects
• Divested US Salt LLC, a non-core business in the MS&L segment, for approximately $225 million
• Valuation is ~11x 2017E distributable cash flow
• Transaction closed December 1, 2017
Crestwood is self-funding its 2017 and 2018 capital programs to maximize project returns and DCF/unit value creation
Retained DCF
Joint-Venture Strategy
• Forecasted cash flow growth allows Crestwood to maintain distribution coverage >1.2x and leverage <4.0x
• Crestwood will reinvest cash flow into accretive organic projects in Q4 2017 and FY 2018
• Strategic joint-ventures minimize project risk and capital commitments, while enhancing commercial opportunities:– Delaware Basin: First Reserve and Shell Midstream (NYSE: SHLX)– NE Marcellus: Consolidated Edison (NYSE:ED)– PRB Niobrara: Williams Partners (NYSE:WPZ)
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Connections for America’s Energy™ ™™ ™™ ™ 10
Attractive Set of Near-term Organic Growth Projects
Connections for America’s Energy™ ™™ ™™ ™
Bakken Growth Strategy
11
Crestwood continues to expand the Bakken Arrow System to offer producers full value-chain services and meet growing volume forecasts
Arrow Overview
Oil
Natural Gas
Water
• Arrow Gathering system expected to generate ~$120MM of Adj. EBITDA in 2017; ~$90MM in 2016 Adj. EBITDA
• >1,500 drilling locations identified on dedicated acreage
• Diversified and balanced group of producers: WPX, QEP, XTO, EnerPlus, Bruin, Rimrock
• 8-year weighted average contract length and Crestwood purchases 100% of oil and gas volumes at the wellhead
• Crestwood expects to connect >100 wells in both 2017 and 2018
• The Arrow system will be Crestwood’s largest driver of cash flow growth in ’17/’18
3-Product Growth Strategy• Oil gathering volumes expected to increase ~15% in 2018
• Current projects: Increasing oil gathering capacity to 120 MBbls/d
• Gas gathering volumes expected to increase ~50% in 2018
• Current Projects: (1) Increasing gas gathering capacity to 120 MMcf/d and (2) Bear Den Plant: 2-phase 150 MMcf/d plant; Evaluating downstream NGL solutions to optimize producer netbacks and project returns
• Water gathering volumes expected to increase ~60% in 2018
• Current projects: Increasing water gathering capacity to 90 MBbls/d and new SWD wells
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Forecasted Volume Growth
80 well connects per year through 2021 drives
15-20% EBITDA CAGR
–
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Connections for America’s Energy™ ™™ ™™ ™
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Arrow System Expansion Projects
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Arrow expansions nearly double capacity to support long-term development plans and increasing Bakken well performance
Gathering Projects
New Oil & Water Pumps
New Compressor
Station
Bear Den Plant
Phase 1: 30 MMcf/d
Phase 2: 120 MMcf/d
SWD Expansions
Crude Gathering Water Gathering Gas Gathering Gas Processing
+50% +70% +120% +400%
Connections for America’s Energy™ ™™ ™™ ™ 13
Arrow Bear Den Processing Plant
Crestwood’s Bear Den West pipeline and Phase 1 plant commissioned in late November 2017; Phase 2 scheduled for Q2 2019 as Arrow volumes ramp up
Greatly enhances Flow Assurance and “control of our own destiny”
Project Rationale
Project Overview• Bear Den Processing Plant is a two phase processing
solution that will provide 150 MMcf/d of combined processing capacity
• Phase 1: “Immediate solution” - 30 MMcf/d RJT unit sized to process excess gas volumes currently flaring or above third-party contracts
– Phase 1 project cost $115MM
– Commissioned late November 2017
• Phase 2: “Long-term solution” - 120 MMcf/d cryogenic plant sized to process 100% of Arrow gas by 2019
– Phase 2 project expected cost ~$185MM
– Targeted in-service Q2 2019
• Attractive total project returns of sub-6x; Phase 1 project accretive to DCF in 2018
Bear Den Plant – Phase 1
Better netbacks and more reliable service for Arrow producers than existing processor and competing proposals
Improves competitive position and ability to attract incremental third parties in the area
Enables Crestwood to utilize integrated midstream value chain with incremental volumes
Bear Den plant phase-1: final stages of construction
Crestwood purchases 100% of oil and gas volumes at the wellhead from its producers; full control of processing volumes
Connections for America’s Energy™ ™™ ™™ ™
Delaware Basin Growth Strategy
14
Asset MapAsset Overview & Strategy
Crestwood is building competitive scale and fully integrated systems in the heart of the Delaware Basin, the most active shale play in the US
• 50/50 joint venture with First Reserve
• Current assets includes Willow Lake gathering & processing and Nautilus gathering & compression
– Total gathering capacity of 335 MMcf/d
– Total processing capacity of 85 MMcf/d
• Current growth projects: In-Service
– 30 MMcf/d dew point control skid Complete
– Orla Express Pipeline Q3 2018
– 200 MMcf/d Orla Processing Plant Q3 2018
• Future expansion opportunities:
– Crude oil gathering, terminalling and condensate stabilization/blending
– Produced water gathering and disposal
>$100 million of total Delaware Basin EBITDA potential by 2021 from identified expansion opportunities
Connections for America’s Energy™ ™™ ™™ ™
Delaware Basin Current G&P Assets
15
Willow Lake and Nautilus gathering systems, combined gather over 110 MMcf/d, are at the center of significant development activity in the Delaware Basin
Delaware System MapsWillow Lake System• Willow Lake Gathering and Processing System is at the epicenter of
Northern Delaware Basin development in Eddy and Lea counties, NM
– ~82 miles low pressure gathering system
– Current processing capacity of 85 MMcf/d (includes 30 MMcf/d expansion to handle volume growth during 3Q17-2Q18)
• Existing acreage/well dedications with Concho and Mewbourne supported by 100,000 acre AMI around plant/system
• The Orla Express pipeline will connect the Willow Lake system to the Orla Processing Plant in 1H 2018
Nautilus System
Asset Ownership:Willow Lake
Orla Plant Nautilus
Crestwood 50% 50% 25%
First Reserve 50% 50% 25%
Shell Midstream - - 50%
• Nautilus Natural Gas Gathering System supports Shell’s Delaware Basin development program
– 20-year tiered fixed-fee gathering and compression contract
– 100,000 acreage dedication in Loving and Ward counties, TX
• ~$90MM of capital invested in 2017 at a ~5.0x build-multiple
• October 2017 – Shell Midstream exercises option to acquire 50% interest in the system; further aligning Crestwood’s and Shell’s interests
Over 200K dedicated acres
The Permian basin is the most important asset within Shell’s unconventional portfolio, Shell has around 270k acres in the Permian, and intends to invest $1 billion per year to grow production to 155 MBbls/d by 2020.” –SHLX Q2’17 Earnings Call
Connections for America’s Energy™ ™™ ™™ ™
Orla Express Pipeline & Orla Processing Plant
16
200 MMcf/d processing plant and super-header integrates asset footprint to compete across the entire primary Delaware Basin catchment area
Premier G&P Footprint in Delaware Basin Core
WES/ETP Bone Spring
Project Overview• Construction underway on 33 miles
of 20” pipeline and 200 MMcf/d cryogenic gas plant in Orla, TX
– Plant capacity expandable to 600 MMcf/d
– Plant location offers multiple residue and NGL takeaway options
• Initial phase connects Willow Lake gathering to Orla Express and Orla plant
– Base scope capital of ~$170 million
– Targeted in-service date Q3 2018
• Expansion phase will connect the Nautilus system to Orla plant and new laterals connecting additional producers
Orla Plant: 200 MMcf/d cryogenic gas processing
plant
Orla Express Pipeline connecting existing
Willow Lake system to new Orla gas
processing plant
(1)
(1) Assumes First Reserves covers $160 million of plant capital in return for a 50% ownership in the Willow Lake gathering and processing assets.
Connections for America’s Energy™ ™™ ™™ ™
Delaware Basin Water Solutions Next Leg of Growth
17
Scalable infrastructure solutions for Delaware Basin water requirements; potential next phase of Delaware Basin growth strategy
Delaware Water Production
• Based on Crestwood’s current capture area, 2.4 MMBbls/d of produced water is forecasted by 2021
• Crestwood’s existing assets well-positioned to offer water gathering and disposal services to producers
• Crestwood has extensive experience gathering and disposing produced water in the BakkenCapture Area.
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Source: DrillingInfo and Wood Mackenzie.(1) Water forecast based on capture area gas forecast and converted to
water based on GORs and WORs for the Wolfcamp and Bone Spring type curves per Wood Mackenzie.
EddyLea
Culberson
JeffDavis
Loving
Pecos
Reeves
Ward
Winkler
Daily Production (BBL)
5-YR Delaware Basin Water Forecast(1)
MMBbls/d
Connections for America’s Energy™ ™™ ™™ ™
• Strategic 50/50 JV with Consolidated Edison (“Con Edison”)• Extensive network of FERC regulated storage and pipeline
assets located at center of prolific Marcellus dry-gas resource play− 2.9 Bcf/d delivery capacity; over 180 miles of pipes− 41 Bcf storage capacity
• Evaluating incremental takeaway projects out of the NE Marcellus basin with downstream pipeline partners
• Stagecoach generated ~$145MM Adjusted EBITDA in 2016; Current CEQP cash flow distribution is 35%− June 2018: Cash flow distribution steps up 5% to 40%− June 2019: Cash flow distribution steps up 10% to 50%
NE Marcellus is largest US gas supply base and best potential for demand growth; Stagecoach is strategically positioned to capture growth opportunities
23%
49%
28%
79%
13%
9%
NE Marcellus - Stagecoach Gas Services JV
18
Assets MapStagecoach Overview
Stagecoach Storage Customers
Producers
Marketers
Marketers
Utility / LDCs
Producers
Stagecoach Transportation Customers
Utility/ LDCs
CON EDISON SERVICE AREA
Connections for America’s Energy™ ™™ ™™ ™
PRB Niobrara – Jackalope G&P JV
19
CHK PRB Net Production Potential
Source: Chesapeake Energy Company Presentations.
• PRB Jackalope JV - Crestwood (50%) and Williams (50%) owns 180 MMcf/d gas gathering system and 120 MMcf/d processing plant in Converse Co., Wyoming
• 20-year fixed fee contract; Includes minimum revenue guarantees for 5 – 7 years
• Chesapeake is currently drilling in the Turner, Parkman, Mowry and Sussex formations in addition to Niobrara
− Current gas volumes at >60 MMcf/d up from 46 MMcf/d from FY 2016
− Recent Turner test:
2,886 Boe/d with 51% oil cut
2,560 Boe/d with 80% oil cut
1,700 Boe/d with 80% oil cut
• Potential to grow production to more than 100,000 boe/d over the next five to seven years
Overview
New G&P contract allows Chesapeake to accelerate development plans and achieve full potential of PRB Niobrara acreage
388KDedicated Acres
2,600Drilling Locations
Chesapeake is currently running 3 rigs on the Jackalope system andone dedicated frac crew; expect to add a 4th rig in Q1 2018
CHK Outperforming Industry Offsets
5Productive Zones
Connections for America’s Energy™ ™™ ™™ ™
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Gathe
ring Vo
lumes (M
Mcf/d)• Crestwood & BlueStone have 10-year
agreement
– Fixed-fee and percent of index fee structure for both Natural Gas and NGLs
– Contract structure provides significant upside as commodity prices rebound
• BlueStone brought 7 DUCs online in the first quarter 2017
• Active workover program designed to eliminate system declines and modestly grow volumes
• BlueStone evaluating new development and refrac opportunities
Barnett G&P Update
20
BlueStone’s workover activities and recent DUC completions off-set natural volume declines in 2017; Stable 4% YTD volume decline
Asset Overview Barnett Gathering Volume Growth
Increased volumes combined with fixed-fee/percent of index contract structure drive cash flow outperformance
Natural Gas Prices Since 2016(1)
BlueStone Begins System Reactivation
April 15th: BlueStone Agreement
(1) Source: EIA Henry Hub Natural Gas Spot Price.
1H:17 Workovers Offset Natural Field Decline
Connections for America’s Energy™ ™™ ™™ ™
• 20-year, fixed-fee gathering and compression services w/ Antero Resources
• 140,000 acreage dedication; System capacity of 875 MMcf/d
• 100 MMcf/d compression services on AM gathering in Western Area (90% utilized)
• MVCs through 2018 term; however, all current and future cash flow reflective of actual throughput and rate (no cash flow cliff)
• 21 DUCs brought online in 2017
SW Marcellus G&C Update
21
Gathering volumes up 42% YTD 2017 as Antero completes DUC Inventory
Overview
Highlights• ~275 wells have been connected to Crestwood’s system – No
dry holes
• Avg. 30D IP rate ~8.0 MMcf/d; Avg. EURs between 8–12 Bcf(1)
• 800+ liquid-rich (>1,100 BTU) drilling locations and 1,000+ dry gas drilling locations remain
• Growing NGL processing at the Sherwood plant with increased market takeaway capacity out of the basin
• Multiple large SW Marcellus operators hold acreage positions contiguous to Crestwood’s eastern AOD
East AODWestern Area
Arsenal Resources
EQT
Noble Energy
EQTSWN
(1) Source: Wood Mackenzie.
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Asset Map
Gathering Volumes Since FY 2016
21 DUCs in 2017 increased daily volumes >150 MMcf/d
Well connections in 2017 highlight exceptional reservoir quality and significant upside growth potential with incremental activity
Mcf/d
Connections for America’s Energy™ ™™ ™™ ™ 22
Balance Sheet Strength, Disciplined Capital Allocation, Accretive DCF Growth
Connections for America’s Energy™ ™™ ™™ ™
Delivering on 2017 Guidance
23
EBITDA*
DCF*
Growth Capital*
Leverage
Coverage
Commitment to execution, lower cost structure and consistent quarterly results; delivering on increased 2017 financial guidance
$360 $390 $400$380
$200 $230$210
$130 $150 $250$225
4.0x 4.5x
1.2x 1.4x
Original Guidance Range Increased Guidance Range
*Dollar amounts shown in $US millions.
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Strong Balance Sheet & Liquidity
24
• Top-tier leverage position– Q3 2017 leverage of 4.1x or 3.8x pro forma for
US Salt divestiture– Current borrowing capacity ~$650 MM
• Committed to long-term leverage <4.0x once growth projects come online
• No near-term maturities; attractive long-term capital
• Evaluating divestitures to ensure leverage targets
Balance Sheet Positioned for Strength Current Capitalization
Preferred Equity Overview• Crestwood has ~$650MM preferred equity
outstanding
• Annual distribution of 9.25% payable quarterly
• Crestwood began cash payments attributable to the Q3 2017 distribution
• Preferred equity holders have option to convert 1-for-10 after Q2 2017 (~7.1MM common units) – Investor conversion unlikely and no forced
conversion
Crestwood strengthened its balance sheet by repaying approximately $1 billion of debt in 2Q 2016; Crestwood targets YE 2017 leverage of 4.0x-4.5x
No Near-Term Debt Maturities($MM)
RCF
6.25% Notes
5.75% Notes
Issue Price Yield
2023 104.00 4.9%
2025 103.00 5.1%
Actuals Actuals Actuals Pro Forma($ millions) 2015 2016 Q3 2017 US SALT
Cash $1 $2 $1 $1
Revolver $735 $77 $444 $219
Senior Notes 1,800 1,475 1,200 1,200
Other Debt 9 6 2 2
Total Debt $2,544 $1,558 $1,647 $1,422
Total Leverage Ratio 4.8x 3.7x 4.1x 3.8x
Connections for America’s Energy™ ™™ ™™ ™
The Crestwood Investment Opportunity
25
Focused on aggressively executing growth opportunities while maintaining financial strength
• SELF-FUNDED near-term gathering and processing growth opportunities in the Bakken and Delaware Basin
• Long-term PRB and northeast Marcellus pipeline projects
In the meantime…
• Crestwood is well-positioned to deliver attractive yield to investors(1)
– Current Yield = 9.8%; Coverage Ratio = 1.2x; Leverage Ratio = 3.8x
• Diversified business mix and strong contract portfolio
• No incentive distribution rights
• Assets leveraged to volume growth with commodity price improvement
• Reversion to Peer Group / Alerian yield provides significant upside for units
Execution Drives Significant Upside Return Opportunity;CASH FLOW PER UNIT GROWTH TO RESUME IN 2018
(1) Current yield data as of 12/1/2017. Coverage ratio and leverage ratio as of 9/30/2017 and pro forma for the US Salt divestiture for $225 million.
Connections for America’s Energy™ ™™ ™™ ™
Appendix
2626
Appendix:
Connections for America’s Energy™ ™™ ™™ ™
CEQP Non-GAAP Reconciliations
27
CRESTWOOD EQUITY PARTNERS LP Full Year 2017 Adjusted EBITDA and Distributable Cash Flow Guidance
Reconciliation to Net Income (in millions) (unaudited)
Net income (loss) $(13) - $7 Interest and debt expense, net 105 Loss on modification/extinguishment of debt
38 Depreciation, amortization and accretion 195 Unit-based compensation charges
25 Earnings from unconsolidated affiliates
(50) - (55) Adjusted EBITDA from unconsolidated affiliates
80 - 85
Adjusted EBITDA $380 - $400 Cash interest expense (a) (100) Maintenance capital expenditures (b) (20) - (25) Cash distributions to preferred unitholders (c)
(45)
Distributable cash flow attributable to CEQP common unitholders (d) $210 - $230
(a) Cash interest expense less amortization of deferred financing costs plus bond premium amortization plus or minus fair value adjustments. (b) Maintenance capital expenditures are defined as those capital expenditures which do not increase operating capacity or revenues from existing levels. (c) Includes cash distributions to Crestwood Niobrara preferred unitholders and cash distributions to preferred unitholders. (d) Distributable cash flow is defined as Adjusted EBITDA, less cash interest expense, maintenance capital expenditures, income taxes, deficiency payments
(primarily related to deferred revenue). Distributable cash flow should not be considered an alternative to cash flows from operating activities or any other measure of financial performance calculated in accordance with generally accepted accounting principles as those items are used to measure operating performance, liquidity, or the ability to service debt obligations. We believe that distributable cash flow provides additional information for evaluating our ability to declare and pay distributions to unitholders. Distributable cash flow, as we define it, may not be comparable to distributable cash flow or similarly titled measures used by other corporations and partnerships.