Crestwood Midstream Partners LP
Annual Report 2013

Plain-text annual report

CONNECTIONS FOR AMERICA’S ENERGY CRESTWOOD 2013 ANNUAL REPORT Merger of Crestwood and Inergy creates a new midstream business providing valuable services to producers and consumers of American energy Crestwood’s Competitive Business Strategy is to Connect Supply and Demand Across the Midstream Value Chain SUPPLY Dry Gas Rich Gas, NGL and Crude Dry Gas Gathering Pipelines Rich Gas Gathering Pipelines Crude Gathering Pipelines and Trucks CO2 Treating Intrastate and Interstate Pipelines Gas Storage Intrastate and Interstate Pipelines DEMAND Gas Processing Mixed NGL Pipelines and Trucks NGL Fractionation NGL Storage and NGL Pipelines Crude Storage and Terminals Crude-by- Rail and Pipelines Crude Oil Refining Refined Products Pipelines and Barges •• Current service offerings and/or operational capacity Third party services • Crestwood is Building a Sustainable Midstream Organization Based upon Strategic Pillars CONNECTIONS OPERATIONS EXECUTION INTEGRITY Create Flow Assurance Maximize Value to Customers Deliver on Disciplined Strategy Embody Core Principles Linking supply and demand across midstream value chain Increased visibility for producers to end-users End-to-end solutions for best path to demand centers Scale to complete major infrastructure growth projects Critical midstream infrastructure in premier shale plays and market centers Comprehensive services, leveraging relationships to link supply with demand Expertise in gathering, processing, transportation, storage and logistics Improving customer options through control of product from wellhead to burner tip Best-in-class operations and customer service Focus on operational safety as our top priority Completing infrastructure projects on time, on budget Optimize the asset portfolio through organic projects and acquisition growth Experienced management and dedicated employees focused on creating investor value Responsible care for environmental compliance and sustainability Commitment to communities where we operate and our employees live Valuing relationships with our employees, customers, vendors and the public CRESTWOOD 2013 ANNUAL REPORT PAGE 1 Crestwood connects fundamental energy supply with energy demand across North America through a best-in-class midstream network. Our diversified asset base and integrated services provide flow assurance across the value chain for producers and consumers of natural gas, natural gas liquids and crude oil. Four pillars of our business create value for our customers and country: Connections linking supply and demand; Operations providing critical infrastructure; Execution delivering best-in-class operations and service; Integrity valuing commitment to customers, employees and communities. Pictured: Construction of the Morgan Compressor Station in the Marcellus Shale adds approximately 55 MMcf/d of compression capacity. The facility was placed in service in November 2013. PAGE 2 Connections are at the heart of the new Crestwood. Our operations connect America’s supplies of oil and natural gas from producing fields in places like North Dakota, West Virginia and Texas through world-class gathering, processing, storage and transportation assets to energy demand markets from California to New York. We call this nationwide midstream business strategy … Connections for America’s Energy. Crestwood connects upstream customers including leading exploration and production companies with downstream customers including crude oil refiners, gas utilities, industrial users and wholesalers. Our achievements in 2013 established a new beginning and created a new platform for all of our stakeholders. Investors in our two NYSE-listed partnerships, Crestwood Equity Partners LP (CEQP) and Crestwood Midstream Partners LP (CMLP) are already benefiting from the growth enabled by our larger financial capability, as evidenced by the strategically important Arrow Midstream acquisition, completed immediately after the merger. Legacy Crestwood and Inergy customers see the value in Crestwood’s new, expanded ability to offer a full range of services and solutions for each customer up and down the midstream value chain. Similarly, Crestwood’s approximately 1,200 post-merger employees across the country are discovering new opportunities in an organization committed to operating excellence as defined by our four strategic pillars: connections, operations, execution and integrity. In this report, we want to introduce you to the new Crestwood, explain how we plan to create value – and offer perspectives on why you may want to be part of our story going forward. Connecting with Future Growth The biggest achievement of 2013 – though certainly not the only one – was the transformational combination of two midstream businesses on opposite ends of the midstream value chain, Crestwood and Inergy, to create Robert G. Phillips CHAIRMAN, PRESIDENT AND CHIEF EXECUTIVE OFFICER DEAR FELLOW INVESTORS Following the merger of Crestwood and Inergy in 2013, combined partnerships with an aggregate enterprise Crestwood has emerged as a leader in providing midstream value of approximately $9.0 billion and a diversified base services to support the growth of America’s energy of operations across most of the major shale plays in the independence through our operations in every premier United States. I could not be more pleased with the U.S. shale play. As we enter 2014, Crestwood is uniquely progress we have made since announcing the merger positioned with the scale, resources and relationships to in May 2013, and I appreciate the help of First Reserve, substantially expand our midstream business across the our general partner sponsor, in completing this historic midstream value chain in the years ahead. merger of MLPs. CRESTWOOD 2013 ANNUAL REPORT PAGE 3 CRESTWOOD CORPORATE STRUCTURE First Reserve/ Crestwood Holdings Crestwood Equity Partners LP (NYSE: CEQP) NGL Supply and Logistics and Gas Storage Crestwood Midstream Partners LP (NYSE: CMLP) We wasted no time in 2013, continuing to expand our growth platform even as the merger progressed. Three days after closing the Inergy merger, Crestwood announced the $750 million acquisition of Arrow Midstream, a crude oil, natural gas and produced water gathering system in the Bakken Shale play of North Dakota that links with our nearby COLT Hub crude-by-rail and pipeline terminal. Crestwood now handles approximately 18% of the crude oil produced in the Bakken, making us one of the largest midstream players for crude services in that rapidly growing region. Earlier in the year, we invested approximately $150 million to acquire a strategic position in the Powder River Niobrara Shale play, an emerging rich gas and crude oil growth region in eastern Wyoming. Our 50% stakes in the Jackalope gathering and processing system and the Douglas crude oil rail terminal give Crestwood growing cash flow streams and a presence as an early mover in one of the nation’s most promising “liquids-rich” shale plays. Gathering and Processing Storage and Transportation NGL and Crude Oil Services The integration of the two partnerships into the new Crestwood is now largely complete. Our teams are working together as one organization, sharing past experiences and collectively competing for new business opportunities. Our diverse midstream assets and operations, broad geographic reach, and upstream and downstream connections make a powerful combination. Our customer and contract portfolio provides services to high-quality customers through fixed- fee arrangements providing a unique blend of stable cash flows and high-growth expansion potential in the areas in which we operate. And we are executing on the growth strategy made possible by the new Crestwood’s financial resources, expertise and relationships. Crestwood’s liquids-based growth strategy focuses on providing connections for high-value production of 2013 GROWTH CAPITAL SPENDING, ACQUISITIONS AND INVESTMENTS(1) (in millions) $295 Organic Capital Projects $127 Jackalope Gas Gathering $24 Douglas Crude Rail Terminal $775 Arrow Midstream crude oil and natural gas liquids (NGLs) in America’s shale (1) Includes combined spending of legacy Crestwood and legacy Inergy for the full year 2013. regions. Our operations in the Marcellus, Bakken, Niobrara and other key plays provide great opportunities in crude In addition to the Inergy merger and the acquisitions oil and NGLs. We are well-positioned with long-term completed in 2013, our combined partnerships invested contracts and broad shale play acreage dedications in approximately $295 million last year to expand existing “the core of the core,” the most productive acreage in these assets, mostly build-outs in the prolific Marcellus and growth areas. Our businesses in these regions are profiled Bakken plays. We believe organic growth, balanced with on pages 10-15. bolt-on and synergistic acquisitions, will add valuable CRESTWOOD 2013 ANNUAL REPORT PAGE 4 connections to our midstream network and drive increased Storage and Transportation – strategically located in value for our investors in 2014 and beyond. To finance our the Northeast and Gulf Coast market regions, our safe 2013 acquisitions and expansion projects and our 2014 and environmentally sound storage and pipeline delivery growth capital budget, Crestwood and Inergy collectively facilities provide connections to market and certainty of raised approximately $1.7 billion in new investment capital, supply for customers in growing US demand centers. which provides an excellent financial platform to develop these new growth opportunities. NGL and Crude Services – fully integrated logistics and marketing services move energy for producers, refiners Maximizing Value in the Midstream and downstream customers across the country, including One of Crestwood’s unique advantages is our active pipeline, truck, rail, storage and terminal services. engagement across the midstream value chain – providing assurance of flow from the oil and gas supply at the Spanning the value chain adds value for producers wellhead, through the most logistically efficient path and energy users, enabling us to leverage relationships possible, to the burner tip at our customers’ locations coast and offer additional midstream services to customers. For to coast. These diverse operations allow us to provide example, Crestwood’s Arrow crude oil gathering operations multiple customer services, engage in larger infrastructure in the Bakken connect producers, via our nearby COLT Hub projects, and provide our investors with stable cash flows crude-by-rail terminal, with efficient transportation to our and visible growth opportunities. refinery customers on the West Coast or East Coast, taking Crestwood operations fit into three midstream segments: imported crude supplies. Similarly, a customer anywhere in advantage of price differentials between domestic and 2013 EBITDA MIX(1) By segment 29% Storage and Transportation 38% Gathering and Processing 33% NGL and Crude Services (1) Includes combined contribution of legacy Crestwood, legacy Inergy and Arrow Midstream for the full year 2013 without pro forma adjustments required by GAAP. the country can locate energy supplies that make the most sense – and use Crestwood’s logistical expertise to find the best path for that energy to flow. The operational balance of Crestwood’s business is matched by the geographic diversity of our nationwide footprint. We have a presence in the leading unconventional shale plays in North America, including the Marcellus, Bakken, Niobrara, Barnett, Fayetteville, Haynesville and old resource areas that are being redeveloped such as the Permian Basin and Granite Wash. Our storage and transportation facilities in Pennsylvania and New York connect growing Marcellus dry gas supplies with a strong network of utility, industrial and wholesale customers throughout the Northeast. Growing in the Core of the Core Crestwood’s liquids-focused growth strategy has guided our strategic investment decisions in the past few years as high-valued rich natural gas and crude oil areas have benefited from superior production economics, which ultimately drive development activity and infrastructure requirements. As important as being in the right shale Gathering and Processing – starting at the wellhead, our plays and contracting with the right producers, Crestwood extensive gathering and processing systems connect has successfully acquired long-term contracts to provide upstream supplies in the largest and most active midstream services in the best areas of each shale play, which unconventional resource plays in North America to we call “core of the core” production. These long-term acreage downstream pipelines. dedications in core of the core areas ensure that producers will CRESTWOOD 2013 ANNUAL REPORT PAGE 5 continue to actively develop new energy supplies and utilize Engaging You in Our Story our pipelines, plants, trucks and terminals for many years in We believe Crestwood can create significant value going the future. forward, beginning with the top-quality assets and world- While many of our service contracts include take-or-pay, class team of people we have assembled. As we have fixed-fee and minimum-volume commitment features that created this exciting new venture for the future, we are do give some downside protection on investment returns, defining “who we are” by four strategic pillars: it is our disciplined selection of core of the core areas that provides visibility to long-term growth. We provide more Connections – to create flow assurance across the value chain detail on pages 8-9 on our strategic location of assets in the Operations – to maximize value for customers with best places. midstream services In the near term, distribution growth at Crestwood Execution – to deliver on a disciplined strategy for building will be driven by increased volumes in the rapidly growing value for our unitholders production areas of the Marcellus, Bakken and Niobrara Integrity – to embody the core principles of safety, plays and expansion of our nationwide NGL logistics and environmental responsibility, and commitment to our crude services businesses. Looking forward, we have employees and communities identified approximately $1.2 billion of expansion projects in and around our existing assets or in the areas where Crestwood’s size, scale and financial strength position us we operate. This build-out, detailed on page 7, will take well to deliver attractive returns going forward. Our liquids- place over several years and highlights another benefit focused strategy, organic project backlog and commitment of the merger. 2014-2018 GROWTH CAPITAL SPENDING PROJECTION (in millions) $80 COLT Hub Expansion $100 Arrow Midstream $150 Other $375 Marcellus Gathering and Compression to execute growth projects on-time and on-budget supports our outlook for increasing cash distributions to unitholders of both Crestwood Midstream Partners and Crestwood Equity Partners. Finally, I want to offer my personal thanks to you – to all of the unitholders of both MLPs, as well as to each of Crestwood’s nearly 1,200 employees across the country. Your support made possible our transformation in 2013 – and is vital in delivering on the great potential of the new Crestwood. $240 Jackalope $250 NE Marcellus Transportation Expansion Robert G. Phillips Chairman, President and Chief Executive Officer March 7, 2014 Our approach to growth is balanced. We expect to continue to make acquisitions – especially bolt-on expansions in the vicinity of our current high-value assets – where we see promise for attractive returns. CRESTWOOD 2013 ANNUAL REPORT PAGE 6 CRESTWOOD 2013 ANNUAL REPORT SIGNIFICANT ORGANIC GROWTH OPPORTUNITY Crestwood has committed more than $1.2 billion to organic growth projects from 2014-2018. Most of this investment will expand Crestwood’s capacity in our connections serving the liquids-rich growth areas of the Bakken, Marcellus and Niobrara producing regions. About $150 million of the total will add revenue- enhancing projects to existing assets in other regions. $1.2B Identified and contracted expansion projects CRESTWOOD 2013 ANNUAL REPORT PAGE 7 Pictured: The Bakken Shale, located in North Dakota, is a growing source of new domestic crude oil supplies for the United States. Through Crestwood’s Arrow oil gathering system and COLT crude-by-rail terminal, we are helping our producers get their new supplies to market. BAKKEN REGION MARCELLUS REGION NIOBRARA REGION JACKALOPE Construction of expanding rich gas gathering system and 120 MMcf/d processing plant for RKI and Chesapeake in PRB Niobrara Timeline: 2014 – 2016 Capex ($MM): $240 COLT HUB EXPANSION Ongoing 40,000 Bbl/d expansion completed in 1H 2014 and additional future expansion of COLT Hub facility MARCELLUS GATHERING AND COMPRESSION Pipeline and compression expansion for Antero Resources in rich gas window of SW Marcellus Shale core Timeline: 2014 – 2016 Capex ($MM): $80 ARROW MIDSTREAM Continued build-out of Bakken crude oil, water, and natural gas gathering system for WPX, QEP, Halcon, XTO and Kodiak Timeline: 2014 - 2018 Capex ($MM): $100 Timeline: 2014 – 2018 Capex ($MM): $375 NE MARCELLUS TRANSPORTATION EXPANSION Additional takeaway capacity in NE Pennsylvania with direct connectivity to North-South and MARC I pipelines to bring growing Marcellus dry gas supplies to market Timeline: 2015 – 2016 Capex ($MM): $250 Pictured: Crestwood operates a fleet of 557 truck units providing connectivity between our facilities and our customers’ facilities allowing more efficient and safe distribution of multiple crude and NGL products. PAGE 8 DIVERSIFIED U.S. MIDSTREAM PORTFOLIO HILLIARD-BAXTER- MANCOS MANCOS HERMOSA LEWIS MONTEREY-TEMBLOR NGL Transportation Office 13 West Coast Midstream MONTEREY Gathering and Processing NGL and Crude Services Storage and Transportation Basin Areas Areas of Operation COLC COLT Hubb LT OLT ubHu CO Hub T H 9 8 rowwAr owrroA Arrow Mw M w Midstream GAMMON BAKKEN SHALE MOWRY 9 6 Douglas Rail Jackalope Gathering PRB NIOBRARA SHALE U.S. Salt Sene neca Lake Watkitkins Glenenenenneneneenele 12 15 BaththBa hBatB 10 15 10 Thomas Corn TThThh rnenersneerssrseeeneee 15 Steteubeuben eububen e ben uueeubeu 16 15 North-Soh-S Noort -S rthNoN outh S Stagecoa Stagec tagSt age ec S chachch c MARC IRCM MARC I ARMA I 16 NGL Transportation GL TGL T NGNNG UTICA 7 OfficeOfOfOOO 11 South Jersey Terminal Marcellus Gathering ANTRIM NGL Transportation Office Seymour Terminal EXCELLO-MULKY Executive Office NEW ALBANY 11 DEVONIAN PIERRE Granite Wash Gathering and Processing 4 WOODFORD GRANITE WASH Fayetteville Gathering 3 CONASAUGA FAYETTEVILLE SHALE MARCELLUS SHALE Avalon Gathering 1 BARNETT- WOODFORD Barnett Gathering and Processing 2 5 Operations Office Haynesville Gathering BARNETT SHALE EAGLE FORD HAYNESVILLE AND BOSSIER SHALE AVALON SHALE AND BONE SPRING Headquarters 14 Tres Palacios 8,000 Bbl/d isomerization plant 160,000 Bbl/d rail loading capacity 955 MMcf/d gathering capacity WEST COAST MIDSTREAM COLT HUB BARNETT SHALE CRESTWOOD 2013 ANNUAL REPORTCOLT Hubb CO Hub OLT ubHu COLC T H LT 9 8 Arrow rowwAr owrroA w Midstream Mw M GAMMON BAKKEN SHALE MOWRY 9 6 Douglas Rail Jackalope Gathering PRB NIOBRARA SHALE HILLIARD-BAXTER- MANCOS MANCOS HERMOSA LEWIS MONTEREY-TEMBLOR NGL Transportation Office 13 West Coast Midstream MONTEREY Watkitkins Glenenenenneneneenele BaththBa hBatB 10 U.S. Salt 12 15 Sene neca Lake TThThh Thomas Corn rnenersneerssrseeeneee 15 uueeubeu Steteubeuben e ben eububen UTICA 7 ANTRIM NGL Transportation Office Seymour Terminal 15 10 16 15 S Noort -S rthNoN North-Soh-S outh c ec tagSt Stagecoa Stagec S age chachch ARMA MARC IRCM MARC I I 16 NGNNG GL TGL T NGL Transportation OfficeOfOfOOO 11 South Jersey Terminal Marcellus Gathering EXCELLO-MULKY Executive Office NEW ALBANY 11 DEVONIAN MARCELLUS SHALE PIERRE Granite Wash Gathering and Processing 4 WOODFORD GRANITE WASH CONASAUGA FAYETTEVILLE SHALE Fayetteville Gathering 3 Haynesville Gathering Avalon Gathering 1 BARNETT- WOODFORD Barnett Gathering and Processing 2 5 Operations Office BARNETT SHALE EAGLE FORD HAYNESVILLE AND BOSSIER SHALE AVALON SHALE AND BONE SPRING Headquarters 14 Tres Palacios 26.2 Bcf Working gas storage capacity STAGECOACH GAS STORAGE PAGE 9 GATHERING AND PROCESSING 4. GRANITE WASH GATHERING AND PROCESSING • 22,000+ acres with approx. 30-40% developed • 36 miles of gas gathering pipeline • 36 MMcf/d gathering and processing capacity • 10-13 year contracts 1. AVALON GATHERING • 55,000 acres to be redeveloped as rich gas play • 49 miles of low pressure gas gathering pipeline • 50 MMcf/d gathering capacity • 5 year contracts 5. HAYNESVILLE GATHERING • 22,000+ acres with less than 20% developed • 57 miles of low pressure gas gathering pipeline • 100 MMcf/d gathering capacity • 5-10 year contracts 2. BARNETT GATHERING AND PROCESSING • 140,000+ acres with approx. 60% developed • 491 miles of gas gathering pipeline • 955 MMcf/d gathering capacity • 425 MMcf/d processing capacity • 10-20 year contracts 3. FAYETTEVILLE GATHERING • 143,000+ acres with 10-20% developed • 171 miles of low pressure gas gathering pipeline • 510 MMcf/d gathering capacity • 15 year contracts 6. JACKALOPE GATHERING • 311,000 acres area of mutual interest with less than 5% developed • 146 miles of gas gathering pipeline • 20-year 15% cost-of-service contracts • Crestwood owns 50% interest 7. MARCELLUS GATHERING • 140,000+ acres with 5-10% developed • 65 miles of low-pressure gas gathering systems • 605 MMcf/d gathering capacity • 82,340 HP of compression • 20 year contracts NGL AND CRUDE SERVICES 8. ARROW MIDSTREAM • 488 miles of gathering pipeline, including 153 miles for crude oil, 171 miles for natural gas and 164 miles for water gathering 11. NGL TERMINAL FACILITIES • 0.5 MMBbl of NGL storage • Connections to Teppco and ATEX pipelines • Truck terminal facilities • Rail terminal with onsite bullet storage • Critical supply point for Marcellus/Utica-sourced LPG in high-demand Northeast market 12. U.S. SALT • Industry-leading solution mining and salt • Over 150,000 acres dedicated to Arrow systems production company 9. CRUDE OIL LOADING FACILITIES • 160,000 Bbl/d rail loading capacity in Bakken • Ability to handle up to 120-car unit trains • 960,000 Bbl crude oil storage capacity • Early-stage rail terminal in Niobrara 10. NGL STORAGE FACILITIES • 1.7 MMBbl of NGL underground storage with another 2.1 MMBbl under development • Additional development opportunities for gas or LPG storage facilities 13. WEST COAST MIDSTREAM • Strategically located near Bakersfield, CA, between major West Coast refining centers • 12,000 Bbl/d fractionation, 8,000 Bbl/d butane isomerization • 24 million gallons of NGL storage capacity • State-of-the-art rail & truck transport terminals • Additional development opportunities for gas or • 70-unit transport fleet LPG storage facilities • Rail and truck terminal facilities STORAGE AND TRANSPORTATION 14. TRES PALACIOS • 38.4 Bcf of capacity • 2.5 Bcf/d (max) withdrawal • 1.0 Bcf/d (max) injection • Connected to 10 intrastate and interstate pipelines • Market-based rate structure 15. NORTHEAST STORAGE • 4 gas storage facilities totaling 41 Bcf of capacity • 845 MMcf/d (max) withdrawal • 423 MMcf/d (max) injection 16. NORTHEAST PIPELINES • 985 MMcf/d firm pipeline transportation capacity • Market-based rate structures CRESTWOOD 2013 ANNUAL REPORTPAGE 10 CRESTWOOD 2013 ANNUAL REPORT CORE OF THE CORE BAKKEN COLT HUB RAIL TERMINAL ARROW MIDSTREAM 160,000 Bbl/d rail loading capacity 488 miles of gathering pipeline Leading rail facility for crude in the Bakken Shale, connecting premier East and West Coast refiners with Bakken supply Unit trains up to 120 cars 960,000 Bbl crude oil storage (expanding to 1.2 million Bbl) 21-mile bi-directional pipeline connecting to Crestwood’s Dry Fork terminal, tying in with four major pipelines Located in Epping, North Dakota, sourcing production via trucks, pipelines and gathering system interconnects Connectivity with Crestwood’s Arrow crude gathering system Serving producers in the core of the Bakken under long-term gathering contracts Gathering system includes 153 miles of crude oil lines, 171 miles of natural gas lines and 164 miles of water lines Over 150,000 acres dedicated to Arrow, including more than 1,000 potential drilling locations Expansion projects to increase gathering capacities to 125,000 Bbl/d of crude oil, 100 MMcf/d of natural gas and 40,000 Bbl/d of produced water by 2015 23-acre central delivery point for crude oil, natural gas and production water, with fully automated truck loading and crude storage Direct connectivity between Arrow and COLT Hub provides improved pricing and sales optionality for Bakken producers and access to new wellhead supplies for COLT customers CRESTWOOD 2013 ANNUAL REPORT PAGE 11 Pictured: Crude Logistics employees watch over train cars after they are loaded with roughly 680 barrels of crude oil at COLT Hub. ND TES O R O ENBRIDGE B NS F MAI N LI NE BEAVER LODGE COLT TERMINAL COLT CONNECTOR DRY FORK TERMINAL TES OR O ARROW SYSTEM ARROW ACREAGE PAGE 12 CRESTWOOD 2013 ANNUAL REPORT CORE OF THE CORE MARCELLUS NORTHEAST STORAGE AND TRANSPORTATION MARCELLUS GATHERING 41 Billion cubic feet of gas storage 140,000 dedicated acres Highly flexible, premier storage and transportation platform between Marcellus production and major Northeast U.S. cities Located in upstate New York and northeast Pennsylvania Four natural gas storage centers with 41 Bcf of capacity Three gas pipelines offer total capacity of 985 MMcf/d and interconnects to major markets Fully subscribed with long-term producer and customer contracts Buffering supply-demand imbalances for utilities and industries in New York, New Jersey and New England markets Growing pipeline and gas compression operation in the highly productive West Virginia core of the Marcellus Shale 65 miles of gathering pipeline and 82,340 MMcf/d of compression capacity at year- end 2013; additional build-out underway 20-year 100% fixed-fee contract with Antero Resources, the Marcellus region’s most active driller, with 15 active drilling rigs in West Virginia Serving 140,000 dedicated acres in Antero’s eastern area, with committed minimum volumes and annual escalators 7-year right of first offer on gathering system development to serve Antero’s approx. 200,000-acre western area of dedication Antero’s development plans are driving significant system growth for Crestwood in 2014 CRESTWOOD 2013 ANNUAL REPORT PAGE 13 Pictured: Pipeline construction in Doddridge County, WV supports the expanding gas gathering for Antero’s active development within the Marcellus Shale. WV WESTERN AREA EAST AOD Greenbrier Area Existing pipeline CMLP compressor stations 2014-2016 planned build out 3rd party compressor stations 3rd party takeaway MWE Sherwood Plant Victoria WESTERN AREA West Union MWE Sherwood Plant EAST AOD Greenbrier Area Existing pipeline CMM Compressor stations 2014-2016 Planned build out 3rd party comp stations 3rd party takeaway NY T E M P I R E S S E N N E E E D O M I N I O N N A T I O N A L F U E L BA SL WG TC ST D O MINIO N CRESTWOOD PIPELINE EAST M I L L E N N I U M SC N Y P A NORTH-SOUTH PIPELINE TENNESSEE MARC I PIPELINE T R A N S C O LEIDY HUB ST Steuben Gas Storage WG Watkins Glen NGL Storage TC Thomas Corners Gas Storage SL Seneca Lake Gas Storage BA Bath NGL Storage SC Stagecoach Gas Storage PAGE 14 CRESTWOOD 2013 ANNUAL REPORT CORE OF THE CORE NIOBRARA DOUGLAS CRUDE RAIL TERMINAL 20,000 Bbl/d rail loading capacity Newly constructed crude oil terminal placed in service in August 2013, being expanded to 20,000 Bbl/d capacity to load unit trains in 2014 Rapidly expanding storage and loading capacities Located near Douglas, Wyoming, to serve emerging crude and rich gas production in Niobrara region of Powder River Basin Crestwood owns 50% interest in Douglas terminal, a start-up similar to COLT Hub in the Bakken Anchored by long-term contracts, plus fee-based acreage dedication Early-mover advantage for Crestwood in Niobrara play JACKALOPE GATHERING 146 miles of gathering pipeline Rich gas gathering and processing system serving premier producers in the emerging Niobrara Shale of the Powder River Basin Located in Converse County, Wyoming, where rapidly growing production is held back by the need for midstream capacity Developing Jackalope to gather and process rich gas from 311,000 dedicated acres under development by producers Chesapeake and RKI Initial system consisting of 146 miles of gathering pipelines and 15,600 HP of compression equipment, with expansion underway in 2014 80 wells connected to system as of year-end 2013 Building a 120 MMcf/d processing plant Supported by 20-year gathering and processing agreements with Chesapeake and RKI, with cost-of-service based fees and annual redeterminations Positions Crestwood strategically in one of America’s promising new shale oil and gas plays CRESTWOOD 2013 ANNUAL REPORT PAGE 15 Pictured: Drilling rigs operated by Chesapeake and RKI are supported by development of the Jackalope gathering and processing facilities in the emerging Niobrara Shale. CHK/RKI Leasehold CHK Operated Rigs Industry Rigs Non-operated Rigs NIOBRARA WY CAMPBELL CONVERSE Jackalope AMI Douglas Facility DOUGLAS FACILITY PAGE 16 CRESTWOOD 2013 ANNUAL REPORT CRESTWOOD CONNECTS TO THE FUTURE The new Crestwood is actively contributing to America’s emerging energy independence. After creating a diversified mid cap partnership through transformational actions in 2013, Crestwood is driving growth through a disciplined balance of organic expansion and asset acquisitions. Building on stable cash flows from top-quality midstream operations, our strategy focuses on services across the value chain for natural gas, crude oil and natural gas liquids. Crestwood has committed $1.2 billion to near-term organic growth projects – new connections for America’s energy. A copy of Crestwood Equity Partners LP and Crestwood Midstream Partners LP Annual Reports on Form 10-K can be found in the Investor Relations section of our website at www.crestwoodlp.com or contact us at investorrelations@crestwoodlp.com or 832.519.2200. Table of ContentsUNITED STATESSECURITIES AND EXCHANGE COMMISSIONWASHINGTON, D.C. 20549 FORM 10-KANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACTOF 1934 For the fiscal year ended December 31, 2013OR¨TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGEACT OF 1934 For the transition period from to .COMMISSION FILE NUMBER: 001-34664Crestwood Equity Partners LP(Exact name of registrant as specified in its charter)Delaware 43-1918951(State or other jurisdiction ofincorporation or organization) (IRS EmployerIdentification No.) 700 Louisiana Street, Suite 2060Houston, Texas 77002(Address of principal executive offices) (Zip code)(832) 519-2200(Registrant’s telephone number, including area code)Inergy, L.P.Two Brush Creek Blvd., Suite 200Kansas City, Missouri, 64112September 30(Former name)(Former address)(Former fiscal year) SECURITIES REGISTERED PURSUANT TO SECTION 12(b) OF THE ACT:Title of Each Class Name of Each Exchange on Which RegisteredCommon Units representing limited partnership interests The New York Stock ExchangeSECURITIES REGISTERED PURSUANT TO SECTION 12(g) OF THE ACT: NoneIndicate by check mark if registrant is a well-known seasoned issuer, as defined by Rule 405 of the Securities Act. Yes x No ¨Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or 15(d) of the Act. Yes ¨ No xIndicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 duringthe preceding 12 months (or for such shorter period that the registrant was required to file such reports) and (2) has been subject to such filing requirementsfor the past 90 days. Yes x No ¨Indicate by check mark whether the registrant has submitted electronically and posted on its corporate website, if any, every Interactive Data File required to besubmitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that theregistrant was required to submit and post such files). Yes x No ¨Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein and will not be contained, to the bestof registrant’s knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form10-K. xTable of ContentsIndicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer or a smaller reporting company. Seedefinitions of “large accelerated filer”, “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.Large accelerated filer x Accelerated filer ¨ Non-accelerated filer ¨ (Do not check if a smaller reporting company) Smaller reporting company ¨Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ¨ No xThe aggregate market value of the 110,283,259 common units of the registrant held by non-affiliates computed by reference to the $12.72 closing price ofsuch common units on February 14, 2014, was $1.4 billion. As of June 28, 2013, the last business day of the registrant's most recently completed secondquarter, the aggregate market value of the registrant's common units held by non-affiliates of the registrant was $1.8 billion based on a closing price of $16.02per common unit as reported on the New York Stock Exchange on such date. As of February 14, 2014, the registrant had 186,429,575 common unitsoutstanding. DOCUMENTS INCORPORATED BY REFERENCEPortions of the following documents are incorporated by reference into the indicated parts of this report: None.Table of ContentsCRESTWOOD EQUITY PARTNERS LP (FORMERLY INERGY, L.P.)INDEX TO ANNUAL REPORT ON FORM 10-K Page PART I Item 1.Business6 Item 1A.Risk Factors23 Item 1B.Unresolved Staff Comments42 Item 2.Properties42 Item 3.Legal Proceedings42 Item 4.Mine Safety Disclosures42 PART II Item 5.Market for the Registrant’s Common Equity, Related Unitholder Matters and Issuer Purchases of Equity Securities43 Item 6.Selected Financial Data44 Item 7.Management’s Discussion and Analysis of Financial Condition and Results of Operations48 Item 7A.Quantitative and Qualitative Disclosures about Market Risk64 Item 8.Financial Statements and Supplementary Data66 Item 9.Changes in and Disagreements with Accountants on Accounting and Financial Disclosure66 Item 9A.Controls and Procedures66 Item 9B.Other Information67 PART III Item 10.Directors, Executive Officers and Corporate Governance68 Item 11.Executive Compensation73 Item 12.Security Ownership of Certain Beneficial Owners and Management and Related Unitholder Matters90 Item 13.Certain Relationships, Related Transactions and Director Independence92 Item 14.Principal Accountant Fees and Services95 PART IV Item 15.Exhibits and Financial Statement Schedules973Table of ContentsGLOSSARYThe terms below are common to our industry and used throughout this report./dper dayAODArea of dedication, which means the acreage dedicated to a company by an oil and/or natural gas producer under oneor more contracts.Barrel (Bbl)One barrel of petroleum products equal to 42 U.S. gallons.Base gasA quantity of natural gas held within the confines of the natural gas storage facility and used for pressure supportand to maintain a minimum facility pressure. May consist of injected base gas or native base gas. Also known ascushion gas.BcfOne billion cubic feet of natural gas. A standard volume measure of natural gas products.CycleA complete withdrawal and injection of working gas. Cycling refers to the process of completing one cycle.DthOne dekatherm of natural gas.EPAEnvironmental Protection Agency.FASBFinancial Accounting Standards Board.FERCFederal Energy Regulatory Commission.Firm serviceServices pursuant to which customers receive an assured or firm right to (i) in the context of storage service, storeproduct in the storage facility or (ii) in the context of transportation service, transport product through a pipeline,over a defined period of time.GAAPGenerally Accepted Accounting Principles.Gas storage capacityThe maximum volume of natural gas that can be cost-effectively injected into a storage facility and extracted duringthe normal operation of the storage facility. Gas storage capacity excludes base gas.G&PGathering and processing.HubGeographic location of a storage facility and multiple pipeline interconnections.Hub servicesWith respect to our natural gas storage and transportation operations, the following services: (i) interruptible storageservices, (ii) firm and interruptible park and loan services, (iii) interruptible wheeling services, and (iv) balancingservices.Injection rateThe rate at which a customer is permitted to inject natural gas into a natural gas storage facility.Interruptible serviceServices pursuant to which customers receive only limited assurances regarding the availability of (i) with respect tostorage services, capacity and deliverability in storage facilities or (ii) with respect to transportation services,capacity and deliverability from receipt points to delivery points. Customers pay fees for interruptible services basedon their actual utilization of the storage or transportation assets.LIBORLondon Interbank Offered Rate.McfOne thousand cubic feet of natural gas. We have converted throughput numbers from a heating value number to avolumetric number based upon a conversion factor of 1 MMbtu equals 1 Mcf.MMbtuOne million British thermal units, which is approximately equal to one Mcf. One British thermal unit is equivalentto an amount of heat required to raise the temperature of one pound of water by one degree.MMcfOne million cubic feet of natural gas.Natural gasA gaseous mixture of hydrocarbon compounds, primarily methane together with varying quantities of ethane,propane, butane and other gases.Natural Gas ActFederal law enacted in 1938 that established the FERC's authority to regulate interstate pipelines.Natural gas liquids (NGLs)Those hydrocarbons in natural gas that are separated from the natural gas as liquids through the process ofabsorption, condensation, adsorption or other methods in natural gas processing or cycling plants. NGLs includenatural gas plant liquids (primarily ethane, propane, butane and isobutane) and lease condensate (primarilypentanes produced from natural gas at lease separators and field facilities).NYSENew York Stock Exchange.Salt cavernA man-made cavern developed in a salt dome or salt beds by leaching or mining of the salt.4Table of ContentsSECSecurities and Exchange Commission.WheelingThe transportation of natural gas from one pipeline to another pipeline through the pipeline facilities of a natural gasstorage facility. The gas does not flow into or out of actual storage, but merely uses the surface facilities of thestorage operation.Withdrawal rateThe rate at which a customer is permitted to withdraw gas from a natural gas storage facility.Working gasNatural gas in a storage facility in excess of base gas. Working gas may or may not be completely withdrawn duringany particular withdrawal season.Working gas storage capacitySee gas storage capacity (above).5Table of ContentsPART IItem 1. Business.Unless the context requires otherwise, references to (i) “we,” “us,” “our,” “our company,” the “Company,” “Crestwood Equity,” and like terms refer toCrestwood Equity Partners LP and its consolidated subsidiaries, (ii) “Crestwood Midstream” refers to Crestwood Midstream Partners LP and its consolidatedsubsidiaries following the Crestwood Merger (defined below), (iii) “Legacy Inergy” refers to Inergy, L.P. and its consolidated subsidiaries prior to theCrestwood Merger, (iii) “Inergy Midstream” refers to Inergy Midstream, L.P. and its consolidated subsidiaries prior to the Crestwood Merger, and (iv) “LegacyCrestwood” refers to Crestwood Midstream Partners LP and its consolidated subsidiaries prior to the Crestwood Merger. Unless otherwise indicated,information contained herein is reported as of December 31, 2013.As explained below and in Part IV, Item 15, Exhibits and Financial Statement Schedules, Notes 1 and 2, our acquisition of the Legacy Crestwood’s generalpartner in June 2013 was accounted for as a reverse acquisition under the purchase method of accounting. The general partner of Legacy Crestwood,Crestwood Gas Services GP, LLC (“Legacy Crestwood GP”), is therefore treated as the acquirer for accounting purposes, whereas we acquired LegacyCrestwood GP for legal purposes. Notwithstanding this distinction, references in this Part I to “we,” “us,” “our,” “our company,” the “Company,” and“Crestwood Equity” refer to the combined operations of Legacy Crestwood GP and the Company unless the context requires otherwise.IntroductionCrestwood Equity, a Delaware limited partnership formed in March 2001, is a master limited partnership (“MLP”) that develops, acquires, owns or controls,and operates primarily fee-based assets and operations within the energy midstream sector. Headquartered in Houston, Texas, we provide broad-ranginginfrastructure solutions across the value chain to service premier liquids-rich and crude oil shale plays across the United States. Our common unitsrepresenting limited partner interests are listed on the NYSE under the symbol “CEQP”.We own and operate a diversified portfolio of crude oil and natural gas gathering, processing, storage and transportation assets that connect fundamentalenergy supply with energy demand across North America. Our consolidated operating assets include:•natural gas facilities with approximately 2.5 Bcf/d of gathering capacity, 471 MMcf/d of processing capacity,1.0 Bcf/d of firm transmission capacity, and 79.4 Bcf of working gas storage capacity;•NGL facilities with approximately 24,000 Bbls/d of fractionation capacity and 2.8 million barrels of storage capacity;•crude oil facilities with approximately 100,000 Bbls/d of gathering capacity, 960,000 barrels of storage capacity, and 120,000 Bbls/d of railloading capacity; and•7 truck and rail terminals and a transportation fleet of approximately 557 truck/trailer units and 1,071 rail units that can transport more than330,000 Bbls/d of NGLs for our proprietary supply and logistics business.Our primary business objective is to increase the cash distributions that we pay to our unitholders. We have worked to position Crestwood Midstream as agrowth MLP through which we will expand our midstream platform and to reposition the Company as more of a “pure play” general partner than an operatingcompany, and we expect to continue this strategy going forward. We therefore expect to increase cash available for distribution to our unitholders primarilythrough our investment in Crestwood Midstream and, to a lesser extent, through growth opportunities involving the assets owned by us. We anticipate that thecontribution of our remaining operating assets into Crestwood Midstream will enhance our value based on our ownership interests in Crestwood Midstream(including our ownership of its incentive distribution rights), and we expect to consummate such drop downs at an appropriate time in the future.6Table of ContentsOwnership StructureThe diagram below reflects a simplified version of our ownership structure as of December 31, 2013:7Table of ContentsOur non-economic general partner interest is held by Crestwood Equity GP LLC, which we refer to as our “general partner” and which is indirectly owned byCrestwood Holdings LLC (“Crestwood Holdings”). Crestwood Holdings, which is substantially owned and controlled by First Reserve Management, L.P.(“First Reserve”), also owns 100% of our incentive distribution rights (“IDRs”) and approximately 29% of our limited partner units as of December 31, 2013.We own the non-economic general partner interest of Crestwood Midstream and, therefore, control Crestwood Midstream. We also own 100% of the IDRs andapproximately 4% of the common units representing limited partnership interests of Crestwood Midstream as of December 31, 2013.In May 2013, the former owners of our general partner and Crestwood Holdings entered into a series of transactions that would effectively consolidate andcombine the operations of Legacy Crestwood and Inergy Midstream. The parties first completed a series of “upstairs” transactions in June 2013 that resulted inCrestwood Holdings’ acquisition of control of us, and our legal acquisition of Legacy Crestwood GP, on June 19, 2013. The strategic business combinationwas completed in October 2013 when Legacy Crestwood merged with and into Inergy Midstream (the “Crestwood Merger”) and Inergy Midstream changed itsname to Crestwood Midstream Partners LP. Contemporaneously with the Crestwood Merger, we changed our name from Inergy, L.P. to Crestwood EquityPartners LP and changed our NYSE listing symbol from “NRGY” to “CEQP.” See Part IV, Item 15, Exhibits and Financial Statement Schedules, Notes 1and 2 for additional information on these related transactions.Our AssetsWe, through our wholly-owned subsidiaries, own and operate a proprietary NGL and crude oil supply and logistics business, a West Coast NGL business,and the Tres Palacios natural gas storage facility. All of our other consolidated assets are owned by or through Crestwood Midstream.We have three reporting segments: (i) gathering and processing, (ii) NGL and crude services, and (iii) storage and transportation.Gathering and ProcessingWe provide natural gas gathering, processing, treating and compression services to producers in unconventional shale plays located in West Virginia,Wyoming, Texas, Arkansas, New Mexico, and Louisiana. We own rich gas systems in the Marcellus, Powder River Basin (“PRB”) Niobrara, Barnett,Granite Wash, and Avalon/Bone Spring Shale plays, and dry gas gathering systems in the Barnett, Fayetteville and Haynesville/Bossier Shale plays.8Table of ContentsThe table below summarizes certain information about our gathering and processing systems as of December 31, 2013:Shale Play(State)Counties / ParishesPipeline(Miles)GatheringCapacity(MMcf/d)AverageGatheringVolume (MMcf/d)Compression(HP)Number of In-ServiceProcessing PlantsProcessingCapacity(MMcf/d)Gross AcreageDedicationMarcellusWest VirginiaHarrison, Barbour andDoddridge6560542082,340——140,000PRB Niobrara(1)WyomingConverse146604515,600——311,000BarnettTexasHood, Somervell, Johnson,Tarrant, and Denton491955429153,4652425140,000FayettevilleArkansasConway, Faulkner, VanBuren, and White1715109827,645——143,000Granite WashTexasRoberts36362112,24013622,000Haynesville / BossierLouisianaSabine5710022———22,000Avalon / Bone SpringNew MexicoEddy49501095511055,000Total 1,0152,3161,045292,2454471833,000(1)Our PRB Niobrara assets are owned by Jackalope Gas Gathering Services, L.L.C., our 50% owned equity-method investment. The average gathering volumes represent theaverage volumes for the period of acquisition (July 19, 2013) to December 31, 2013.We generate G&P revenues predominantly under fee-based contracts, which minimizes our commodity price exposure and provides less volatile operatingperformance and cash flows. Our principal G&P systems are described below.MarcellusWe own and operate rich gas systems in Harrison and Doddridge Counties, West Virginia and a dry gas system in Barbour County, West Virginia. Thesesystems consist of 65 miles of low pressure gathering lines and seven compression and dehydrations stations with 82,340 horsepower. Our current operationsare predominantly focused on our rich gas systems. On these systems, we provide midstream services to Antero Resources (“Antero”), which is the mostactive upstream developer of the rich gas corridor of the southwestern core of the Marcellus Shale play. We provide our services under long-term, fixed-feecontracts across two operating areas, our eastern area of operation (“East AOD”) and our western area of operation (“Western Area”).In the East AOD, we provide gathering, dehydration and compression services to Antero in an approximately 140,000 gross acre area from which Antero hasdedicated all production of rich natural gas to our system pursuant to a 20-year, fixed-fee gathering and compression agreement. As a part of that agreement,we gather and deliver Antero’s production to MarkWest Energy Partners’ Sherwood Gas Processing Plant and various regional pipeline systems. Antero hasprovided minimum volume commitments under our agreement, which increase from an average of 400 MMcf/d in 2014 up to an average of 450 MMcf/d in2016, 2017 and 2018, respectively. Our system is currently connected to 173 wells and current average daily volumes delivered to our system have increasedby over 180% from when we acquired the assets in 2012.In the Western Area, we provide compression and dehydration services to Antero’s gathering facilities predominantly with our West Union and Victoriacompressor stations. We provide services to Antero under a five year, fixed-fee agreement that runs through 2018, subject to Antero’s right to extend thecontract term for an additional five years. Although volumes compressed from these stations are not contractually dedicated to us in the Western Area, Anterodoes provide minimum volume commitments up to 50% of the throughput capacity of each compressor station. We also hold a right of first offer until 2019 toacquire and develop any midstream facilities developed by Antero in the Western Area for ultimate transfer or sale to a third party.9Table of ContentsWe estimate that Antero has developed less than 10% of its available drilling locations on its West Virginia Marcellus Shale acreage, and as a result, we expectto continue to materially expand our systems in both the East AOD and Western Area to service Antero’s continued growth in throughput. We investedapproximately $236 million in our Marcellus systems during the year ended December 31, 2013, bringing our total capital invested in these systems toapproximately $726 million since acquiring them in 2012.PRB NiobraraOur G&P segment includes our 50% interest in Jackalope Gas Gathering Services, L.L.C. (“Jackalope”), which owns a gas gathering system being developedto support a 311,000 gross acre AOD operated by Chesapeake Energy Corporation (“Chesapeake”) and RKI Exploration and Production LLC (“RKI”) in thecore of the PRB Niobrara Shale. The Jackalope system, which is 50% owned and operated by Access Midstream Partners, L.P., consists of approximately146 miles of gathering pipelines and 15,600 horsepower of compression equipment located in Converse County, Wyoming. The existing system, whichconnects to 115 wells, and its planned future development are supported by a 20-year gathering and processing agreement with Chesapeake and RKI underwhich Jackalope receives cost-of-service based fees with annual redeterminations sufficient to provide Jackalope a fixed return on all capital invested to buildout and expand the system over the life of the contract. Crestwood Niobrara manages the commercial operations of Jackalope.We invested approximately $128 million in Jackalope in fiscal 2013. Our Jackalope interest, which we acquired in July 2013, was financed in part through ajoint venture formed by our consolidated subsidiary, Crestwood Niobrara LLC (“Crestwood Niobrara”), with General Electric Capital Corporation and GEStructured Finance, Inc. (collectively, "GE"). See Part IV, Item 15, Exhibits and Financial Statement Schedules, Notes 5 and 11 for additional information onour Jackalope acquisition and financing thereof.BarnettWe own and operate three systems in the Barnett Shale, including the Cowtown, Lake Arlington and the Alliance systems.Our Cowtown system, which is located principally in the southern portion of the Fort Worth Basin, consists of (i) pipelines that gather rich natural gasproduced by customers and delivers the volumes to our plants for processing, (ii) the Cowtown plant, which includes two natural gas processing units thatextract NGLs from the natural gas stream and deliver customers’ residue gas and extracted NGLs to unaffiliated pipelines for sale downstream, and (iii) theCorvette plant, which extracts NGLs from the natural gas stream and delivers customers’ residue gas and extracted NGLs to unaffiliated pipelines for saledownstream. For the year ended December 31, 2013, our Cowtown and Corvette plants had a total average throughput of 189 MMcf/d of natural gas with anaverage NGL recovery of 19,600 Bbl/d.Our Lake Arlington system, which is located in eastern Tarrant County, Texas, consists of a gas gathering system and related compression facility. OurAlliance system, which is located in northern Tarrant and southern Denton Counties, Texas, consists of a gas gathering system and a related dehydration,compression and amine treating facility.We also own the West Johnson County system in the Barnett, which was operational from the date we acquired the plant (August 24, 2012) until we ceasedoperating the plant on December 31, 2012. We have since diverted rich gas volumes to our other processing facilities and are currently evaluating otherpotential uses for the West Johnson County plant, which has a processing capacity of 100 MMcf/d of natural gas.FayettevilleWe own and operate five systems in the Fayetteville Shale, including the Twin Groves, Prairie Creek, Woolly Hollow, Wilson Creek, and Rose Bud systems.Our Twin Groves, Prairie Creek, and Woolly Hollow systems (Conway and Faulkner Counties) consist of three gas gathering, compression, dehydration andtreating facilities. Our Wilson Creek (Van Buren County) and Rose Bud system (White County) systems each consist of a gas gathering system and a relatedcompression facility. All of our systems gather natural gas produced by customers and deliver customers’ gas to unaffiliated pipelines for downstream sale.OtherWe also own and operate systems in the Granite Wash, Avalon/Bone Spring, and the Haynesville/Bossier Shales. Our Indian Creek system, which is locatedin Roberts County, Texas in the Granite Wash, includes a rich gas gathering system, compression facility and processing plant. Our Las Animas system,which is located in Eddy County, New Mexico, consists of three gas gathering systems located in the Morrow/Atoka reservoir and the Avalon/Bone SpringShale rich gas trend in the10Table of ContentsPermian Basin. Our Sabine system, which is located in Sabine Parish, Louisiana, includes high-pressure gas gathering pipelines that provide gathering andtreating services for producers in the Haynesville/Bossier Shale.See Part IV, Item 15, Exhibits and Financial Statement Schedules, Note 4 for information related to our acquisition of various G&P systems.NGL and Crude ServicesThe operations comprising our NGL and crude segment primarily include our proprietary NGL and crude oil supply and logistics business, crude oil railterminals, the Arrow gathering system described below, our West Coast NGL business, NGL storage facilities, and US Salt, LLC (“US Salt”).Our proprietary NGL and crude oil supply and logistics business utilizes assets under our ownership or control to effectively provide supply “flowassurance” to producers, refiners and other customers. We are able to offer services that ensure uninterruptible NGL and crude oil supply flows at attractiveeconomic values by optimizing our fleet of rail and rolling stock (including approximately 290 tractors, 458 transports, and terminals in multiple states), ourWest Coast NGL operations, our NGL storage facilities, and NGL pipeline and storage capacity leased from third parties. Among other facilities utilized byour transportation fleet, we own or control rail-to-truck terminals in Bridgeton, New Jersey, Peekskill, New York and Lantana, Florida, and truckmaintenance facilities located in Indiana, Mississippi, New Jersey and Ohio.The COLT Hub consists of a crude oil loading and storage terminal and interconnecting pipeline facilities located in the heart of the Bakken and Three ForksShale oil-producing areas in Williams County, North Dakota. It has 960,000 barrels of crude oil storage capacity and is capable of loading up to 120,000Bbls/d utilizing two 8,700-foot rail loops that can accommodate 120-car unit trains. Customers can source crude oil through interconnected gathering systems,an eight-bay truck unloading rack and the COLT Connector, a 21-mile, 10-inch bi-directional pipeline that connects the COLT Hub to the Enbridge andTesoro crude pipelines at Dry Fork (Beaver Lodge/Ramberg junction). The COLT Hub is connected to the Meadowlark Midstream Company, LLC (formerly,Bear Tracker Energy) and Hiland crude oil gathering systems, and the Enbridge and Tesoro pipeline systems. We acquired the COLT Hub for $425 millionin December 2012, and since the acquisition we have invested a total of approximately $36.5 million in the COLT Hub to expand storage and rail loadingcapacity.Our NGL and crude services segment also includes our approximate 50% interest in Power River Basin Industrial Complex, LLC (“PRBIC”), which owns anearly stage crude oil rail terminal located in Douglas County, Wyoming that supports crude oil volumes produced within the PRB Niobrara. The rail loadingterminal, which we jointly own with Enserco Midstream LLC, is capable of loading up to 6,000 Bbls/d on a manifest basis and is expected to commence unittrain service in the first quarter of 2014. We paid approximately $22.5 million for our interest in PRBIC and we have invested approximately $1.9 million inPRBIC in 2013 since acquiring our equity interest. See Part IV, Item 15, Exhibits and Financial Statement Schedules, Note 5 for additional information on ourPRBIC investment.The Arrow system gathers crude oil, rich natural gas and produced water from wells operating on the Fort Berthold Indian Reservation in the core ofthe Bakken Shale in McKenzie and Dunn Counties, North Dakota. The system, which is located approximately 60 miles southeast of the COLT Hub,connects to our COLT Hub through the Hiland and Tesoro crude oil pipeline systems. The Arrow system includes more than 485 miles of gathering lines(including approximately 153 miles of crude oil gathering pipeline, 171 miles of natural gas gathering pipeline, and 164 miles of produced water gatheringlines), a 23-acre central delivery point with multiple pipeline take-away outlets and a fully-automated truck loading facility, and salt disposal wells. Ouroperations are anchored by long-term, primarily fee-based gathering contracts with blue-chip producers who have dedicated over 150,000 acres to the Arrowsystem, and our underlying contracts provide for fixed-fee gathering services with annual escalators for crude oil, natural gas and produced water gatheringservices. We are gathering approximately 48,300 Bbls/d of crude oil, 11.8 MMcf/d of rich natural gas and 10,500 Bbls/d of produced water on the Arrowsystem as of December 31, 2013. We acquired the Arrow system in November 2013 for approximately $750 million, and since the acquisition we haveinvested approximately $24.9 million in the Arrow system. See Part IV, Item 15, Exhibits and Financial Statement Schedules, Note 4 for additionalinformation on this acquisition.Our West Coast NGL business provides processing, fractionation, storage, transportation and marketing services to producers, refiners and other customers.Located near Bakersfield, California, our West Coast facilities include 24 million gallons of aboveground NGL storage capacity, 25 MMcf/d of natural gasprocessing capacity, 12,000 Bbls/d of NGL fractionation capacity, 8,000 Bbls/d of butane isomerization capacity, and NGL rail and truck take-awayoptions. We separate NGLs from methane, deliver methane to local natural gas pipelines, and retain NGLs for further processing at our fractionation facility,as well as provide butane isomerization and refrigerated storage services. Our isomerization facility chemically changes normal butane to isobutane, which weprovide to area refineries for motor fuel blending.11Table of ContentsOur NGL storage facilities include the Seymour and Bath storage facilities. The Seymour storage facility, which is located in Seymour, Indiana, has 21million gallons of underground NGL storage capacity and 1.2 million gallons of aboveground “bullet” storage capacity. The facility’s receipts and deliveriesare supported by TE Products Pipeline (“TEPPCO”) pipeline and truck access. The Bath storage facility, which is located near Bath, New York, has1.7 million barrels of underground NGL storage capacity and is supported by both rail and truck terminal facilities capable of loading and unloading 23railcars per day and approximately 100 truck transports per day. We also lease more than 700,000 barrels of NGL working storage capacity at major hubssuch as Mt. Belvieu, Texas and Conway, Kansas.US Salt is an industry-leading solution mining and salt production company located on the shores of Seneca Lake near Watkins Glen in Schuyler County,New York. It is one of five major solution mined salt manufacturers in the United States, capable of producing more than 400,000 tons of evaporated saltproducts for food, industrial and pharmaceutical uses. The solution mining process used by US Salt creates salt caverns that can be converted into naturalgas and NGL storage capacity.Storage and TransportationWe own and operate five high-performance natural gas storage facilities located in Texas, New York and Pennsylvania that have an aggregate working gasstorage capacity of approximately 79.4 Bcf. Our storage facilities have low maintenance costs, long useful lives and comparatively high cycling capabilities.The interconnectivity of our storage facilities with interstate pipelines offers flexibility to shippers in the Northeast, and our facilities are located in closeproximity to the Northeast demand market and a prolific supply source, the Marcellus Shale. Our natural gas storage facilities, each of which generates fee-based revenues, include:•Tres Palacios, a 38.4 Bcf multi-cycle, salt dome storage facility owned and operated by our Tres Palacios Gas Storage Company LLC (“TPGS”)subsidiary. The facility’s 60-mile, 24-inch diameter header system (including a 51-mile north pipeline lateral and an approximate 11-mile southpipeline lateral) interconnects with 10 pipeline systems and can receive residue gas from the tailgate of Kinder Morgan Inc's (formerly CopanoEnergy's) Houston central processing plant;•Stagecoach, a 26.2 Bcf multi-cycle, depleted reservoir storage facility owned and operated by our Central New York Oil And Gas Company, L.L.C.(“CNYOG”) subsidiary. A 24-mile, 30-inch diameter south pipeline lateral connects the storage facility to Tennessee Gas Pipeline Company, LLC's(“TGP”) 300 Line, and a 10-mile, 20-inch diameter north pipeline lateral connects to the Millennium Pipeline (“Millennium”);•Thomas Corners, a 7.0 Bcf multi-cycle, depleted reservoir storage facility owned and operated by our Arlington Storage Company, LLC (“ArlingtonStorage”) subsidiary. An 8-mile, 12-inch diameter pipeline lateral connects the storage facility to TGP's 400 Line, and a 7.5-mile, 8-inch diameterpipeline lateral connects to Millennium. Thomas Corners is also connected to Dominion Transmission Inc. (“Dominion”) system through our Steubenfacility;•Steuben, a 6.3 Bcf single-turn, depleted reservoir storage facility owned and operated by Arlington Storage. A 12.5-mile, 12-inch diameter pipelinelateral connects the storage facility to the Dominion system, and a 6-inch diameter pipeline measuring less than one mile connects our Steuben andThomas Corners storage facilities; and•Seneca Lake, a 1.5 Bcf multi-cycle, bedded salt storage facility owned and operated by Arlington Storage. A 19-mile, 16-inch diameter pipelinelateral connects the storage facility to Millennium and Dominion’s system. Inergy Midstream acquired the Seneca Lake facility from New York StateElectric & Gas Corporation (“NYSEG”) in July 2011.12Table of ContentsThe following provides additional information about our natural gas storage facilities as of December 31, 2013:Storage Facility /Location CyclingCapability(Number ofCyclesper Year) CertificatedWorking GasStorageCapacity(Bcf) MaximumInjectionRate(MMcf/d) MaximumWithdrawalRate(MMcf/d) PipelineConnectionsTres PalaciosMatagorda, Wharton and ColoradoCounties, TX 7x 38.4(1) 1,000 2,500 Multiple(2)StagecoachTioga County, NY;Bradford County, PA 2x 26.2 250 500 TGP's 300 Line;Millennium;Transco's Leidy Line(3)Thomas CornersSteuben County, NY 2x 7.0 70 140 TGP's 400 Line;Millennium;DominionSeneca LakeSchuyler County, NY 12x(4) 1.5 73 145 Dominion;MillenniumSteubenSteuben County, NY 1x 6.3 30 60 TGP's 400 Line;Millennium;DominionTotal 79.4 1,423 3,345 (1)We have requested FERC authorization to abandon up to 22.9 Bcf of the certificated working gas storage capacity. See Part IV, Item 15, Exhibits and Financial StatementSchedules, Note 15, for additional information on this abandonment proceeding.(2)Tres Palacios is interconnected to Florida Gas Transmission Company, LLC, Kinder Morgan Tejas Pipeline, L.P., Houston Pipe Line Company, Central Texas GatheringSystem, Natural Gas Pipeline Company of America, Transcontinental Gas Pipe Line Corporation (“Transco”), TGP, Valero Natural Gas Pipe Line Company, Channel PipelineCompany, and Texas Eastern Transmission, L.P.(3)Stagecoach is connected to Transco's Leidy Line through our MARC I Pipeline.(4)Seneca Lake was designed for 12-turn service, but we operate it as a nine-turn high-deliverability storage facility.We own natural gas transportation facilities located in New York and Pennsylvania. These facilities have low maintenance costs and long useful lives, andthey are located in or near the Marcellus shale. Throughput on our transportation assets can also be expanded at relatively low capital costs. In 2013, ourtransportation facilities delivered approximately 0.8 Bcf/d of natural gas on a firm or interruptible basis. Our natural gas transportation facilities include:•North-South Facilities, which include compression and appurtenant facilities installed to expand transportation capacity on the Stagecoach northand south pipeline laterals. The bi-directional facilities, which are owned and operated by CNYOG, provide more than 365 MMcf/d of firm interstatetransportation capacity to shippers. The North-South Facilities, which were placed into service in December 2011, generate fee-based revenues under anegotiated rate structure authorized by the FERC;•MARC I Pipeline, a 39-mile, 30-inch diameter interstate natural gas pipeline that connects the Stagecoach south lateral and TGP's 300 Line inBradford County, Pennsylvania, with Transco’s Leidy Line in Lycoming County, Pennsylvania. The bi-directional pipeline, which is owned andoperated by CNYOG, provides more than 590 MMcf/d of firm interstate transportation capacity to shippers. It includes a 16,360 horsepower gas-fired compressor station near the Transco interconnection, and a 15,000 horsepower electric-powered compressor station at the interconnection betweenthe Stagecoach south lateral and TGP’s 300 Line. The MARC I Pipeline, which placed into service in December 2012, generates fee-based revenuesunder a negotiated rate structure authorized by the FERC; and•East Pipeline, a 37.5 mile, 12-inch diameter natural gas intrastate pipeline located in New York, which transports 30 MMcf/d of natural gas fromDominion to the Binghamton, New York city gate. The pipeline, which is owned and operated by Crestwood Pipeline East, LLC (formerly InergyPipeline East, LLC, “CPE”), runs within three miles of our Stagecoach north lateral's point of interconnection with Millennium. The East Pipelinegenerates fee-based revenues under a negotiated rate structure authorized by the New York State Public Service Commission (“NYPSC”). We acquiredthe East Pipeline from NYSEG in July 2011 as part of its acquisition of the Seneca Lake gas storage facility.13Table of ContentsGrowth ProjectsGathering and ProcessingWe are expanding our gathering and compression facilities in the Marcellus Shale to accommodate Antero’s increased drilling activity and acceleratedproduction plans. Based on our existing construction plans and Antero’s latest production plans, we expect to spend between $180 million and $220 million in2014 to construct additional gathering lines and four compressor stations. As a result of this additional installed system capacity, we expect daily gatheringvolumes for all of our gathering and processing operations to increase from approximately 500 MMcf/d at December 31, 2013 to approximately 750 MMcf/dby December 31, 2014.We are working with our joint venture partner to build out the Jackalope gathering system and to construct a 120 MMcf/d processing facility (Bucking HorsePlant) to serve PRB Niobrara producers, including Chesapeake and RKI. In December 2013, Jackalope received the state permit required to commenceconstruction of the gas processing plant, and we anticipate that Jackalope will commence processing volumes at the cryogenic plant in the fourth quarter of2014. We expect the processing plant to produce more than 9,000 barrels of NGLs daily at full capacity, and we anticipate that Jackalope will spendapproximately $237 million on the system build out next year. We anticipate that Jackalope will complete the build-out of its system to reach a total designcapacity of 150 MMcf/d of gas gathering by the third quarter of 2014.NGL and Crude ServicesWe are continuing to build out the Arrow gathering system to its total design capacity of 125,000 Bbls/d of crude oil gathering, 100 MMcf/d of gas gathering,and 40,000 Bbls/d of produced water gathering. We also substantially completed in late 2013 certain system enhancements (including line looping and systemcompression) that will enable us to capture greater volumes of natural gas currently being flared by producers, and we expect to complete these enhancementsin the first half of 2014. Given that the Arrow system was designed and constructed to handle significantly greater volumes than those flowing today and thatour producer customers are responsible for the costs of connecting their wells to our system, we expect to complete the Arrow system build-out to reach targetedoperational throughput capacities with modest organic capital requirements (approximately $80 million) over the next 18-24 months.We are expanding our COLT Hub to increase our crude oil throughput and storage capacities. The expansion primarily entails the installation of additionalcrude oil loading arms and pumps at our rail loading rack; the construction of parallel rail tracks on which we will be able to store additional unit trains; theconstruction of two floating-roof crude oil storage tanks; the construction of additional truck unloading racks; and, modifications that will enable us to receivemore crude oil from interconnected gathering systems. The expansion is designed to increase our unit train loading capacity to 160,000 Bbls/d, our truckunloading capacity to 96,000 Bbls/d, our working storage capacity to 1.08 million barrels, and our input capacity from third-party gathering systems toapproximately 105,000 Bbls/d. We estimate the total capital cost of this expansion to be approximately $52.0 million, and we have entered into customercontracts that support a substantial portion of our anticipated capital investment. We expect to complete the expansion in the first quarter of 2014.We are developing an NGL storage facility at our US Salt complex in Schuyler County, New York. We have requested from the New York State Departmentof Environmental Conservation (“NYSDEC”) the permits necessary to store up to 2.1 million barrels of propane and butane in underground caverns createdby US Salt’s solution-mining process. We estimate that the total capital cost of our proposed Watkins Glen NGL storage project to be approximately $40.3million. We expect the NYSDEC to issue the requested permits in 2014 and to place the storage facility into service within 90-120 days thereafter, but we canprovide no assurances that we will receive, if at all, the permits necessary to commence construction.Storage and TransportationWe have requested the regulatory approvals (including FERC authorization) necessary to expand the working gas capacity of our Seneca Lake natural gasstorage facility by approximately 0.5 Bcf. We estimate the total capital cost of this expansion to be approximately $2.0 million. We expect to place thisexpansion capacity into service in the first half of 2014.CustomersNo customer accounted for 10% or more of our total consolidated revenues for the year ended December 31, 2013. For the year ended December 31, 2012,Quicksilver Resources Inc. (“Quicksilver”) and Antero accounted for approximately 47% and 11% of our total consolidated revenues. For the year endedDecember 31, 2011, Quicksilver accounted for approximately 64% of our total consolidated revenues.14Table of ContentsIndustry BackgroundThe midstream sector of the energy industry provides the link between exploration and production and the delivery of crude oil, natural gas and theircomponents to end-use markets. The midstream sector consists generally of gathering, processing, storage, and transportation activities. We gather crude oiland natural gas; process natural gas; fractionate NGLs; store crude oil, NGLs and natural gas; and transport crude oil, NGLs and natural gas.The diagram below depicts the main segments of the midstream sector value chain:Crude OilPipelines typically provide the most cost-effective option for shipping crude oil. Crude oil gathering systems normally comprise a network of small-diameterpipelines connected directly to the well head that transport crude oil to central receipt points or interconnecting pipelines through larger diameter trunk lines.Common carrier pipelines frequently transport crude oil from central delivery points to logistics hubs or refineries under tariffs regulated by the FERC or stateauthorities. Logistic hubs provide storage and connections to other pipeline systems and modes of transportation, such as railroads and trucks. Pipelines notengaged in the interstate transportation of crude may also be proprietary or leased entirely to a single customer.Trucking complements pipeline gathering systems by gathering crude oil from operators at remote wellhead locations not served by pipeline gathering systems.Trucking is generally limited to low volume, short haul movements because trucking costs escalate sharply with distance, making trucking the mostexpensive mode of crude oil transportation. Railroads provide additional transportation capabilities for shipping crude oil between gathering storage systems,pipelines, terminals and storage centers and end-users. Natural GasMidstream companies within the natural gas industry create value at various stages along the value chain by gathering natural gas from producers at thewellhead, processing and separating the hydrocarbons from impurities and into lean gas (primarily methane) and NGLs, and then routing the separated leangas and NGL streams for delivery to end-markets or to the next stage of the value chain. A significant portion of natural gas produced at the wellhead contains NGLs. Natural gas produced in association with crude oil typically contains higherconcentrations of NGLs than natural gas produced from gas wells. This rich natural gas is generally not acceptable for transportation in the nation’stransmission pipeline system or for residential or commercial use. Processing plants extract the NGLs, leaving residual lean gas that meets transmissionpipeline quality specifications for ultimate consumption. Processing plants also produce marketable NGLs, which, on an energy equivalent basis, typicallyhave a greater economic value as a raw material for petrochemicals and motor gasolines than as a component of the natural gas stream.15Table of ContentsGathering. At the earliest stage of the midstream value chain, a network of typically small diameter pipelines known as gathering systems directly connect towellheads or pad sites in the production area. Gathering systems transport gas from the wellhead to downstream pipelines or a central location for treating andprocessing. Gathering systems are often designed to be highly flexible to allow gathering of natural gas at different pressures and scalable to allow foradditional production and well connections without significant incremental capital expenditures. A byproduct of the gathering process is the recovery ofcondensate liquids, which are sold on the open market.Compression. Gathering systems are operated at pressures intended to enable the maximum amount of production to be gathered from connected wells.Through a mechanical process known as compression, volumes of natural gas at a given pressure are compressed to a sufficiently higher pressure, therebyallowing those volumes to be delivered into a higher pressure downstream pipeline to be shipped to market. Because wells produce at progressively lower fieldpressures as they age, it becomes necessary to add additional compression over time to maintain throughput across the gathering system.Treating and Dehydration. Treating and dehydration involves the removal of impurities such as water, carbon dioxide, nitrogen and hydrogen sulfide thatmay be present when natural gas is produced at the wellhead. Impurities must be removed for the natural gas to meet the quality specifications for pipelinetransportation, and end users normally cannot consume (and will not purchase) natural gas with a high level of impurities. Therefore, to meet downstreampipeline and end user natural gas quality standards, the natural gas is dehydrated to remove water and is chemically treated to separate the impurities from thenatural gas stream.Processing. Once impurities are removed, pipeline-quality residue gas is separated from NGLs. Most rich natural gas is not suitable for long-haul pipelinetransportation or commercial use and must be processed to remove the heavier hydrocarbon components. The removal and separation of hydrocarbons duringprocessing is possible because of the differences in physical properties between the components of the raw gas stream. There are four basic types of natural gasprocessing methods: cryogenic expansion, lean oil absorption, straight refrigeration and dry bed absorption. Cryogenic expansion represents the latestgeneration of processing, incorporating extremely low temperatures and high pressures to provide the best processing and most economical extraction.Natural gas is processed not only to remove heavier hydrocarbon components that would interfere with pipeline transportation or the end use of the natural gas,but also to separate from the natural gas those hydrocarbon liquids that could have a higher value as NGLs than as natural gas. The principal component ofresidue gas is methane, although some lesser amount of entrained ethane typically remains. In some cases, processors have the option to leave ethane in the gasstream or to recover ethane from the gas stream, depending on ethane’s value relative to natural gas. The processor’s ability to “reject” ethane varies dependingon the downstream pipeline’s quality specifications. The residue gas is sold to industrial, commercial and residential customers and electric utilities.Fractionation. Once NGLs have been removed from the natural gas stream, they can be broken down into their base components to be useful to commercialcustomers. Mixed NGL streams can be further separated into purity NGL products, including ethane, propane, normal butane, isobutane, and naturalgasoline. Fractionation works based on the different boiling points of the different hydrocarbons in the NGL stream, and essentially occurs in stagesconsisting of the boiling off of hydrocarbons one by one. The entire fractionation process is broken down into steps, starting with the removal of the lighterNGLs from the stream. In general, fractionators are used in the following order: (i) deethanizer, which separates ethane from the NGL stream, (ii)depropanizer, which separates propane, (iii) debutanizer, which boils off the butanes and leaves the pentanes and heavier hydrocarbons in the NGL stream,and (iv) butane splitter (or deisobutanizer), which separates isobutanes and normal butanes.Transportation and Storage. Once raw natural gas has been treated or processed and the raw NGL mix fractionated into individual NGL components, thenatural gas and NGL components are stored, transported and marketed to end-use markets. The natural gas pipeline grid in the United States transportsnatural gas from producing regions to customers, such as LDCs, industrial users and electric generation facilities.Historically, the concentration of natural gas production in a few regions of the United States generally required transportation pipelines to transport gas notonly within a state but also across state borders to meet national demand. However, a recent shift in supply sources, from conventional to unconventional, hasaffected the supply patterns, the flows and the rates that can be charged on pipeline systems. The impacts vary among pipelines according to the location andthe number of competitors attached to these new supply sources. These changing market dynamics are prompting midstream companies to evaluate theconstruction of short-haul pipelines as a means of providing demand markets with cost-effective access to newly-developed production regions, as compared torelying on higher-cost, long-haul pipelines that were originally designed to transport natural gas greater distances across the country.16Table of ContentsNatural gas storage plays a vital role in maintaining the reliability of gas available for deliveries. Natural gas is typically stored in underground storagefacilities, including salt dome caverns, bedded salt caverns and depleted reservoirs. Storage facilities are most often utilized by pipeline companies to managetemporary imbalances in operations; natural gas end-users, such as LDCs, to manage the seasonality and variability of demand and to satisfy future naturalgas needs; and, independent natural gas marketing and trading companies in connection with the execution of their trading strategies.Salt ManufacturingAccording to the United States Geological Survey, approximately 280 million metric tons of salt were produced in the world in 2012. Salt is generallycategorized into four types based upon the method of production: evaporated salt, solar salt, rock salt and salt in brine. Dry salt is produced through thefollowing methods: solution mining and mechanical evaporation, solar evaporation or deep-shaft mining. US Salt produces salt using solution mining andmechanical evaporation. In solution mining, wells are drilled into salt beds or domes and then water is injected into the formation and circulated to dissolve thesalt. After salt is removed from a solution-mined salt deposit, the empty cavern can be used to store other substances, such as natural gas, NGLs orcompressed air.The salt solution, or brine, is next pumped out of the cavern and taken to a processing plant for evaporation. The brine may be treated to remove minerals andthen pumped into vacuum pans in which the brine is boiled, and evaporated until a salt slurry is created. The slurry is then dried and separated. Dependingon the type of salt product to be produced, iodine and an anti-caking agent may be added to the salt. Most food grade table salt is produced in this manner.CompetitionOur G&P operations compete for customers based on reputation, operating reliability and flexibility, price, creditworthiness, and service offerings, includinginterconnectivity to producer-desired takeaway options (e.g., processing facilities and pipelines). We face strong competition in acquiring new supplies in theproduction basins in which we operate, and competition customarily is impacted by the level of drilling activity in a particular geographic region andfluctuations in commodity prices. Our primary competitors include other midstream companies with G&P operations and producer-owned systems, andcertain competitors enjoy first-mover advantages over us and may offer producers greater gathering and processing efficiencies, lower operating costs and moreflexible commercial terms.Our proprietary NGL and crude oil supply and logistics business competes primarily with integrated major oil companies, refiners and processors, and otherenergy companies that own or control transportation and storage assets that can be optimized for supply, marketing and logistics services.Natural gas storage and pipeline operators compete for customers primarily based on geographic location, which determines connectivity and proximity tosupply sources and end-users, as well as price, operating reliability and flexibility, available capacity and service offerings. Our primary competitors in ournatural gas storage market include other independent storage providers and major natural gas pipelines with storage capabilities embedded within theirtransmission systems. Our primary competitors in our natural gas transportation market include major natural gas pipelines and intrastate pipelines that cantransport natural gas volumes between interstate systems. Long-haul pipelines often enjoy cost advantages over new pipeline projects with respect to options fordelivering greater volumes to existing demand centers, and new projects and expansions proposed from time to time may serve the markets we serve andeffectively displace the service we provide to customers.Our crude oil rail terminals primarily compete with crude oil pipelines and other midstream companies that own and operate rail terminals in the markets weserve. The crude oil logistics business is characterized by strong completion for supplies, and competition is based largely on customer service quality,pricing, and geographic proximity to customers and other market hubs.Our salt operations compete for customers primarily based on price and service. Because transportation costs are a material component of the costs borne byour customers, most of our customers are geographically located east of the Mississippi River.RegulationOur operations are subject to extensive regulation by federal, state and local authorities. The regulatory burden on our operations increases our cost of doingbusiness and, in turn, impacts our profitability. In general, midstream companies have experienced increased regulatory oversight over the past few years, andwe expect this trend to continue for the foreseeable future.17Table of ContentsPipeline SafetyWe are subject to pipeline safety regulations imposed by the Department of Transportation Pipeline and Hazardous Materials Safety Administration(“PHMSA”). PHMSA regulates safety requirements in the design, construction, operation and maintenance of jurisdictional natural gas and hazardous liquidpipeline facilities. Currently, all of our natural gas pipelines used in gathering, storage and transportation activities are subject to regulation by PHMSA underthe Natural Gas Pipeline Safety Act of 1968, as amended, and all of our NGL and crude oil pipelines used in gathering, storage and transportation activitiesare subject to regulation by PHMSA as hazardous liquids pipelines under the Hazardous Liquid Pipeline Safety Act of 1979, as amended.These federal statutes and PHMSA implementing regulations collectively impose numerous safety requirements on pipeline operators, such as the developmentof a written qualification program for individuals performing covered tasks on pipeline facilities and the implementation of pipeline integrity managementprograms. For example, the Pipeline Safety Improvement Act of 2002 establishes mandatory inspections for all crude oil and natural gas transmissionpipelines in high-consequence areas, such as areas of high population and areas unusually sensitive to environmental damage. Integrity management plansrequire more frequent inspections and other preventative measures to ensure pipeline safety in high consequence areas.We plan to continue our pipeline integrity testing programs to assess and maintain the integrity of our pipelines in accordance with PHMSA regulations.Notwithstanding our preventive and investigatory maintenance efforts, we may incur significant expenses if anomalous pipeline conditions are discovered ordue to the implementation of more stringent pipeline safety standards resulting from new or amended legislation. For example, President Obama in January2012 signed the Pipeline Safety, Regulatory Certainty, and Job Creation Act of 2011 (“Pipeline Safety Act”), which requires increased safety measures for gasand hazardous liquids transportation pipelines. Among other things, the Pipeline Safety Act directs the Secretary of Transportation to promulgate rules orstandards relating to expanded integrity management requirements, automatic or remote-controlled valve use, excess flow valve use, and leak detection systeminstallation. The Pipeline Safety Act also directs owners and operators of interstate and intrastate gas transmission pipelines to verify their records confirmingthe maximum allowable pressure of pipelines in certain class locations and high consequence areas, requires promulgation of regulations for conducting teststo confirm the material strength of pipe operating above 30% of specified minimum yield strength in high consequence areas, and increases the maximumpenalty for violation of pipeline safety regulations from $1 million to $2 million. Furthermore, PHMSA is considering changes to its natural gas transmissionpipeline regulations to, among other things, expand the scope of high consequence areas, strengthen integrity management requirements applicable to existingoperators; strengthen or expand non-integrity pipeline management standards relating to such matters as valve spacing, automatic or remotely-controlledvalves, corrosion protection, and gathering lines; and add new regulations to govern the safety of underground natural gas storage facilities, includingunderground storage caverns and injection or withdrawal well piping that are not regulated today. We cannot predict the final outcome of these legislative orregulatory efforts or the precise impact that compliance with any resulting new requirements may have on our business.States are largely preempted by federal law from regulating pipeline safety for interstate lines, but most are certified by the Department of Transportation toassume responsibility for enforcing federal intrastate pipeline regulations and inspection of intrastate pipelines. In practice, because states can adopt stricterstandards for intrastate pipelines than those imposed by the federal government for interstate pipelines, states vary considerably in their authority and capacityto address pipeline safety. Our pipelines have operations and maintenance plans designed to keep the facilities in compliance with pipeline safety requirements,and we do not anticipate any significant difficulty in complying with applicable state laws and regulations.Natural Gas Storage and TransportationOur interstate natural gas storage and transportation operations are subject to regulation by the FERC under the Natural Gas Act, and three of our subsidiaries(TPGS, CNYOG and Arlington Storage) are regulated by the FERC as natural gas companies. Under the Natural Gas Act, the FERC has authority to regulategas transportation services in interstate commerce, which includes natural gas storage services. The FERC exercises jurisdiction over rates charged for servicesand the terms and conditions of service; the certification and construction of new facilities; the extension or abandonment of services and facilities; themaintenance of accounts and records; the acquisition and disposition of facilities; standards of conduct between affiliated entities; and various other matters.Regulated natural gas companies are prohibited from charging rates determined by the FERC to be unjust, unreasonable, or unduly discriminatory, and boththe existing tariff rates and the proposed rates of regulated natural gas companies are subject to challenge.18Table of ContentsThe rates and terms and conditions of our natural gas storage and transportation services are found in the FERC-approved tariffs of (i) TPGS, the owner ofthe Tres Palacios facility, (ii) CNYOG, the owner of the Stagecoach facility, the North-South Facilities and the MARC I Pipeline, and (iii) Arlington Storage,the owner of the Thomas Corners, Seneca Lake and Steuben facilities. TPGS, CNYOG and Arlington Storage are authorized to charge and collect market-based rates for storage services, and CNYOG is authorized to charge and collect negotiated rates for transportation services. Market-based and negotiated rateauthority allows us to negotiate rates with individual customers based on market demand, which we then make public. A loss of market-based or negotiatedrate authority or any successful complaint or protest against the rates charged or provided by TPGS, CNYOG or Arlington Storage could have an adverseimpact on our revenues.In addition, the Energy Policy Act of 2005 amended the Natural Gas Act to (i) prohibit market manipulation by any entity; (ii) direct the FERC to facilitatemarket transparency in the market for sale or transportation of physical natural gas in interstate commerce; and (iii) significantly increase the penalties forviolations of the Natural Gas Act, the Natural Gas Policy Act of 1978, and FERC rules, regulations or orders thereunder. As a result of the Energy Policy Actof 2005, the FERC has the authority to impose civil penalties for violations of these statutes and FERC rules, regulations and orders, up to $1 million per dayper violation.On December 6, 2013, we requested FERC authorization for TPGS to abandon up to 22.9 Bcf of Tres Palacios’ working gas storage capacity. Multipleparties (none of which are customers) have filed protests, and the lessor under our Tres Palacios storage sublease has requested that the FERC toll ourabandonment proceeding until after a Texas state court rules on an action for declaratory judgment filed by the lessor on January 8, 2014. We filed with theFERC our responses to the protesters' filings in January and February 2014, and we expect the FERC to issue an order in the first half of 2014. Assuming theFERC grants our request, we anticipate completing the abandonment within one year thereafter.In May 2012, we requested FERC authorization for Steuben Gas Storage Company to abandon its tariff as part of its merger with Arlington Storage, and forArlington Storage to thereafter charge marketed-based rates under its tariff for services at the Steuben facility. In October 2012, the FERC issued an ordergranting the requested authorizations. We consummated the abandonments and merger effective April 1, 2013. As a result, we charge market-based rates forstorage service provided by our Thomas Corners, Seneca Lake and Steuben facilities and we provide wheeling services for all through facilities under onetariff (Arlington Storage’s tariff).Our interstate natural gas storage operations are also subject to non-rate regulation by various state agencies. For example, the Texas Railroad Commission(“RRC”) and NYSDEC have jurisdiction over the underground storage of natural gas and well drilling, conversion and plugging in Texas and New York,respectively. These respective agencies therefore regulate aspects of our Tres Palacios, Stagecoach, Thomas Corners, Seneca Lake and Steuben natural gasstorage facilities.Our intrastate pipeline in New York (the East Pipeline) is subject to lightened regulation under NYPSC regulations and policies. Lightened regulation generallyexempts us from NYPSC regulation applicable to the provision of retail service. CPE, as the owner and operator of the East Pipeline, remains subject to limitedcorporate (e.g., obtaining approval prior to any transfer of its ownership interests or the issuance of debt securities) and operational and safety (e.g., filing ofvegetation management plan) regulation established and maintained by the NYPSC.Natural Gas GatheringNatural gas gathering facilities are exempt from FERC jurisdiction under Section 1(b) of the Natural Gas Act. Although the FERC has not made formaldeterminations with respect to all of our facilities we consider to be gathering facilities, we believe that our natural gas pipelines meet the traditional tests that theFERC has used to determine that a pipeline is a gathering pipeline and is therefore not subject to FERC jurisdiction. The distinction between FERC-regulatedtransmission services and federally unregulated gathering services, however, has been the subject of substantial litigation, and the FERC determines whetherfacilities are gathering facilities on a case-by-case basis, so the classification and regulation of our gathering facilities is subject to change based on futuredeterminations by the FERC, the courts or Congress. If the FERC were to consider the status of an individual facility and determine that the facility and/orservices provided by it are not exempt from FERC regulation under the Natural Gas Act and the facility provides interstate service, the rates for, and terms andconditions of, services provided by such facility would be subject to regulation by the FERC under the Natural Gas Act or the Natural Gas Policy Act. Suchregulation could decrease revenue, increase operating costs, and, depending upon the facility in question, could adversely affect our results of operations andcash flows. In addition, if any of our facilities were found to have provided services or otherwise operated in violation of the Natural Gas Act or the NaturalGas Policy Act, this could result in the imposition of civil penalties as well as a requirement to disgorge charges collected for such service in excess of the rateestablished by the FERC.19Table of ContentsStates may regulate gathering pipelines. State regulation of gathering facilities generally includes various safety, environmental and, in some circumstances,requirements prohibiting undue discrimination, and in some instances complaint-based rate regulation. Our natural gas gathering operations may be subject toratable take and common purchaser statutes in the states in which we operate. These statutes are designed to prohibit discrimination in favor of one producerover another producer or one source of supply over another source of supply, and they generally require our gathering pipelines to take natural gas withoutundue discrimination as to source of supply or producer. These statutes have the effect of restricting our right as an owner of gathering facilities to decide withwhom we contract to purchase or transport natural gas.The states in which we operate gathering systems have adopted a form of complaint-based regulation of natural gas gathering operations, which allows naturalgas producers and shippers to file complaints with state regulators in an effort to resolve grievances relating to gathering access and rate discrimination. Todate, these regulations have not had an adverse effect on our systems. We cannot predict whether such a complaint will be filed against us in the future, andfailure to comply with state regulations can result in the imposition of administrative, civil and criminal remedies.In Texas, we have filed with the Texas Railroad Commission (“TRCC”) to establish rates and terms of service for certain of our pipelines. Our assets in Texasinclude intrastate common carrier NGL pipelines subject to the regulation of the TRCC, which requires that our NGL pipelines file tariff publications thatcontain all the rules and regulations governing the rates and charges for services we perform. NGL pipeline rates may be limited to provide no more than a fairreturn on the aggregate value of the pipeline property used to render services.NGL StorageOur NGL storage terminals are subject primarily to state and local regulation. For example, the Indiana Department of Natural Resources (“INDNR”) and theNYSDEC have jurisdiction over the underground storage of NGLs and well drilling, conversion and plugging in Indiana and New York, respectively. Thus,the INDNR regulates aspects of our Seymour facility, and the NYSDEC regulates aspects of the Bath facility.We filed an application with the NYSDEC in October 2009 for an underground storage permit for our Watkins Glen NGL storage development project. Theagency issued a Positive Declaration for the project in November 2010, determined in August 2011 that the Draft Supplemental Environmental ImpactStatement we submitted for the project was complete, and held public hearings on the project in September and November 2011. In early 2012, based onconcerns expressed by interested stakeholders and conversations with NYSDEC Staff, we informed the agency that we would reduce our environmentalfootprint and modified our brine pond design. In September 2012, we submitted to the NYSDEC final drawings and plans for our revised project design.Although we believe we have satisfied the administrative requirements necessary for the NYSDEC to issue the requested permits, we believe the agency’sdetermination is being delayed due to political reasons unrelated to the project's design and environmental impact. Given the critical shortage of propanedelivery options and storage infrastructure serving the Northeast and the record prices being paid by New York propane consumers in the 2013-2014 winter,we remain optimistic that state officials will recognize the importance of this critical energy infrastructure project and the NYSDEC will issue the permits thisyear. However, we cannot predict with certainty if and when the political challenges associated with the NYSDEC permitting process will dissipate.Crude Oil TransportationThe transportation of crude oil by common carrier pipelines on an interstate basis is subject to regulation by the FERC under the Interstate Commerce Act(“ICA”), the Energy Policy Act of 1992, and the rules and regulations promulgated under those laws. FERC regulations require interstate common carrierpetroleum pipelines to file with the FERC and publicly post tariffs stating their interstate transportation rates and terms and conditions of service. The ICAand FERC regulations also require that such rates be just and reasonable, and to be applied in a non-discriminatory manner and to not confer undue preferenceupon any shipper. The transportation of crude oil by common carrier pipelines on an intrastate is subject to regulation by state regulatory commissions. Thebasis for intrastate crude oil pipeline regulation, and the degree of regulatory oversight and scrutiny given to intrastate crude oil pipeline rates, varies from stateto state. Intrastate common carriers must also offer service to all shippers requesting service on the same terms and under the same rates. Our crude oilpipelines in North Dakota are not common carrier pipelines and, therefore, are not subject to rate regulation by the FERC or any state regulatory commission.Portions of our Arrow gathering system, which is located on the Fort Berthold Indian Reservation, are subject to regulation by the Mandan, Hidatsa & ArikaraNation. An entirely separate and distinct set of laws and regulations applies to operators and other parties within the boundaries of Native Americanreservations in the United States. Various federal agencies within the U.S. Department of the Interior, particularly the Bureau of Indian Affairs, the Office ofNatural Resources Revenue and Bureau of Land Management (“BLM”), and the EPA, together with each Native American tribe, promulgate and enforceregulations20Table of Contentspertaining to oil and gas operations on Native American reservations. These regulations include lease provisions, environmental standards, Tribal employmentcontractor preferences and numerous other matters.Native American tribes are subject to various federal statutes and oversight by the Bureau of Indian Affairs and BLM. However, each Native American tribe isa sovereign nation and has the right to enact and enforce certain other laws and regulations entirely independent from federal, state and local statutes andregulations, as long as they do not supersede or conflict with such federal statutes. These tribal laws and regulations include various fees, taxes, requirementsto employ Native American tribal members or use tribal owned service businesses and numerous other conditions that apply to lessees, operators andcontractors conducting operations within the boundaries of a Native American reservation. Further, lessees and operators within a Native American reservationare often subject to the Native American tribal court system, unless there is a specific waiver of sovereign immunity by the Native American tribe allowingresolution of disputes between the Native American tribe and those lessees or operators to occur in federal or state court.Therefore, we are subject to various laws and regulations pertaining to Native American oil and gas leases, fees, taxes and other burdens, obligations andissues unique to oil and gas operations within Native American reservations. One or more of these requirements, or delays in obtaining necessary approvals orpermits pursuant to these regulations, may increase our costs of doing business on Native American tribal lands and have an impact on the economic viabilityof any well or project on those lands.PHMSA is currently reviewing the adequacy of Bakken crude laboratory testing measures used to determine the packaging group selection for shipment ofcrude by rail. PHMSA's objective is to confirm that crude being offered for shipment by rail has been properly classified and characterized to ensure the safetransport to end users. We, as the owner of a Bakken crude loading terminal, are providing input as this review process progresses through multiple agenciesand organizations. Supply and LogisticsThe transportation of crude oil and NGLs by truck is subject to regulations promulgated under the Federal Motor Carrier Safety Act. These regulations, whichare administered by the DOT, cover the transportation of hazardous materials.IRS AuditOn January 29, 2014, the Internal Revenue Service (“IRS”) issued a Notice of Beginning of Administrative Proceeding (“NBAP”) to us stating that the IRS iscommencing an examination of Inergy, L.P.’s (now Crestwood Equity Partners LP) 2011 partnership tax return. A copy of the NBAP is available on ourwebsite at www.crestwoodlp.com. We understand this to be a routine compliance examination of various items of partnership income, gain, deductions,losses and credits. The examination is in its preliminary stages so it is not known whether the IRS will propose any adjustments to the 2011 tax return,whether such adjustments would be material, or how such adjustments would affect unitholders.We intend to fully cooperate with the IRS examiners auditing this return. Unitholders should consult their tax advisers if they have any questions.Environmental MattersOur operations are subject to stringent federal, regional, state and local laws and regulations governing the discharge and emission of pollutants into theenvironment, environmental protection, or occupational health and safety. These laws and regulations may impose significant obligations on our operations,including the need to obtain permits to conduct regulated activities; restrict the types, quantities and concentration of materials that can be released into theenvironment; apply workplace health and safety standards for the benefit of employees; require remedial activities or corrective actions to mitigate pollutionfrom former or current operations; and impose substantial liabilities on us for pollution resulting from our operations. Failure to comply with these laws andregulations may result in the assessment of sanctions, including administrative, civil and criminal penalties; the imposition of investigatory, remedial andcorrective action obligations or the incurrence of capital expenditures; the occurrence of delays in the development of projects; and the issuance of injunctionsrestricting or prohibiting some or all of the activities in a particular area.21Table of ContentsThe following is a summary of the more significant existing federal environmental laws and regulations, each as amended from time to time, to which ourbusiness operations are subject:•The Comprehensive Environmental Response, Compensation and Liability Act, a remedial statute that imposes strict liability on generators,transporters and arrangers of hazardous substances at sites where hazardous substance releases have occurred or are threatening to occur;•The Resource Conservation and Recovery Act, which governs the treatment, storage and disposal of solid wastes, including hazardous wastes;•The Clean Air Act, which restricts the emission of air pollutants from many sources and imposes various pre-construction, monitoring and reportingrequirements;•The Water Pollution Control Act, also known as the federal Clean Water Act, which regulates discharges of pollutants from facilities to state andfederal waters;•The Safe Drinking Water Act, which ensures the quality of the nation's public drinking water through adoption of drinking water standards andcontrolling the injection of substances into below-ground formations that may adversely affect drinking water sources;•The National Environmental Policy Act, which requires federal agencies to evaluate major agency actions having the potential to significantly impactthe environment and which may require the preparation of Environmental Assessments and more detailed Environmental Impact Statements that maybe made available for public review and comment;•The Endangered Species Act, which restricts activities that may affect federally identified endangered and threatened species or their habitats throughthe implementation of operating restrictions or a temporary, seasonal, or permanent ban in affected areas; and•The Occupational Safety and Health Act, which establishes workplace standards for the protection of the health and safety of employees, includingthe implementation of hazard communications programs designed to inform employees about hazardous substances in the workplace, potentialharmful effects of these substances, and appropriate control measures.Certain of these environmental laws impose strict, joint and several liability for costs required to clean up and restore properties where pollutants have beenreleased regardless of whom may have caused the harm or whether the activity was performed in compliance with all applicable laws. In the course of ouroperations, generated materials or wastes may have been spilled or released from properties owned or leased by us or on or under other locations where thesematerials or wastes have been taken for recycling or disposal. In addition, many of the properties owned or leased by us were previously operated by thirdparties whose management, disposal or release of materials and wastes was not under our control. Accordingly, we may be liable for the costs of cleaning up orremediating contamination arising out of our operations or as a result of activities by others who previously occupied or operated on properties now owned orleased by us. Private parties, including the owners of properties that we lease and facilities where our materials or wastes are taken for recycling or disposal,may also have the right to pursue legal actions to enforce compliance as well as to seek damages for non-compliance with environmental laws and regulationsor for personal injury or property or natural resource damages. We may not be able to recover some or any of these additional costs from insurance.We have not received any notices that we have violated these environmental laws and regulations in any material respect and we have not otherwise incurredany material liability or capital expenditures thereunder. Future developments, such as stricter environmental laws or regulations, or more stringent enforcementof existing requirements could affect our operations. For instance, the EPA and other federal and state agencies are considering or have already commenced thestudy of potential adverse impacts that certain drilling methods (including hydraulic fracturing) may have on water quality and public health, with the U.S.Department of Energy having released a report recommending the implementation of a variety of measures to reduce the environmental impacts from shale-gasproduction. Similarly, Congress and several states have proposed or enacted legislation or regulations that are expected to make it more difficult or costly forexploration and production companies to produce hydrocarbons. These initiatives, enactments and regulations could have an indirect adverse impact on us bydecreasing demand for the services that we offer.EmployeesAs of January 31, 2014, we had 1,133 full-time employees, 212 of which were general and administrative employees and 921 of which were operational. Asof January 31, 2014, US Salt had 126 employees, 98 of which are members of a labor union. We believe that our relationship with our employees (includingunion labor) is satisfactory.22Table of ContentsAvailable InformationOur website is located at www.crestwoodlp.com. We make available, free of charge, on or through our website our annual reports on Form 10-K, whichinclude our audited financial statements, quarterly reports on Form 10-Q, current reports on Form 8-K and amendments to those reports filed or furnishedpursuant to Section 13(a) or 15(d) of the Exchange Act as soon as we electronically file such material with the Securities and Exchange Commission (“SEC”).These documents are also available, free of charge, at the SEC's website at www.sec.gov. In addition, copies of these documents, excluding exhibits, may berequested at no cost by contacting Investor Relations, Crestwood Equity Partners LP, 700 Louisiana Street, Suite 2060, Houston, Texas 77002, and ourcorporate telephone number is (832) 519-2200.We also make available within the “Corporate Governance” section of our website our corporate governance guidelines, the charter of our Audit Committee andour Code of Business Conduct and Ethics. Requests for copies may be directed in writing to Crestwood Equity Partners LP, 700 Louisiana Street, Suite 2060,Houston, Texas 77002, Attention: General Counsel. Interested parties may contact the chairperson of any of our Board committees, our Board's independentdirectors as a group or our full Board in writing by mail to Crestwood Equity Partners LP, 700 Louisiana Street, Suite 2060, Houston, Texas 77002,Attention: General Counsel. All such communications will be delivered to the director or directors to whom they are addressed.Item 1A. Risk FactorsRisks Inherent in Our BusinessOur business depends on hydrocarbon supply and demand fundamentals, which can be adversely affected by numerous factors outside of ourcontrol.Our success depends on the supply and demand for natural gas, NGLs and crude oil. The degree to which our business is impacted by changes in supply ordemand varies. Our business can be negatively impacted by sustained downturns in supply and demand for one or more commodities, including reductionsin our ability to renew contracts on favorable terms and to construct new infrastructure. For example, major factors that will impact natural gas demanddomestically will be the realization of potential liquefied natural gas exports and demand growth within the power generation market, and a major factorimpacting oil and gas supplies has been the significant growth in unconventional sources such as shale plays. In addition, the supply and demand for naturalgas, NGLs and crude oil for our business will depend on many other factors outside of our control, some of which include:•adverse changes in general global economic conditions. The level and speed of the recovery from the recent recession remains uncertain and couldimpact the supply and demand for natural gas and our future rate of growth in our business;•adverse changes in domestic regulations that could impact the supply or demand for oil and gas;•technological advancements that may drive further increases in production and reduction in costs of developing shale plays;•competition from imported supplies and alternate fuels;•increased commodity prices that could negatively impact demand for these products;•increased costs to explore for, develop, produce, gather, process or transport commodities;•adoption of various energy efficiency and conservation measures; and•perceptions of customers on the availability and price volatility of our services, particularly customers’ perceptions on the volatility of commodityprices over the longer-term.If volatility and seasonality in the oil and gas industry decrease, because of increased production capacity or otherwise, the demand for our services and theprices that we will be able to charge for those services may decline. In addition to volatility and seasonality, an extended period of high commodity priceswould likely place upward pressure on the costs of associated expansion activities. An extended period of low commodity prices could adversely impactstorage and transportation values for some period of time until market conditions adjust. These commodity price impacts could have a negative impact on ourbusiness, financial condition, and results of operations.23Table of ContentsOur future growth may be limited if we do not complete growth projects or make acquisitions.Our business strategy depends on our ability to complete growth projects and make acquisitions that increase cash generated from operations on a per unitbasis. We may be unable to complete successful, accretive growth projects or acquisitions for any of the following reasons, among others: •we fail to identify (or we are outbid for) attractive expansion or development projects or acquisition candidates that satisfy our economic and othercriteria;•we cannot raise financing for such projects or acquisitions on economically acceptable terms;•we fail to secure adequate customer commitments to use the facilities to be developed, expanded or acquired; or•we cannot obtain governmental approvals or other rights, licenses or consents needed to complete such projects or acquisitions on time or on budget,if at all.The development and construction of gathering, processing, storage and transportation facilities involves numerous regulatory, environmental, safety, politicaland legal uncertainties beyond our control and may require the expenditure of significant amounts of capital. When we undertake these projects, they may notbe completed on schedule, at the budgeted cost or at all. Moreover, our revenues may not increase immediately upon the expenditure of funds on a particulargrowth project. For instance, if we build a new gathering system or transmission pipeline, the construction may occur over an extended period of time and wewill not receive material increases in revenues until the project is placed in service. Accordingly, if we do pursue growth projects, we can provide noassurances that our efforts will provide a platform for additional growth for our company.The growth projects and acquisitions we complete may not perform as anticipated.Even if we complete acquisitions or growth projects that we believe will be strategic and accretive, such acquisitions and projects may nevertheless reduce ourcash available for distribution due to the following factors, among others: •mistaken assumptions about capacity, revenues, synergies, costs (including operating and administrative, capital, debt and equity costs), customerdemand, growth potential, assumed liabilities and other factors;•the failure to receive cash flows from a growth project or newly acquired asset due to delays in the commencement of operations for any reason;•unforeseen operational issues or the realization of liabilities that were not known to us at the time the acquisition or growth project was completed;•the inability to attract new customers or retain acquired customers to the extent assumed in connection with an acquisition or growth project;•the failure to successfully integrate growth projects or acquired assets or businesses into our operations and/or the loss of key employees; or•the impact of regulatory, environmental, political and legal uncertainties that are beyond our control. In particular, we may construct facilities to capture anticipated future growth in production and/or demand in a region in which such growth does notmaterialize. As a result, new facilities may not be able to attract enough throughput to achieve our expected investment return, which could adversely affect ourbusiness, financial condition, results of operations and ability to make distributions.If we complete future growth projects or acquisitions, our capitalization and results of operations may change significantly, and you will not have theopportunity to evaluate the economic, financial and other relevant information that we will consider in determining the application of these funds and otherresources. If any growth projects or acquisitions we ultimately complete are not accretive to our cash available for distribution, our ability to makedistributions may be reduced. Our failure to successfully and timely integrate acquired companies and assets into our organization could adversely affect our results ofoperation.The success of the Crestwood Merger and our recent acquisitions (including our Arrow acquisition) will depend, in part, on our ability to realize theanticipated benefits and synergies from combining (i) the businesses of Legacy Inergy and Legacy Crestwood and (ii) our company and our acquisitiontargets. If our combined organization is unable to achieve these objectives, or is not able to achieve these objectives on a timely basis, the anticipated benefits ofthe Crestwood Merger and our acquisitions may not be realized fully or at all. Additional unanticipated costs may be incurred in the integration of thebusinesses. There can be no assurance that the elimination of certain duplicative costs, as well as the realization of other efficiencies related to the integration ofthe two businesses, will offset the incremental transaction-related costs over time. These integration difficulties could adversely affect the future results of thecombined organization.24Table of ContentsWe rely upon third-party assets to operate our facilities, and we could be negatively impacted by circumstances beyond our control that temporarilyor permanently interrupt the operation of such third-party assets.Our operations depend on assets owned and controlled by third parties to operate effectively. For example, (i) certain of our “rich gas” gathering systemsdepend on interconnections and processing plants owned by third parties for us to move gas off our systems; (ii) our crude oil rail terminals depend onrailroad companies to move our customers’ crude oil to market; and (iii) our natural gas storage facilities rely on third-party interconnections and pipelines toreceive and deliver natural gas. Since we do not own or operate these third-party facilities, their continuing operation is outside of our control. If third-partyfacilities become unavailable or constrained, or other downstream facilities utilized to move our customers’ product to their end destination becomeunavailable, it could have a material adverse effect on our business, financial condition, results of operations, and ability to make distributions.In addition, the rates charged by processing plants, pipelines and other facilities interconnected to our assets affect the utilization and value of our services.Significant changes in the rates charged by these third parties, or the rates charged by the third parties that own “downstream” assets required to movecommodities to their final destinations, could have a material adverse effect on our business, financial condition, results of operations and ability to makedistributions.We depend on a limited number of customers for a substantial portion of our revenues.We generate a substantial portion of our gathering revenue from a limited number of oil and gas producers. Within our G&P segment, the top five producers(including Antero in the Marcellus Shale and Quicksilver in the Barnett Shale) accounted for approximately 17% of our total consolidated revenues in 2013.Within our NGL and crude services segment, seven producers on our Arrow system in the Bakken Shale accounted for approximately 15% of our totalconsolidated revenues in 2013. We expect our gathering revenues to remain leveraged to a limited number of producers in 2014 as we continue to build out ourgathering systems, particularly in the Marcellus, Bakken and PRB Niobrara.Although we have obtained acreage dedications from many producer customers, most of our gathering contracts do not contain minimum volume requirementsthat would protect us against volumetric risks associated with lower-than-forecast volumes flowing through our systems. Our producer customers do not havecontractual obligations to develop their properties in the areas covered by our acreage dedications, and they may determine that it is more attractive to directtheir capital spending and resources to other areas. A decrease in producer capital spending and reserves in the areas covered by our acreage dedications withour significant gathering customers could result in reduced volumes serviced by us and a material decline in our revenue and cash flow.Our gathering and processing operations depend, in part, on drilling and production decisions of others.Our gathering and processing operations are dependent on the continued availability of natural gas and crude oil production. We have no control over the levelof drilling activity in our areas of operation, the amount of reserves associated with wells connected to our systems, or the rate at which production from a welldeclines. Our gathering systems are connected to wells whose production will naturally decline over time, which means that our cash flows associated withthese wells will decline over time. To maintain or increase throughput levels on our gathering systems and utilization rates at our natural gas processing plants,we must continually obtain new natural gas and crude oil supplies. Our ability to obtain additional sources of natural gas and crude oil primarily depends onthe level of successful drilling activity near our systems, our ability to compete for volumes from successful new wells, and our ability to expand our systemcapacity as needed. If we are not able to obtain new supplies of natural gas and crude oil to replace the natural decline in volumes from existing wells,throughput on our gathering and processing facilities would decline, which could have a material adverse affect on our results of operations and distributablecash flow. Although we have acreage dedications from customers that include certain producing and non-producing oil and gas properties, our customers are notcontractually required to develop the reserves and or properties they have dedicated to us. We have no control over producers or their drilling and productiondecisions in our areas of operations, which are affected by, among other things, (i) the availability and cost of capital; (ii) prevailing and projected commodityprices; (iii) demand for natural gas, NGLs and crude oil, (iv) levels of reserves and geological considerations, (v) governmental regulations, including theavailability of drilling permits and the regulation of hydraulic fracturing; and (vi) the availability of drilling rigs and other development services. Fluctuationsin energy prices can also greatly affect the development of oil and gas reserves. Drilling and production activity generally decreases as commodity pricesdecrease, and sustained declines in commodity prices could lead to a material decrease in such activity. Because of these factors, even if oil and gas reservesare known to exist in areas25Table of Contentsserved by our assets, producers may choose not to develop those reserves. Reductions in exploration or production activity in our areas of operations could leadto reduced utilization of our systems.Estimates of oil and gas reserves depend on many assumptions that may turn out to be inaccurate, and future volumes on our gathering systemsmay be less than anticipated.We normally do not obtain independent evaluations of natural gas or crude oil reserves connected to our gathering systems. We therefore do not haveindependent estimates of total reserves dedicated to our systems or the anticipated life of such reserves. It often takes producers longer periods of time todetermine how to efficiently develop and produce hydrocarbons from unconventional shale plays than conventional basins, which can result in lower volumesbecoming available as soon as expected in the shale plays in which we operate. If the total reserves or estimated life of the reserves connected to our gatheringsystems is less than anticipated and we are unable to secure additional sources of natural gas or crude oil, it could have a material adverse effect on ourbusiness, results of operations and financial condition.We have limited experience in the crude oil gathering business.We acquired the Arrow gathering system in November 2013, which serves customers producing crude oil and rich gas from the Bakken Shale formation. TheArrow system is the first crude oil and produced water gathering system that we have been required to build out and operate. Other operators of gatheringsystems in the Bakken have more experience in the construction, operation and maintenance of crude oil gathering systems than we do. Our lack of experiencemay hinder our ability to fully implement our business plan in a timely and cost-effective manner, which may adversely affect our results of operations andability to make distributions.Our industry is highly competitive, and increased competitive pressure could adversely affect our ability to execute our growth strategy.We compete with other energy midstream enterprises, some of which are much larger and have significantly greater financial resources or operating experience,in our areas of operation. Our competitors may expand or construct infrastructure that creates additional competition for the services we provide to customers.Our ability to renew or replace existing contracts with our customers at rates sufficient to maintain current revenues and cash flow could be adversely affectedby the activities of our competitors and our customers. All of these competitive pressures could have a material adverse effect on our business, results ofoperations, financial condition and ability to make distributions.Our level of indebtedness could adversely affect our ability to raise additional capital to fund operations, limit our ability to react to changes in ourbusiness or industry, and place us at a competitive disadvantage.We had approximately $2.3 billion of long-term debt outstanding as of December 31, 2013. Our inability to generate sufficient cash flow to satisfy debtobligations or to obtain alternative financing could materially and adversely affect our business, results of operations, financial condition and businessprospects.Our substantial debt could have important consequences to our unitholders. For example, it could:•increase our vulnerability to general adverse economic and industry conditions;•limit our ability to fund future capital expenditures and working capital, to engage in development activities, or to otherwise realize the value of ourassets and opportunities fully because of the need to dedicate a substantial portion of our cash flow from operations to payments of interest andprincipal on our debt or to comply with any restrictive covenants or terms of our debt;•result in an event of default if we fail to satisfy debt obligations or fail to comply with the financial and other restrictive covenants contained in theagreements governing our indebtedness, which event of default could result in all of our debt becoming immediately due and payable and couldpermit our lenders to foreclose on any of the collateral securing such debt;•require a substantial portion of cash flow from operations to be dedicated to the payment of principal and interest on our indebtedness, thereforereducing our ability to use cash flow to fund operations, capital expenditures and future business opportunities;•increase our borrowings;26Table of Contents•restrict us from making strategic acquisitions or causing us to make non-strategic divestitures;•limit our flexibility in planning for, or reacting to, changes in our business or industry in which we operate, placing us at a competitive disadvantagecompared to our peers who are less highly leveraged and who therefore may be able to take advantage of opportunities that our leverage prevents usfrom exploring; and•impair our ability to obtain additional financing in the future.Realization of any of these factors could adversely affect our financial condition, results of operations and cash flows.Restrictions in our revolving credit facilities could adversely affect our business, financial condition, results of operations and ability to makedistributions. We have a $550 million revolving credit facility that matures in July 2016. Our revolving credit facility will be available to fund working capital and ourgrowth projects, make acquisitions and for general partnership purposes. Crestwood Midstream has a $1 billion revolving credit facility (expandable up to$1.25 billion) that matures in October 2018. Crestwood Midstream’s revolving credit facility will be available to fund working capital and its growthprojects, make acquisitions and for general partnership purposes. Our revolving credit facilities contain various covenants and restrictive provisions that will limit our ability to, among other things: •incur additional debt;•make distributions on or redeem or repurchase units;•make certain investments and acquisitions;•incur or permit certain liens to exist;•enter into certain types of transactions with affiliates;•merge, consolidate or amalgamate with another company; and•transfer or otherwise dispose of assets. Furthermore, our revolving credit facilities contain covenants requiring us to maintain certain financial ratios. For example, (i) our revolving credit facilityrequires maintenance of a consolidated leverage ratio (as defined in our credit agreement) of not more than 5.00 to 1.00 and an interest coverage ratio (as definedin our credit agreement) of not less than 2.50 to 1.00, and (ii) Crestwood Midstream’s credit facility requires maintenance of a consolidated leverage ratio (asdefined in its credit agreement) of not more than 5.00 (and in certain instances, 5.50) to 1.00 and an interest coverage ratio (as defined in its credit agreement)of not less than 2.50 to 1.00.Borrowings under our revolving credit facility are secured by pledges of the equity interests of, and guarantees by, substantially all of our restricted domesticsubsidiaries, and liens on substantially all of our real and personal property. Borrowings under Crestwood Midstream’s revolving credit facility are securedby pledges of the equity interests of, and guarantees by, substantially all of its restricted domestic subsidiaries, and liens on substantially all of its realproperty (outside of New York) and personal property.The provisions of our credit agreements may affect our ability to obtain future financing and pursue attractive business opportunities and our flexibility inplanning for, and reacting to, changes in business conditions. In addition, a failure to comply with the provisions of our revolving credit facilities could resultin events of default, which could enable our lenders, subject to the terms and conditions of credit agreements, to declare any outstanding principal of that debt,together with accrued interest, to be immediately due and payable. If the payment of any such debt is accelerated, our assets (and, with respect to CrestwoodMidstream’s revolver, Crestwood Midstream’s assets) may be insufficient to repay such debt in full, and the holders of our common units could experience apartial or total loss of their investment.A change of control could result in us facing substantial repayment obligations under our revolving credit facilities.Our credit agreements contain provisions relating to change of control of our general partners and our partnerships. If these provisions are triggered, ouroutstanding bank indebtedness may become due. In such an event, there is no assurance that we would be able to pay the indebtedness, in which case thelenders under our revolving credit facilities would have the right to foreclose on our assets, which would have a material adverse effect on us. There is norestriction on the ability of our general partner or its parent companies to enter into a transaction which would trigger the change of control provisions, andthere are27Table of Contentsno restrictions on our ability to enter into a transaction which would trigger Crestwood Midstream’s change of control provisions.Our ability to make cash distributions may be diminished, and our financial leverage could increase, if we are not able to obtain needed capital orfinancing on satisfactory terms.Historically, each of the Company and Crestwood Midstream have used cash flow from operations, borrowings under its respective revolving credit facilityand issuances of debt or equity to fund their respective capital programs, working capital needs and acquisitions. Our capital program may require additionalfinancing above the level of cash generated by our respective operations to fund growth. If our cash flow from operations decreases as a result of lowerthroughput volumes on our systems or otherwise, our ability to expend the capital necessary to expand our business or increase our future cash distributionsmay be limited. If our cash flow from operations is insufficient to satisfy our financing needs, we cannot be certain that additional financing will be availableto us on acceptable terms, if at all. Our ability to obtain bank financing or to access the capital markets for future equity or debt offerings may be limited byour financial condition or general economic conditions at the time of any such financing or offering. Even if we are successful in obtaining the necessaryfunds, the terms of such financings could have a material adverse effect on our business, results of operation, financial condition and ability to make cashdistributions to our unitholders. Further, incurring additional debt may significantly increase our interest expense and financial leverage and issuing additionallimited partner interests may result in significant unitholder dilution and would increase the aggregate amount of cash required to maintain the cashdistribution rate which could materially decrease our ability to pay distributions. If additional capital resources are unavailable, we may curtail our activitiesor be forced to sell some of our assets on an untimely or unfavorable basis.Debt we incur in the future may limit our flexibility to obtain financing and to pursue other business opportunities. Our future level of debt could have important consequences to us, including the following:•our ability to obtain additional financing, if necessary, for working capital, capital expenditures, acquisitions or other purposes may be impaired orsuch financing may not be available on favorable terms, if at all;•our funds available for operations, future business opportunities and distributions to common unitholders will be reduced by that portion of ourcash flow required to make interest payments on our debt;•we may be more vulnerable to competitive pressures or a downturn in our business or the economy generally; and•our flexibility in responding to changing business and economic conditions may be limited.Our ability to service our debt will depend upon, among other things, our future financial and operating performance, which will be affected by prevailingeconomic conditions and financial, business, regulatory and other factors, some of which are beyond our control. If our operating results are not sufficient toservice any future indebtedness, we will be forced to take actions such as reducing distributions, reducing or delaying our business activities, acquisitions,investments or capital expenditures, selling assets or seeking additional equity capital. We may not be able to effect any of these actions on satisfactory termsor at all. Increases in interest rates could adversely impact our unit price, ability to issue equity or incur debt for acquisitions or other purposes, and abilityto make payments on our debt obligations.Interest rates may increase in the future. As a result, interest rates on future credit facilities and debt offerings could be higher than current levels, causing ourfinancing costs to increase accordingly. Therefore, changes in interest rates either positive or negative, may affect the yield requirements of investors whoinvest in our units, and a rising interest rate environment could have an adverse impact on our unit price and our ability to issue equity or incur debt foracquisitions or other purposes and to make payments on our debt obligations.The loss of key personnel could adversely affect our ability to operate.Our success is dependent upon the efforts of our senior management team, as well as on our ability to attract and retain both executives and employees for ourfield operations. Our senior executives have significant experience in the oil and gas industry and have developed strong relationships with a broad range ofindustry participants. The loss of any of these executives, or the loss of key field employees operating in competitive markets like the Bakken Shale and theMarcellus Shale, could prevent us from implementing our business strategy and could have a material adverse effect on our customer relationships, results ofoperations and ability to make distributions.28Table of ContentsWe operate in the PRB Niobrara through joint ventures that may limit our operational flexibility.Our operations in the PRB Niobrara are conducted through joint venture arrangements (including the Jackalope and PRBIC joint ventures), and we may enteradditional joint ventures in the future. In a joint venture arrangement, we could have less operational flexibility, as actions must be taken in accordance withthe applicable governing provisions of the joint venture. In certain cases, we:•could have limited ability to influence or control certain day to day activities affecting the operations;•could have limited control on the amount of capital expenditures that we are required to fund with respect to these operations;•could be dependent on third parties to fund their required share of capital expenditures;•may be subject to restrictions or limitations on our ability to sell or transfer our interests in the jointly owned assets; and•may be forced to offer rights of participation to other joint venture participants in certain areas of mutual interest.In addition, our joint venture participants may have obligations that are important to the success of the joint venture, such as the obligation to pay substantialcarried costs pertaining to the joint venture and to pay their share of capital and other costs of the joint venture. The performance and ability of the third partiesto satisfy their obligations under joint venture arrangements is outside of our control. If these parties do not satisfy their obligations, our business may beadversely affected. Our joint venture partners may be in a position to take actions contrary to our instructions or requests or contrary to our policies orobjectives, and disputes between us and our joint venture partners may result in delays, litigation or operational impasses. The risks described above or thefailure to continue our joint ventures or to resolve disagreements with our joint venture partners could adversely affect our ability to conduct business that isthe subject of a joint venture, which could in turn negatively affect our financial condition and results of operations.We may not be able to renew or replace expiring contracts. Our primary exposure to market risk occurs at the time our existing contracts expire and are subject to renegotiation and renewal. As of December 31, 2013, theweighted average remaining term of (i) our existing portfolio of natural gas storage and transportation contracts is approximately four years, (ii) our existingportfolio of natural gas gathering contracts is approximately 11 years, and (iii) our existing portfolio of crude oil gathering contracts is approximately fiveyears. Customer contracts totaling 8.3 Bcf will expire in 2014. The extension or replacement of existing contracts depends on a number of factors beyond ourcontrol, including:•the macroeconomic factors affecting natural gas, NGL and crude economics for our current and potential customers;•the level of existing and new competition to provide services to our markets;•the balance of supply and demand, on a short-term, seasonal and long-term basis, in our markets;•the extent to which the customers in our markets are willing to contract on a long-term basis; and•the effects of federal, state or local regulations on the contracting practices of our customers.Any failure to extend or replace a significant portion of our existing contracts, or extending or replacing them at unfavorable or lower rates, could have amaterial adverse effect on our business, financial condition, results of operations and ability to make distributions. The fees we charge to customers under our contracts may not escalate sufficiently to cover our cost increases, and those contracts may besuspended in some circumstances. Our costs may increase at a rate greater than the rate that the fees we charge to third parties increase pursuant to our contracts with them. In addition, somethird parties’ obligations under their agreements with us may be permanently or temporarily reduced upon the occurrence of certain events, some of which arebeyond our control, including force majeure events wherein the supply of natural gas or crude oil is curtailed or cut off. Force majeure events generally include,without limitation, revolutions, wars, acts of enemies, embargoes, import or export restrictions, strikes, lockouts, fires, storms, floods, acts of God,explosions, mechanical or physical failures of our equipment or facilities or those of third parties. If our escalation of fees is insufficient to cover increasedcosts or if any third party suspends or terminates its contracts with us, our business, financial condition, results of operations and ability to makedistributions could be materially adversely affected.29Table of ContentsOur operations are subject to extensive regulation, and regulatory measures adopted by regulatory authorities could have a material adverse effecton our business, financial condition and results of operations. Our operations are subject to extensive regulation by federal, state and local regulatory authorities. For example, because we transport natural gas in interstatecommerce and we store natural gas that is transported in interstate commerce, our natural gas storage and transportation facilities are subject to comprehensiveregulation by the FERC under the Natural Gas Act. Federal regulation under the Natural Gas Act extends to such matters as: •rates, operating terms and conditions of service;•the form of tariffs governing service;•the types of services we may offer to our customers;•the certification and construction of new, or the expansion of existing, facilities;•the acquisition, extension, disposition or abandonment of facilities;•contracts for service between storage and transportation providers and their customers;•creditworthiness and credit support requirements;•the maintenance of accounts and records;•relationships among affiliated companies involved in certain aspects of the natural gas business;•the initiation and discontinuation of services; and•various other matters. Natural gas companies may not charge rates that, upon review by FERC, are found to be unjust and unreasonable or unduly discriminatory. Existinginterstate transportation and storage rates may be challenged by complaint and are subject to prospective change by FERC. Additionally, rate increasesproposed by a regulated pipeline or storage provider may be challenged and such increases may ultimately be rejected by FERC. We currently hold authorityfrom FERC to charge and collect (i) market-based rates for interstate storage services provided at the Stagecoach, Thomas Corners, Seneca Lake, Steuben andTres Palacios facilities and (ii) negotiated rates for interstate transportation services provided by our North-South Facilities and MARC I Pipeline. FERC's“market-based rate” policy allows regulated entities to charge rates different from, and in some cases, less than, those which would be permitted undertraditional cost-of-service regulation. Among the sorts of changes in circumstances that could raise market power concerns would be an expansion of capacity,acquisitions or other changes in market dynamics. There can be no guarantee that we will be allowed to continue to operate under such rate structures for theremainder of those assets' operating lives. Any successful challenge against rates charged for our storage and transportation services, or our loss of market-based rate authority or negotiated rate authority, could have a material adverse effect on our business, financial condition, results of operations and ability tomake distributions. Our market-based rate authority for our natural gas storage facilities may be subject to review and possible revocation if FERC determinesthat we have the ability to exercise market power in our market area. If we were to lose our ability to charge market-based rates, we would be required to filerates based on our cost of providing service, including a reasonable rate of return. Cost-of-service rates may be lower than our current market-based rates. There can be no assurance that FERC will continue to pursue its approach of pro-competitive policies as it considers matters such as pipeline rates and rulesand policies that may affect rights of access to natural gas transportation capacity and transportation and storage facilities. Failure to comply with applicableregulations under the Natural Gas Act, the Natural Gas Policy Act of 1978, the Pipeline Safety Act of 1968 and certain other laws, and with implementingregulations associated with these laws, could result in the imposition of administrative and criminal remedies and civil penalties of up to $1,000,000 per day,per violation.A change in the jurisdictional characterization of our gathering assets may result in increased regulation, which could cause our revenues todecline and operating expenses to increase.Our natural gas and crude oil gathering operations are generally exempt from the jurisdiction and regulation of the FERC, except for certain anti-marketmanipulation provisions. FERC regulation nonetheless affects our businesses and the markets for products derived from our gathering businesses. TheFERC’s policies and practices across the range of its oil and gas regulatory activities, including, for example, its policies on open access transportation, ratemaking, capacity release and market center promotion, indirectly affect intrastate markets. In recent years, the FERC has pursued pro-competitive policies inits regulation of interstate oil and natural gas pipelines. However, we have no assurance that the FERC will continue this approach as it considers matters suchas pipeline rates and rules and policies that may affect rights of access to oil and natural gas transportation capacity. In addition, the distinction betweenFERC-regulated transmission services and federally unregulated gathering services has regularly been the subject of substantial, on-going litigation.Consequently, the classification and regulation of some of our pipelines could change based on future determinations by the FERC, the courts or Congress. If30Table of Contentsour gathering operations become subject to FERC jurisdiction, the result may adversely affect the rates we are able to charge and the services we currentlyprovide, and may include the potential for a termination of certain gathering agreements.State and municipal regulations also impact our business. Common purchaser statutes generally require gatherers to gather or provide services without unduediscrimination as to source of supply or producer; as a result, these statutes restrict our right to decide whose production we gather or transport. Federal lawleaves any economic regulation of natural gas gathering to the states. The states in which we currently operate have adopted complaint-based regulation ofgathering activities, which allows oil and gas producers and shippers to file complaints with state regulators in an effort to resolve access and rate grievances.Other state and municipal regulations may not directly regulate our gathering business, but may nonetheless affect the availability of natural gas for purchase,processing and sale, including state regulation of production rates and maximum daily production allowable from gas wells. While our gathering linescurrently are subject to limited state regulation, there is a risk that state laws will be changed, which may give producers a stronger basis to challenge the rates,terms and conditions of its gathering lines. Our operations are subject to compliance with environmental and operational safety laws and regulations that may expose us to significant costsand liabilities. Our operations are subject to stringent federal, regional, state and local laws and regulations governing health and safety aspects of our operations, thedischarge of materials into the environment or otherwise relating to environmental protection. Such environmental laws and regulations impose numerousobligations that are applicable to our operations, including the acquisition of permits to conduct regulated activities, the incurrence of capital expenditures tocomply with applicable legal requirements, the application of specific health and safety criteria addressing worker protections and the imposition ofrestrictions on the generation, handling, treatment, storage, disposal and transportation of materials and wastes. Failure to comply with such environmentallaws and regulations can result in the assessment of substantial administrative, civil and criminal penalties, the imposition of remedial liabilities and theissuance of injunctions restricting or prohibiting some or all of our activities. Certain environmental laws impose strict, joint and several liability for costsrequired to clean up and restore sites where materials or wastes have been disposed or otherwise released. In the course of our operations, generated materials orwastes may have been spilled or released from properties owned or leased by us or on or under other locations where these materials or wastes have been takenfor recycling or disposal. It is also possible that adoption of stricter environmental laws and regulations or more stringent interpretation of existing environmental laws and regulations inthe future could result in additional costs or liabilities to us as well as the industry in general or otherwise adversely affect demand for our services and saltproducts. It is also possible that adoption of stricter environmental laws and regulations or more stringent interpretation of existing environmental laws andregulations in the future could result in additional costs or liabilities to us or our customers and also adversely affect demand for the natural gas, NGLs, crudeoil or salt products.Climate change legislation or regulations restricting emissions of greenhouse gases could result in increased operating and capital costs andreduced demand for our services. In December 2009, the EPA determined that emissions of carbon dioxide, methane and other greenhouse gases (GHGs) present an endangerment to publichealth and the environment because emissions of such gases are, according to the EPA, contributing to warming of the earth's atmosphere and other climaticchanges. Based on these findings, the EPA has begun adopting and implementing regulations to restrict emissions of GHGs under existing provisions of thefederal Clean Air Act. The EPA has adopted two sets of rules regulating GHG emissions under the Clean Air Act, one of which requires a reduction inemissions of GHGs from motor vehicles and the other of which regulates emissions of GHGs from certain large stationary sources, effective January 2, 2011,which could require greenhouse emission controls for those sources. The EPA has also adopted rules requiring the reporting of GHG emissions from specifiedlarge GHG emission sources on an annual basis, beginning in 2011 for emissions occurring after January 1, 2010, as well as certain onshore oil and naturalgas production, processing, transmission, storage and distribution facilities on an annual basis, beginning in 2012 for emissions occurring in 2011. In addition, the U.S. Congress has from time to time considered adopting legislation to reduce emissions of GHGs, and almost one-half of the states havealready taken legal measures to reduce emissions of GHGs primarily through the planned development of GHG emission inventories and/or regional GHG capand trade programs. Most of these cap and trade programs work by requiring major sources of emissions, such as electric power plants, or major producersof fuels, such as refineries and gas processing plants, to acquire and surrender emission allowances. The number of allowances available for purchase isreduced each year in an effort to achieve the overall GHG emission reduction goal. 31Table of ContentsThe adoption of legislation or regulatory programs to reduce emissions of GHGs could require us to incur increased operating costs, such as costs to purchaseand operate emissions control systems, to acquire emissions allowances or comply with new regulatory or reporting requirements. Any such legislation orregulatory programs could also increase the cost of consuming, and thereby reduce demand for, the oil and natural gas that is produced, which may decreasedemand for our midstream services. Consequently, legislation and regulatory programs to reduce emissions of GHGs could have an adverse effect on ourbusiness, financial condition and results of operations. We may incur higher costs as a result of pipeline integrity management program testing and additional safety legislation.The DOT requires pipeline operators to develop integrity management programs for pipelines located where a leak or rupture could harm “high consequenceareas.” The regulations require operators like us to:•perform ongoing assessments of pipeline integrity;•identify and characterize applicable threats to pipeline segments that could impact a high consequence area;•maintain processes for data collection, integration and analysis;•repair and remediate pipelines as necessary; and•implement preventive and mitigating actions.We estimate that the total future costs to complete the testing required by existing DOT regulations will not have a material impact to our results. This estimatedoes not include the costs, if any, for repair, remediation, preventative or mitigating actions that may be determined to be necessary as a result of the testingprogram itself.Moreover, the Pipeline Safety, Regulatory Certainty and Job Creation Act of 2011 was enacted by Congress in December 2011 and signed into law by thePresident on January 3, 2012. In addition to reauthorizing federal pipeline safety programs through 2015, this legislation adopts additional safety requirementsand reforms and increases penalties for safety violations. The PHMSA has also published an advanced notice of proposed rule making to solicit comments onthe need for changes to its safety regulations, including whether to revise the integrity management requirements and add new regulations governing the safetyof gathering lines. Such legislative and regulatory changes could have a material effect on our operations through more stringent and comprehensive safetyregulations and higher penalties for the violation of those regulations.Our business involves many hazards and risks, some of which may not be fully covered by insurance.Our operations are subject to many risks inherent in gathering, processing, storage and transportation segments of the energy midstream industry, such as:•damage to pipelines and plants, related equipment and surrounding properties caused by natural disasters and acts of terrorism;•subsidence of the geological structures where we store natural gas or NGLs, or storage cavern collapses;•operator error;•inadvertent damage from construction, farm and utility equipment;•leaks, migrations or losses of natural gas, NGLs or crude oil;•fires and explosions;•cyber intrusions; and•other hazards that could also result in personal injury, loss of life, pollution (including environmental pollution) or suspension of operations.These risks could result in substantial losses due to breaches of contractual commitments, personal injury and/or loss of life, damage to and destruction ofproperty and equipment and pollution or other environmental damage. These risks may also result in curtailment or suspension of our operations. A naturaldisaster or other hazard affecting the areas in which we operate could have a material adverse effect on our operations. We are not fully insured against all risksinherent in our business. For example, we do not have any property insurance on any of our underground pipeline systems that would cover damage to thepipelines. We are also not insured against all environmental accidents that might occur, some of which may result in toxic tort claims. If a significant accidentor event occurs for which we are not fully insured, it could result in a material adverse effect on our business, financial condition, results of operations andability to make distributions.We may not be able to maintain or obtain insurance of the type and amount we desire at reasonable rates. As a result of market conditions, premiums anddeductibles for certain of our insurance policies may substantially increase. In some instances, certain insurance could become unavailable or available onlyfor reduced amounts of coverage. Additionally, we may be unable to recover from prior owners of our assets, pursuant to our indemnification rights, forpotential environmental liabilities.32Table of ContentsAlthough we maintain insurance policies with insurers in such amounts and with such coverages and deductibles as we believe are reasonable and prudent,our insurance may not be adequate to protect us from all material expenses related to potential future claims for personal injury and property damage.We do not own all of the land on which our pipelines and facilities are located, which could disrupt our operations.We do not own all of the land on which our pipelines and facilities (particularly our gathering and process facilities) have been constructed, which subjects usto the possibility of more onerous terms or increased costs to obtain and maintain valid easements and rights-of-way. We obtain standard easement rights toconstruct and operate its pipelines on land owned by third parties, and our rights frequently revert back to the landowner after we stop using the easement forits specified purpose. Therefore, these easements exist for varying periods of time. Our loss of easement rights could have a material adverse effect on our ability to operate ourbusiness, thereby resulting in a material reduction in our revenue, earnings and ability to make distributions.Risks Inherent in an Investment in UsWe may not have sufficient cash from operations following the establishment of cash reserves and payment of fees and expenses to enable us topay quarterly distributions to our common unitholders. We may not have sufficient cash each quarter to pay quarterly distributions to our common unitholders. The amount of cash we can distribute on ourcommon units principally depends upon the amount of cash we generate from our operations and payments of fees and expenses. Before we pay anydistributions on our common units, we will establish reserves and pay fees and expenses, including reimbursements to our general partner and its affiliates,for all expenses they incur and payments they make on our behalf. These costs will reduce the amount of cash available to pay distributions to our commonunitholders. The amount of cash we can distribute on our common units will fluctuate from quarter to quarter based on, among other things: •the amount of cash distributions we receive in connection with our ownership of 100% of Crestwood Midstream’s IDRs;•the rates we charge for storage and transportation services and the amount of services our customers purchase from us, which will be affected by,among other things, the overall balance between the supply of and demand for commodities, governmental regulation of our rates and services, andour ability to obtain permits for growth projects;•force majeure events that damage our or third-party pipelines, facilities, related equipment and surrounding properties;•prevailing economic and market conditions;•governmental regulation, including changes in governmental regulation in our industry;•changes in tax laws;•the level of competition from other midstream companies;•the level of our operating and maintenance and general administrative costs;•the level of capital expenditures we make;•our ability to make borrowings under our revolving credit facility; and•the cost of acquisitions.In addition, the actual amount of cash we will have available for distribution will depend on other factors, some of which are beyond our control, including:the level and timing of capital expenditures we make; the cost of acquisitions; our debt service requirements and other liabilities; fluctuations in our workingcapital needs; our ability to borrow funds and access capital markets; restrictions contained in our debt agreements; and the amount of cash reservesestablished by our general partner.Our partnership agreement requires that we distribute all of our available cash, which could limit our ability to grow and make acquisitions. We expect that we will distribute all of our available cash to our common unitholders and will rely primarily upon external financing sources, includingcommercial bank borrowings and the issuance of debt and equity securities, to fund our acquisitions and expansion capital expenditures. As a result, to theextent we are unable to finance growth externally, our cash distribution policy will significantly impair our ability to grow. In addition, because we distribute all of our available cash, our growth may not be as fast as that of businesses that reinvest their available cash to expandongoing operations. To the extent we issue additional units in connection with any acquisitions or expansion capital expenditures, the payment of distributionson those additional units may increase the risk that we will be33Table of Contentsunable to maintain or increase our per unit distribution level. There are no limitations in our partnership agreement on our ability to issue additional units,including units ranking senior to the common units. The incurrence of additional commercial borrowings or other debt to finance our growth strategy wouldresult in increased interest expense, which, in turn, may impact the available cash that we have to distribute to our common unitholders.We may issue additional units without common unitholder approval, which would dilute existing common unitholder ownership interests. Our partnership agreement does not limit the number of additional limited partner interests we may issue at any time without the approval of our existingcommon unitholders. The issuance of additional common units or other equity interests of equal or senior rank will have the following effects:•our existing common unitholders' proportionate ownership interest in us will decrease; •the amount of cash available for distribution on each common unit may decrease; •the ratio of taxable income to distributions may increase; •the relative voting strength of each previously outstanding common unit may be diminished; and •the market price of the common units may decline.Holders of our common units have limited voting rights and are not entitled to elect our general partner or its directors, which could reduce theprice at which our common units will trade. Unlike the holders of common stock in a corporation, our common unitholders have only limited voting rights on matters affecting our business and,therefore, limited ability to influence management's decisions regarding our business. Our common unitholders will have no right on an annual or ongoingbasis to elect our general partner or its board of directors. The board of directors of our general partner, including the independent directors, is chosen entirelyby Crestwood Holdings, as a result of it owning our general partner, and not by our common unitholders. Unlike publicly traded corporations, we will notconduct annual meetings of our common unitholders to elect directors or conduct other matters routinely conducted at annual meetings of stockholders ofcorporations. As a result of these limitations, the price at which the common units will trade could be diminished because of the absence or reduction of atakeover premium in the trading price.Common unitholders may have liability to repay distributions and in certain circumstances may be personally liable for the obligations of thepartnership. Under certain circumstances, common unitholders may have to repay amounts wrongfully returned or distributed to them. Under Section 17-607 of theDelaware Revised Uniform Limited Partnership Act (the "Delaware Act"), we may not make a distribution to our common unitholders if the distribution wouldcause our liabilities to exceed the fair value of our assets. Delaware law provides that for a period of three years from the date of the impermissible distribution,limited partners who received the distribution and who knew at the time of the distribution that it violated Delaware law will be liable to the limited partnershipfor the distribution amount. A purchaser of units who becomes a limited partner is liable for the obligations of the transferring limited partner to makecontributions to the partnership that are known to the purchaser of units at the time it became a limited partner and for unknown obligations if the liabilitiescould be determined from the partnership agreement. Liabilities to partners on account of their partnership interests and liabilities that are non-recourse to thepartnership are not counted for purposes of determining whether a distribution is permitted. It may be determined that the right, or the exercise of the right by the limited partners as a group, to (i) remove or replace our general partner, (ii) approve someamendments to our partnership agreement or (iii) take other action under our partnership agreement constitutes “participation in the control” of our business. Alimited partner that participates in the control of our business within the meaning of the Delaware Act may be held personally liable for our obligations underthe laws of Delaware to the same extent as our general partner. This liability would extend to persons who transact business with us under the reasonable beliefthat the limited partner is a general partner. Neither our partnership agreement nor the Delaware Act specifically provides for legal recourse against our generalpartner if a limited partner were to lose limited liability through any fault of our general partner.The amount of cash we have available for distribution to common unitholders depends primarily on our cash flow and not solely on profitability,which may prevent us from making cash distributions during periods when we record net income. The amount of cash we have available for distribution depends primarily upon our cash flow (the majority of which consists of the cash distributions wereceive in connection with our ownership of 100% of Crestwood Midstream’s IDRs), including cash flow from reserves and working capital or otherborrowings, and not solely on profitability, which will be affected by non-cash34Table of Contentsitems. As a result, we may pay cash distributions during periods when we record net losses for financial accounting purposes and may not pay cashdistributions during periods when we record net income.Our partnership agreement restricts the voting rights of unitholders owning 20% or more of our common units. Our partnership agreement restricts unitholders' voting rights by providing that any units held by a person or group that owns 20% or more of any class ofunits then outstanding, other than our general partner and its affiliates, their transferees and persons who acquired such units with the prior approval of theboard of directors of our general partner, cannot vote on any matter.Crestwood Holdings and its affiliates may sell common units in the public or private markets, and such sales could have an adverse impact on thetrading price of the common units.As of December 31, 2013, Crestwood Holdings and its affiliates beneficially held an aggregate of 53,809,398 limited partner units. The sale of any or all ofthese units in the public or private markets could have an adverse impact on the price of the common units or on any trading market on which the commonunits are traded.Risks Inherent in Our Structure and Relationship with Crestwood MidstreamOur primary cash-generating assets are our partnership interests, including incentive distribution rights, in Crestwood Midstream, and our cashflow is therefore materially dependent upon the ability of Crestwood Midstream to make distributions in respect to those partnership interests to itspartners.The amount of cash that Crestwood Midstream can distribute to its partners each quarter, including us with respect to our IDRs, principally depends upon theamount of cash Crestwood Midstream generates from its operations, which amounts of cash may fluctuate from quarter to quarter based on, among otherthings:•the rates Crestwood Midstream charges for storage and transportation services and the amount of services their customers purchase from CrestwoodMidstream, which will be affected by, among other things, the overall balance between the supply of and demand for natural gas, governmentalregulation of Crestwood Midstream’s rates and services, and Crestwood Midstream’s ability to obtain permits for growth projects;•force majeure events that damage Crestwood Midstream’s or third-party pipelines, facilities, related equipment and surrounding properties;•prevailing economic and market conditions;•governmental regulation, including changes in governmental regulation in Crestwood Midstream’s industry;•leaks or accidental releases of products or other materials into the environment, whether as a result of human error or otherwise;•difficulties in Crestwood Midstream collecting receivables because of its customers’ credit or financial problems;•changes in tax laws;•the level of competition from other midstream energy companies;•the level of Crestwood Midstream’s operating and maintenance and general administrative costs;•the level of capital expenditures Crestwood Midstream makes;•the ability of Crestwood Midstream to make borrowings under its revolving credit facility; and•the cost of acquisitions.In addition, the actual amount of cash Crestwood Midstream will have available for distribution will depend on other factors, some of which are beyond itscontrol, including: the level and timing of capital expenditures it makes; the cost of acquisitions; its debt service requirements and other liabilities; fluctuationsin its working capital needs; its ability to borrow funds and access capital markets; restrictions contained in its debt agreements; and the amount of cashreserves established by its general partner.We do not have control over many of these factors, including the level of cash reserves established by the board of directors of Crestwood Midstream’s generalpartner. Accordingly, we cannot guarantee that Crestwood Midstream will have sufficient available cash to pay a specific level of cash distributions to itspartners.If Crestwood Midstream reduced its per unit distribution, we would have less cash available for distribution and would probably be required to reduce our perunit distribution. Furthermore, the amount of cash that Crestwood Midstream has available for distribution depends primarily upon its cash flow, includingcash flow from financial reserves and working capital borrowings, and is not solely a function of profitability, which will be affected by non-cash items. As aresult, Crestwood35Table of ContentsMidstream may be able to make cash distributions during periods when it records losses and may not be able to make cash distributions during periods whenit records net income.To the extent we purchase additional securities from Crestwood Midstream, our rate of growth may be reduced.Our business strategy may include supporting the growth of Crestwood Midstream by purchasing its securities or lending funds to Crestwood Midstream toprovide funding for acquisitions or internal growth projects. To the extent we purchase common units, the rate of our distribution growth may be reduced, atleast in the short term, as less of our cash distributions will come from our ownership of Crestwood Midstream’s IDRs, which distributions increase at afaster rate than those of our other securities.We could have an indemnification obligation to Crestwood Midstream, which could materially adversely affect our financial condition.We have entered into an omnibus agreement with Crestwood Midstream and its general partner that governs certain aspects of our relationship with them.Pursuant to the omnibus agreement, we are generally obligated to indemnify Crestwood Midstream and its affiliates against certain environmental liabilitiesand liabilities of the assets of the operations of Crestwood Midstream prior to December 21, 2011. See “Certain Relationships and Related Party Transactions-Omnibus Agreement.” Our indemnification obligations under the omnibus agreement could result in substantial expenses and liabilities to us, which couldmaterially adversely affect our financial condition.Unitholders have less ability to elect or remove management than holders of common stock in a corporation.Unlike the holders of common stock in a corporation, unitholders have only limited voting rights on matters affecting our business, and therefore limitedability to influence management’s decisions regarding our business. Unitholders did not elect, and do not have the right to elect, our general partner or its boardof directors on an annual or other continuing basis. The board of directors of our general partner is chosen by Crestwood Holdings LLC, the general partner ofthe sole member of our general partner, Crestwood Holdings LP (“Holdings LP”), which currently is the only voting member of the general partner of HoldingsLP, and effectively has the authority to appoint all of our directors. Although our general partner has a fiduciary duty to manage our partnership in a mannerbeneficial to us and our unitholders, the directors of our general partner also have a fiduciary duty to manage our general partner in a manner beneficial to itssole member, Holdings LP.If unitholders are dissatisfied with the performance of our general partner, they will have little ability to remove our general partner. Our general partnergenerally may not be removed except upon the vote of the holders of 66⅔% of the outstanding units voting together as a single class.Our unitholders’ voting rights are further restricted by a provision in our partnership agreement providing that any units held by a person that owns 20% ormore of any class of units then outstanding, other than our general partner and its affiliates, cannot be voted on any matter.The control of our general partner may be transferred to a third party without unitholder consent.Our general partner may transfer its general partner interest to a third party in a merger or in a sale of all or substantially all of its assets without the consent ofour unitholders. Furthermore, there is no restriction in our partnership agreement on the ability of the owner of our general partner, Holdings LP, fromtransferring its ownership interest in our general partner to a third party. The new owner of our general partner would then be in a position to replace the boardof directors and officers of our general partner with its own choices and to control the decisions taken by our board of directors and officers. This effectivelypermits a “change of control” without the vote or consent of the common unitholders.Cost reimbursements paid to our general partner may be substantial and may reduce our ability to pay the quarterly distribution.Before making any distributions on our units, we will reimburse our general partner for all expenses it has incurred on our behalf. In addition, our generalpartner and its affiliates may provide us with services for which we will be charged reasonable fees as determined by our general partner. The reimbursementof these expenses and the payment of these fees could adversely affect our ability to make distributions our unitholders. Our general partner has sole discretionto determine the amount of these expenses and fees.36Table of ContentsWe may issue additional common units without unitholder approval, which would dilute our unitholders’ existing ownership interests.We may issue an unlimited number of limited partner interests of any type without the approval of our unitholders. The issuance of additional common unitsor other equity securities of equal rank will have the following effects:•the proportionate ownership interest of our existing unitholders in us will decrease;•the amount of cash available for distribution on each common unit or partnership security may decrease;•the relative voting strength of each previously outstanding common unit will be diminished; and•the market price of the common units or partnership securities may decline.Crestwood Midstream may issue additional common units, which may increase the risk that it will not have sufficient available cash to maintain orincrease its per unit distribution level.The Crestwood Midstream partnership agreement allows it to issue an unlimited number of additional limited partner interests. The issuance of additionalcommon units or other equity securities by Crestwood Midstream will have the following effects:•Our unitholders’ current proportionate ownership interest in Crestwood Midstream will decrease;•the amount of cash available for distribution on each common unit or partnership security may decrease;•the ratio of taxable income to distributions may increase;•the relative voting strength of each previously outstanding common unit may be diminished; and•the market price of Crestwood Midstream’s common units may decline.The payment of distributions on any additional units issued by Crestwood Midstream may increase the risk that Crestwood Midstream may not havesufficient cash available to maintain or increase its per unit distribution level, which in turn may impact the available cash that we have to meet ourobligations.If we cease to manage and control Crestwood Midstream in the future, we may be deemed to be an investment company under the InvestmentCompany Act of 1940.If we cease to manage and control Crestwood Midstream and are deemed to be an investment company under the Investment Company Act of 1940 (the“Investment Company Act”) we would either have to register as an investment company under the Investment Company Act, obtain exemptive relief from theSecurities and Exchange Commission or modify our organizational structure or our contract rights to fall outside the definition of an investment company.Registering as an investment company could, among other things, materially limit our ability to engage in transactions with affiliates, including the purchaseand sale of certain securities or other property to or from our affiliates, restrict our ability to borrow funds or engage in other transactions involving leverageand require us to add additional directors who are independent of us or our affiliates.Moreover, treatment of us as an investment company would prevent our qualification as a partnership for federal income tax purposes, in which case wewould be treated as a corporation for federal income tax purposes. For further discussion of the importance of our treatment as a partnership for federal incometax purposes and the implications that would result from our treatment as a corporation in any taxable year, please read the risk factor below entitled “The taxtreatment of publicly traded partnerships is subject to potential legislative, judicial or administrative changes. If we or Crestwood Midstream were treated as acorporation for federal income tax purposes, or if we or Crestwood Midstream were to become subject to a material amount of state or local taxation, then ourcash available for distribution to our unitholders would be substantially reduced.Although we control Crestwood Midstream through our ownership of its general partner, Crestwood Midstream’s general partner owes fiduciaryduties to Crestwood Midstream’s unitholders, which may conflict with our interests.Conflicts of interest exist and may arise in the future as a result of the relationships between us and our affiliates, on the one hand, and Crestwood Midstreamand its limited partners, on the other hand. The directors and officers of Crestwood Midstream’s general partner have fiduciary duties to manage CrestwoodMidstream in a manner beneficial to us. At the same time, Crestwood Midstream’s general partner has fiduciary duties to manage Crestwood Midstream in amanner beneficial to Crestwood Midstream and its limited partners. The board of directors of Crestwood Midstream’s general partner will resolve any suchconflict and has broad latitude to consider the interests of all parties to the conflict. The resolution of these conflicts may not always be in our best interest.37Table of ContentsFor example, conflicts of interest with Crestwood Midstream may arise in the following situations:•the allocation of shared overhead expenses to Crestwood Midstream and us;•the interpretation and enforcement of contractual obligations between us and our affiliates, on the one hand, and Crestwood Midstream, on the otherhand;•the determination of the amount of cash to be distributed to Crestwood Midstream’s limited partners and the amount of cash to be reserved for thefuture conduct of Crestwood Midstream’s business; and•the determination whether to make borrowings under Crestwood Midstream’s revolving credit facility to pay distributions to Crestwood Midstream’slimited partners.The fiduciary duties of our general partner’s officers and directors may conflict with those of Crestwood Midstream’s general partner.Conflicts of interest may arise because of the relationships among Crestwood Midstream, its general partner and us. Our general partner’s directors andofficers have fiduciary duties to manage our business in a manner beneficial to us and our unitholders. Some of our general partner’s directors and officers arealso directors and officers of Crestwood Midstream’s general partner, and have fiduciary duties to manage the business of Crestwood Midstream in a mannerbeneficial to Crestwood Midstream and its unitholders. The resolution of these conflicts may not always be in our best interest or that of our unitholders.Affiliates of our general partner are not prohibited from competing with us.Our partnership agreement provides that our general partner will be restricted from engaging in any business activities other than acting as our general partnerand those activities incidental to its ownership of interests in us. Except as provided in our partnership agreement, affiliates of our general partner are notprohibited from engaging in other businesses or activities, including those that might be in direct competition with us.Potential conflicts of interest may arise among our general partner, its affiliates and us. Our general partner and its affiliates have limitedfiduciary duties to us, which may permit them to favor their own interests to the detriment of us.Conflicts of interest may arise among our general partner and its affiliates, on the one hand, and us, on the other hand. As a result of these conflicts, ourgeneral partner may favor its own interests and the interests of its affiliates over our interests. These conflicts include, among others, the following:•Our general partner is allowed to take into account the interests of parties other than us, including Crestwood Midstream and its affiliates and anygeneral partner and limited partnerships acquired in the future, in resolving conflicts of interest, which has the effect of limiting its fiduciary dutiesto us.•Our general partner has limited its liability and reduced its fiduciary duties under the terms of our partnership agreement, while also restricting theremedies available for actions that, without these limitations, might constitute breaches of fiduciary duty. As a result of purchasing our units,unitholders consent to various actions and conflicts of interest that might otherwise constitute a breach of fiduciary or other duties under applicablestate law.•Our general partner determines the amount and timing of our investment transactions, borrowings, issuances of additional partnership securities andreserves, each of which can affect the amount of cash that is available for distribution.•Our general partner determines which costs it and its affiliates have incurred are reimbursable by us.•Our partnership agreement does not restrict our general partner from causing us to pay it or its affiliates for any services rendered, or from enteringinto additional contractual arrangements with any of these entities on our behalf, so long as the terms of any such payments or additional contractualarrangements are fair and reasonable to us.•Our general partner controls the enforcement of obligations owed to us by it and its affiliates.•Our general partner decides whether to retain separate counsel, accountants or others to perform services for us.Our partnership agreement limits our general partner’s fiduciary duties to us and restricts the remedies available for actions taken by our generalpartner that might otherwise constitute breaches of fiduciary duty.Our partnership agreement contains provisions that reduce the standards to which our general partner would otherwise be held by state fiduciary duty law. Forexample, our partnership agreement:•provides that our general partner is entitled to make decisions in “good faith” if it reasonably believes that the decisions are in our best interests;38Table of Contents•generally provides that affiliated transactions and resolutions of conflicts of interest not approved by the Conflicts Committee of the board ofdirectors of our general partner and not involving a vote of unitholders must be on terms no less favorable to us than those generally being provided toor available from unrelated third parties or be “fair and reasonable” to us and that, in determining whether a transaction or resolution is “fair andreasonable,” our general partner may consider the totality of the relationships among the parties involved, including other transactions that may beparticularly advantageous or beneficial to us; and•provides that our general partner and its officers and directors will not be liable for monetary damages to us, our limited partners or assignees for anyacts or omissions unless there has been a final and non-appealable judgment entered by a court of competent jurisdiction determining that the generalpartner or those other persons acted in bad faith or engaged in fraud, willful misconduct or gross negligence.Our general partner has a limited call right that may require unitholders to sell their units at an undesirable time or price.If at any time our general partner and its affiliates own more than 80% of our outstanding units, our general partner will have the right, but not the obligation,which it may assign to any of its affiliates or to us, to acquire all, but not less than all, of the units held by unaffiliated persons at a price not less than theirthen-current market price. As a result, unitholders may be required to sell their units at an undesirable time or price and may not receive any return on theirinvestment. Unitholders may also incur a tax liability upon a sale of their units. As of December 31, 2013, the directors and executive officers of our generalpartner owned approximately 12% of our common units.Our cash distribution policy limits our ability to grow.Because we distribute all of our available cash, our growth may not be as rapid as businesses that reinvest their available cash to expand ongoing operations. Ifwe issue additional units or incur debt to fund acquisitions and growth capital expenditures, the payment of distributions on those additional units or intereston that debt could increase the risk that we will be unable to maintain or increase our per unit distribution level.Tax Risks to Common UnitholdersOur tax treatment depends on our status as a partnership for U.S. federal income tax purposes. If the Internal Revenue Service (“IRS”) were totreat us as a corporation for federal income tax purposes or we or Crestwood Midstream were to become subject to material additional amounts ofentity-level taxation for state tax purposes, then our cash available for distribution to unitholders would be substantially reduced.The anticipated after-tax economic benefit of an investment in our common units depends largely on our being treated as a partnership for U.S. federal incometax purposes. The value of our investment in Crestwood Midstream depends largely on Crestwood Midstream being treated as a partnership for federal incometax purposes. Despite the fact that we and Crestwood Midstream are each organized as a limited partnership under Delaware law, we and CrestwoodMidstream would each be treated as a corporation for U.S. federal income tax purposes unless we each satisfy a “qualifying income” requirement. Based uponour current operations, we and Crestwood Midstream each believe we satisfy the qualifying income requirement.Failing to meet the qualifying income requirement or a change in current law could cause us or Crestwood Midstream to be treated as a corporation for U.S.federal income tax purposes or otherwise subject us to taxation as an entity. If we or Crestwood Midstream were treated as a corporation for U.S. federal incometax purposes, we each would pay federal income tax on our taxable income at the corporate tax rate, which is currently a maximum of 35%, as well as anyapplicable state or local taxes. Distributions to our unitholders and Crestwood Midstream’s unitholders would generally be taxed again as corporatedistributions, and no income, gains, losses, deductions or credits would flow through to our unitholders. Because a tax would be imposed upon us as acorporation, our cash available for distribution to our unitholders would be substantially reduced. Therefore, treatment of us or Crestwood Midstream as acorporation would result in a material reduction in the anticipated cash flow and after-tax return to our respective common unitholders, likely causing asubstantial reduction in the value of our common units.Our partnership agreement, as well as that of Crestwood Midstream, provides that if a law is enacted or existing law is modified or interpreted in a manner thatsubjects us to taxation as a corporation or otherwise subjects us to entity-level taxation for federal, state or local income tax purposes, the minimum quarterlydistribution amount and the target distribution amounts may be adjusted to reflect the impact of that law on us. At the state level, several states have beenevaluating ways to subject partnerships to entity-level taxation through the imposition of state income, franchise, or other forms of taxation. Imposition of asimilar tax on us in the jurisdictions in which we operate or in other jurisdictions to which we may expand could substantially reduce our cash available fordistribution to our unitholders or Crestwood Midstream’s unitholders.39Table of ContentsThe tax treatment of publicly traded partnerships or an investment in Crestwood Midstream’s or our common units could be subject to potentiallegislative, judicial or administrative changes and differing interpretations, possibly on a retroactive basis.The present U.S. federal income tax treatment of publicly traded partnerships, including Crestwood Midstream and us, or an investment in CrestwoodMidstream’s or our common units may be modified by administrative, legislative or judicial changes or differing interpretations at any time. For example,from time to time, members of Congress propose and consider substantive changes to the existing federal income tax laws that affect publicly tradedpartnerships. Currently, one such legislative proposal would have eliminated the qualifying income exception upon which we and Crestwood Midstream relyon for our treatment as a partnership for U.S. federal income tax purposes. We are unable to predict whether any of these changes or other proposals will bereintroduced or will ultimately be enacted. Any such changes could negatively impact the value of an investment in Crestwood Midstream’s or our commonunits. Any modification to the U.S. federal income tax laws may be applied retroactively and could make it more difficult or impossible to meet the exceptionfor certain publicly traded partnerships to be treated as partnerships for U.S. federal income tax purposes.If the IRS contests the federal income tax positions we take, the market for our common units may be adversely impacted and the cost of any IRScontest will reduce our cash available for distribution to our unitholders.Neither we nor Crestwood Midstream has requested a ruling from the IRS with respect to our treatment as a partnership for federal income tax purposes. TheIRS may adopt positions that differ from the positions we take. It may be necessary to resort to administrative or court proceedings to sustain some or all of thepositions we take. A court may not agree with the positions we take. Any contest with the IRS may materially and adversely impact the market for ourcommon units and the price at which they trade. In addition, the costs of any contest with the IRS will be borne indirectly by you and our general partnerbecause the costs will reduce our cash available for distribution.You will be required to pay taxes on your share of our income even if you do not receive cash distributions from us.You will be required to pay any federal income taxes and, in some cases, state and local income taxes on your share of our taxable income, whether or not youreceive cash distributions from us. You may not receive cash distributions from us equal to your share of our taxable income or even equal to the actual taxliability which results from that income.Tax gain or loss on the disposition of our common units could be more or less than expected.If you sell your common units, you will recognize a gain or loss equal to the difference between your amount realized and your tax basis in those commonunits. Because distributions in excess of your allocable share of our total net taxable income result in a reduction in your tax basis in your common units, theamount, if any, of such prior excess distributions with respect to the units you sell will, in effect, become taxable income to you if you sell such units at aprice greater than your tax basis in those common units, even if the price you receive is less than your original cost. Furthermore, a substantial portion of theamount realized, whether or not representing gain, may be taxed as ordinary income due to potential recapture of depreciation deductions. In addition, becausethe amount realized includes a unitholder's share of our nonrecourse liabilities, if you sell your units, you may incur a tax liability in excess of the amount ofcash you receive from the sale.Tax-exempt entities, regulated investment companies and non-U.S. persons face unique tax issues from owning common units that may result inadverse tax consequences to them.Investment in common units by tax-exempt entities, including employee benefit plans and individual retirement accounts (known as “IRAs”), and non-U.S.persons raises issues unique to them. For example, virtually all of our income allocated to organizations exempt from federal income tax, including individualretirement accounts and other retirement plans, will be unrelated business taxable income and will be taxable to them. Distributions to non-U.S. persons will bereduced by withholding taxes imposed at the highest effective applicable tax rate, and non-U.S. persons will be required to file U. S. federal income tax returnsand pay tax on their share of our taxable income. If you are a tax-exempt entity or a non-U.S. person, you should consult your tax advisor before investing inour common units.We and Crestwood Midstream will treat each purchaser of our respective common units as having the same tax benefits without regard to thespecific common units purchased. The IRS may challenge this treatment, which could adversely affect the value of Crestwood Midstream’s andour common units.Because we cannot match transferors and transferees of common units and because of other reasons, we and Crestwood Midstream will adopt depreciationand amortization positions that may not conform to all aspects of existing Treasury Regulations. A successful IRS challenge to those positions could adverselyaffect the amount of tax benefits available to you. It40Table of Contentsalso could affect the timing of these tax benefits or the amount of gain from the sale of Crestwood Midstream’s common units and our common units andcould have a negative impact on the value of our respective common units or result in audit adjustments to your tax returns.We prorate our items of income, gain, loss and deduction between transferors and transferees of our units each month based upon the ownershipof units on the first day of each month, instead of on the basis of the date a particular unit is transferred. The IRS may challenge this treatment,which could change the allocation of items of income, gain, loss and deduction among our unitholders.We generally prorate our items of income, gain, loss and deduction between transferors and transferees of our units each month based upon the ownership ofour units on the first day of each month, instead of on the basis of the date a particular unit is transferred. The use of this proration method may not bepermitted under existing Treasury Regulations. The U.S. Treasury Department has issued proposed Treasury Regulations that provide a safe harbor pursuantto which a publicly-traded partnership may use a similar monthly simplifying convention to allocate tax items among transferor and transferee unitholders.Nonetheless, the proposed regulations do not specifically authorize the use of the proration method we have adopted. If the IRS were to successfully challengeour proration method or new Treasury Regulations were issued, we may be required to change the allocation of items of income, gain, loss, and deductionamong our unitholders.A unitholder whose common units are the subject of a securities loan (e.g., a loan to a “short seller” to cover a short sale of common units) maybe considered as having disposed of those common units. If so, he would no longer be treated for tax purposes as a partner with respect to thosecommon units during the period of the loan and may recognize gain or loss from the disposition.Because there are no specific rules governing the U.S. federal income tax consequences of loaning a partnership interest, a unitholder whose common units arethe subject of a securities loan may be considered as having disposed of the loaned units. In that case, he may no longer be treated for tax purposes as a partnerwith respect to those common units during the period of the loan and the unitholder may recognize gain or loss from such disposition. Moreover, during theperiod of the loan, any of our income, gain, loss or deduction with respect to those common units may not be reportable by the unitholder and any cashdistributions received by the unitholder as to those common units could be fully taxable as ordinary income. Unitholders desiring to assure their status aspartners and avoid the risk of gain recognition from a loan to a short seller should modify any applicable brokerage account agreements to prohibit theirbrokers from borrowing their common units.The sale or exchange of 50% or more of our capital and profits interests within a twelve-month period will result in the termination of ourpartnership for federal income tax purposes.We will be considered to have constructively terminated as a partnership for federal income tax purposes if there is a sale or exchange within a twelve-monthperiod of 50% or more of the total interests in our capital and profits. For purposes of determining whether the 50% threshold has been met, multiple sales ofthe same interest will be counted only once. Our termination would, among other things, result in the closing of our taxable year for all unitholders which couldresult in us filing two tax returns (and unitholders receiving two Schedule K-1s) for one calendar year. Our termination could also result in a deferral ofdepreciation deductions allowable in computing our taxable income. In the case of a unitholder reporting on a taxable year other than a calendar year, theclosing of our taxable year may also result in more than twelve months of our taxable income or loss being includable in its taxable income for the year oftermination. Our termination would not affect our classification as a partnership for federal income tax purposes, but instead, we would be treated as a newpartnership for federal income tax purposes. If treated as a new partnership, we must make new tax elections and could be subject to penalties if we are unableto determine that a termination occurred. Pursuant to an IRS relief procedure a publicly traded partnership that has technically terminated may request specialrelief which, if granted by the IRS, among other things, would permit the partnership to provide only a single Schedule K-1 to unitholders for the tax years inwhich the termination occurs.Our unitholders will likely be subject to state and local taxes and return filing requirements in states where they do not live as a result of investingin our common units.In addition to federal income taxes, our unitholders will likely be subject to other taxes, including state and local taxes, unincorporated business taxes, estate,inheritance or intangible taxes and foreign taxes that are imposed by the various jurisdictions in which we do business or own property and in which they donot reside. We own property and conduct business in various parts of the United States. Unitholders may be required to file state and local income tax returnsin many or all of the jurisdictions in which we do business or own property. Further, unitholders may be subject to penalties for failure to comply with thoserequirements. It is our unitholders’ responsibility to file all required U. S. federal, state, local and foreign tax returns.41Table of ContentsItem 1B. Unresolved Staff Comments.None.Item 2. Properties.A description of our properties is included in Item 1. Business, and is incorporated herein by reference. We also lease officespace for our corporate offices in Houston, Texas and our executive offices in Kansas City, Missouri and Fort Worth, Texas.We lease and rely upon our customers' property rights to conduct a substantial part of our operations, and we own or lease the property rights necessary toconduct our storage and transportation operations. We believe that we have satisfactory title to our assets. Title to property may be subject to encumbrances.For example, we have granted to the lenders of our revolving credit facility security interests in substantially all of our real property interests. We believe thatnone of these encumbrances will materially detract from the value of our properties or from our interest in these properties, nor will they materially interferewith their use in the operation of our businessItem 3. Legal Proceedings.See Part IV, Item 15, Exhibits and Financial Statement Schedules, Note 15 for information related to our legal proceedings.Item 4. Mine Safety DisclosuresNot applicable.42Table of ContentsPART IIItem 5. Market for Registrant’s Common Equity, Related Unitholder Matters and Issuer Purchases of Equity Securities.Prior to the Crestwood Merger, our common units traded on the NYSE under the symbol “NRGY.” Concurrent with the completion of the Crestwood Mergeron October 7, 2013, our common units representing limited partner interests began trading on the NYSE under the symbol “CEQP.” The following table setsforth the range of high and low sales prices of the common units, as reported by the NYSE, as well as the amount of cash distributions declared per commonunit for the periods indicated.Quarters Ended:Low High CashDistributionPer Unit2013 December 31, 2013$11.83 $15.30 $0.1375September 30, 201312.59 16.89 0.135June 30, 201313.55 25.34 0.130March 31, 201318.42 20.91 0.2902012 December 31, 201217.05 20.73 0.290September 30, 201217.25 21.99 0.290June 30, 201215.22 20.24 0.375March 31, 201215.06 24.99 0.375The last reported sale price of our common units on the NYSE on February 14, 2014, was $12.72. As of that date, we had 186,429,575 common unitsissued and outstanding, which were held by 105 unitholders of record.Cash Distribution PolicyWe make quarterly distributions to our partners within approximately 45 days after the end of each fiscal quarter in an aggregate amount equal to our availablecash for such quarter. Available cash generally means, with respect to each fiscal quarter, all cash on hand at the end of the quarter less the amount of cashthat the general partner determines in its reasonable discretion is necessary or appropriate to:•provide for the proper conduct of our business;•comply with applicable law, any of our debt instruments, or other agreements; or•provide funds for distributions to unitholders for any one or more of the next four quarters;plus all cash on hand on the date of determination of available cash for the quarter resulting from working capital borrowings made subsequent to the end ofthe quarter. Working capital borrowings are generally borrowings that are made under our working capital facility and in all cases are used solely for workingcapital purposes or to pay distributions to partners.On February 14, 2014, we paid a distribution of $0.1375 per limited partner unit ($0.55 per limited partner unit on an annualized basis) to all unitholders ofrecord on February 7, 2014.Issuer Purchases of Equity SecuritiesFor the year ended December 31, 2013, 408,836 common units were relinquished to us to cover payroll taxes upon the vesting of restricted units. 43Table of ContentsEquity Compensation Plan InformationThe following table sets forth in tabular format, a summary of equity compensation plan information as of December 31, 2013: Plan categoryNumber ofsecurities to beissued uponexercise ofoutstandingoptions, warrantsand rights Weighted-averageexerciseprice ofoutstandingoptions,warrantsand rights Number of securitiesremaining available forfuture issuance underequity compensationplans (excludingsecurities reflected incolumn (a)) (a) (b) (c)Equity compensation plans approved by security holders— $— —Equity compensation plans not approved by security holders49,050 $12.83 9,379,635Total49,050 $12.83 9,379,635Item 6. Selected Financial Data.These consolidated financial statements were originally the financial statements of Legacy Crestwood GP prior to being acquired by us on June 19, 2013. Ouracquisition of Legacy Crestwood GP was accounted for as a reverse acquisition under the purchase method of accounting in accordance with the accountingstandards for business combinations. The accounting for a reverse acquisition results in the legal acquiree (Legacy Crestwood GP) being the acquirer foraccounting purposes. Although Legacy Crestwood GP was the acquirer for accounting purposes, we were the acquirer for legal purposes; consequently, wechanged our name from Crestwood Gas Services GP, LLC to Crestwood Equity Partners LP.The income statement and cash flow data for each of the three years ended December 31, 2013 and balance sheet data as of December 31, 2013 and 2012 werederived from our audited financial statements. We derived the income statement and cash flow data for each of the two years ended December 31, 2010 and thebalance sheet data as of December 31, 2011, 2010 and 2009 from our accounting records. The selected financial data is not necessarily indicative of results tobe expected in future periods and should be read together with Item 7, Management’s Discussion and Analysis of Financial Condition and Results ofOperations and Part IV, Item 15, Exhibits and Financial Statement Schedules included elsewhere in this report.The following table summarizes our results for the years ended December 31, 2013, 2012 and 2011 and two periods in 2010: January 1, 2010 throughSeptember 30, 2010 (the “Predecessor Period”) and October 1, 2010 through December 31, 2010 (the “Successor Period”), which relate to the periods beforeand after Crestwood Holdings acquisition of Quicksilver’s ownership interest in Legacy Crestwood (the “Crestwood Transaction”).“EBITDA” shown in the table below is defined as income before income taxes, plus net interest and debt expense, and depreciation, amortization and accretionexpense. In addition, Adjusted EBITDA considers the adjusted earnings impact of our unconsolidated affiliates by adjusting our equity earnings or lossesfrom our unconsolidated affiliates for our proportionate share of their depreciation and interest, the impact of certain significant items, such as non-cash equitycompensation expenses, gains and impairments of long-lived assets and goodwill, third party costs incurred related to potential and completed acquisitions,loss on contingent consideration, change in fair value of derivative contracts, and other transactions identified in a specific reporting period. EBITDA andAdjusted EBITDA are not measures calculated in accordance with GAAP, as they do not include deductions for items such as depreciation, amortization andaccretion, interest and income taxes, which are necessary to maintain our business. EBITDA and Adjusted EBITDA should not be considered an alternative tonet income, operating cash flow or any other measure of financial performance presented in accordance with GAAP. EBITDA and Adjusted EBITDAcalculations may vary among entities, so our computation may not be comparable to measures used by other companies.44Table of Contents Crestwood Equity Partners LPYear Ended December 31,(in millions, except per unit data) Successor Predecessor Year Ended December 31, 2013 (a) 2012 2011 Period fromOctober 1, 2010to December 31,2010 Period fromJanuary 1, 2010to September 30,2010 Year EndedDecember 31,2009Statement of Income Data: Operating revenues$1,426.7 $239.5 $205.8 $31.3 $82.3 $95.9Operating income28.2 61.4 71.0 5.8 37.5 43.4Income (loss) before income taxes(49.6) 25.6 43.4 1.1 28.7 34.9Net income (loss) from continuing operations(50.6) 24.4 42.1 1.8 28.6 34.5Loss from discontinued operations— — — — — (2.0)Net income (loss)(50.6) 24.4 42.1 1.8 28.6 32.5Net income attributable to Crestwood Equity PartnersLP6.7 14.9 7.7 0.7 1.8 1.2 Performance Measures: Diluted limited partner income per unit: (b) From net income from continuing operations$0.06 $0.38 $0.19 $0.02 $0.04 $0.03From net income$0.06 $0.38 $0.19 $0.02 $0.04 $0.03 Distributions declared per limited partner unit(c)$0.6925 $1.33 $2.82 $0.705 $2.105 $2.68 Other Financial Data: EBITDA (unaudited)$196.2 $134.6 $124.9 $16.0 $54.2 $64.2Adjusted EBITDA (unaudited)297.7 134.4 110.9 19.5 58.9 65.9Net cash provided by operating activities188.3 102.1 86.3 3.1 44.9 68.9Net cash used in investing activities(1,042.9) (616.6) (456.5) (16.6) (132.7) (54.8)Net cash provided by (used in) financing activities859.7 513.8 371.0 13.4 87.2 (13.7) Balance Sheet Data: Property, plant and equipment, net$3,905.3 $1,102.4 $916.8 $710.4 $— $482.5Total assets8,523.2 2,301.6 1,739.2 1,303.1 — 487.6Total debt, including current portion2,266.0 685.2 512.5 283.5 — 125.4Other long-term liabilities(d)140.4 17.2 15.5 9.9 — 62.2Partners' capital5,508.6 1,550.7 1,120.0 926.0 — 284.845Table of Contents Successor Predecessor Year Ended December 31, 2013 2012 2011 Period fromOctober 1, 2010to December 31,2010 Period fromJanuary 1, 2010to September 30,2010 Year EndedDecember 31,2009Reconciliation of Net Income to EBITDA andAdjusted EBITDA: Net income (loss)$(50.6) $24.4 $42.1 $1.8 $28.6 $32.5Depreciation, amortization and accretion167.9 73.2 53.9 10.2 16.7 20.8Interest and debt expense, net77.9 35.8 27.6 4.7 8.8 8.5Provision (benefit) for income taxes1.0 1.2 1.3 (0.7) 0.1 0.4Loss from discontinued operations— — — — — 2.0EBITDA$196.2$134.6$124.9$16.0$54.2$64.2Non-cash equity compensation expense17.4 1.9 0.9 3.5 2.0 1.7(Gain) loss on contingent consideration31.4 (6.8) (17.2) — — —Gain on long-lived assets(5.3) — (1.1) — — —Goodwill impairment4.1 — — — — —Loss from unconsolidated affiliates, net0.1 — — — — —Adjusted EBITDA from unconsolidatedaffiliates2.5 — — — — —Change in fair value of derivative contracts10.7 — — — — —Significant transaction related costs and otheritems40.6 4.7 3.4—— 2.7——Adjusted EBITDA$297.7 $134.4 $110.9 $19.5 $58.9$65.9 46Table of Contents Successor Predecessor Year Ended December 31, 2013 2012 2011 Period fromOctober 1, 2010to December 31,2010 Period fromJanuary 1, 2010to September 30,2010 Year EndedDecember 31,2009Reconciliation of Net Cash Provided byOperating Activities to EBITDA and AdjustedEBITDA: Net cash provided by operating activities$188.3 $102.1 $86.3 $3.1 $44.9 $68.9Net changes in operating assets and liabilities(19.6) (4.1) (4.2) 13.1 5.8 (5.3)Provision for doubtful accounts1.1 — — — — —Amortization of debt-related deferred costs,discounts and premiums(9.2) (5.5) (3.5) (0.7) (0.6) (0.5)Market adjustment on interest rate swap1.7 — — — —Gain (loss) on contingent consideration(31.4) 6.8 17.2 — —Gain on long-lived assets5.3 — 1.1 — —Goodwill impairment(4.1) — — — — —Loss from unconsolidated affiliates, net(0.1) — — — — —Non-cash equity compensation expense(17.4) (1.9) (0.9) (3.5) (2.0) (1.7)Deferred income taxes2.8 — — 0.9 (0.1) (0.4)Interest and debt expense, net77.9 35.8 27.6 4.7 8.8 8.5 Provision (benefit) for income taxes1.0 1.2 1.3 (0.7) 0.10.4 Other non-cash income(0.1) 0.2 — (0.9) (2.7) (5.7)EBITDA$196.2$134.6$124.9$16.0 $54.2$64.2Non-cash equity compensation expense17.4 1.9 0.9 3.5 2.01.7(Gain) loss on contingent consideration31.4 (6.8) (17.2) — ——Gain on long-lived assets(5.3) — (1.1) — ——Goodwill impairment4.1 — — — ——Loss from unconsolidated affiliates, net0.1 — — — ——Adjusted EBITDA from unconsolidated affiliates2.5 — — — ——Change in fair value of derivative contracts10.7 — — — ——Significant transaction related costs and otheritems40.6 4.7 3.4 — 2.7—Adjusted EBITDA$297.7 $134.4 $110.9 $19.5 $58.9$65.9 (a)Financial data presented for periods prior to June 19, 2013, solely reflect the operations of Legacy Crestwood GP. Financial data for periods subsequent to June 19, 2013,represent the consolidated operations of Crestwood Equity. In addition, during 2013, we recorded a $31.4 million loss on contingent consideration which reflects the fair value ofan earn-out premium associated with the original acquisition of our Marcellus G&P assets from Antero in 2012.(b)The weighted average number of units outstanding is calculated based on the presumption that the common and subordinated units issued to acquire Legacy Crestwood GP (theaccounting predecessor) were outstanding for the entire period prior to the June 19, 2013 acquisition. On the date of the acquisition, all of our limited partner units are consideredoutstanding.(c)Reported amounts include the fourth quarter distribution, which was paid in the first quarter of the subsequent year.(d)Other long-term liabilities primarily include our capital leases, asset retirement obligations and a fair value adjustment for unfavorable contracts as a result of certain purchaseaccounting adjustments.47Table of ContentsItem 7. Management’s Discussion and Analysis of Financial Condition and Results of OperationsOur Management’s Discussion and Analysis of Financial Condition and Results of Operations should be read in conjunction with our consolidated financialstatements and the accompanying footnotes.This report, including information included or incorporated by reference herein, contains forward-looking statements concerning the financial condition,results of operations, plans, objectives, future performance and business of our company and its subsidiaries. These forward-looking statements include:•statements that are not historical in nature, including, but not limited to: (i) our expectation that we will grow our business through both organicgrowth projects and acquisitions; (ii) our belief that anticipated cash from operations, cash distributions from entities that we control, and borrowingcapacity under our credit facility will be sufficient to meet our anticipated liquidity needs for the foreseeable future; (iii) our belief that we do not havematerial potential liability in connection with legal proceedings that would have a significant financial impact on our consolidated financial condition,results of operations or cash flows; (iv) our belief that our assets, and Crestwood Midstream’s assets, will continue to benefit from the developmentof unconventional shale plays as significant supply basins; and (vi) our belief that the Crestwood Merger will produce certain commercial synergiesand other benefits; and•statements preceded by, followed by or that contain forward-looking terminology including the words “believe,” “expect,” “may,” “will,” “should,”“could,” “anticipate,” “estimate,” “intend” or the negation thereof, or similar expressions.Forward-looking statements are not guarantees of future performance or results. They involve risks, uncertainties and assumptions. Actual results may differmaterially from those contemplated by the forward-looking statements due to, among others, the following factors:•our ability to successfully implement our business plan for our assets and operations;•governmental legislation and regulations;•industry factors that influence the supply of and demand for crude oil, natural gas and NGLs;•industry factors that influence the demand for services in the markets (particularly unconventional shale plays) in which we provide services;•weather conditions;•the availability of crude oil, natural gas and NGLs, and the price of those commodities, to consumers relative to the price of alternative andcompeting fuels;•economic conditions;•costs or difficulties related to the integration of our existing businesses and acquisitions;•environmental claims;•operating hazards and other risks incidental to the provision of midstream services, including gathering, compressing, treating, processing,fractionating, transporting and storing crude oil, NGLs and natural gas;•interest rates; and•the price and availability of debt and equity financing.We have described under Item 1A, Risk Factors, additional factors that could cause actual results to be materially different from those described in theforward-looking statements. Other factors that we have not identified in this report could also have this effect.OverviewWe are a master limited partnership that manages, owns and operates crude oil, natural gas and NGL midstream assets and operations. Headquartered inHouston, Texas, we are a fully-integrated midstream solution provider that specializes in connecting shale-based energy supplies to key demand markets. Wemanage and conduct a substantial portion of our operations through Crestwood Midstream, a growth-oriented MLP that owns and operates gathering,processing, storage, and transportation assets in the most prolific shale plays across the United States. We own the general partnership interest, IDRs andapproximately 4% of the limited partner interests of Crestwood Midstream as of December 31, 2013.48Table of ContentsStrategic Business CombinationIn 2013, we completed a series of related transactions that transferred control of us to Crestwood Holdings and combined the management and operations of theInergy Midstream and Legacy Crestwood. The strategic rationale behind the business combination included, among other things, commercial synergies thatwould enable us to significantly expand the mix of midstream services we are able to offer our customers; diversified cash flows and asset base; increasedscale to accelerate opportunities to reduce leverage and improve creditworthiness; and, increased scale to better take advantage of growth opportunities, in termsof both organic growth projects and third-party acquisitions. We have already realized (and expect to continue to realize) many of these anticipated mergerbenefits, and we continue to believe this strategic combination enhances our consolidated position as a diversified, high-growth midstream “pure play” focusedon crude and liquids-rich opportunities.Our CompanyWe provide broad-ranging services to customers across the crude oil, NGL and natural gas sector of the energy value chain. Our midstream infrastructure isgeographically located in or near significant supply basins, especially developed and emerging liquids-rich and crude oil shale plays, across the United States.We own or control:•natural gas facilities with approximately 2.5 Bcf/d of gathering capacity, 471 MMcf/d of processing capacity, 79.4 Bcf of working gas storagecapacity, and 1.0 Bcf/d of firm transmission capacity;•NGL facilities with approximately 24,000 Bbls/d of fractionation capacity and 2.8 million barrels of storage capacity;•crude oil facilities with approximately 100,000 Bbls/d of gathering capacity, 960,000 barrels of storage capacity and 120,000 Bbls/d of rail loadingcapacity; and•7 terminal facilities and a transportation fleet of approximately 557 truck/trailer units and 1,071 rail units that can transport more than 330,000Bbls/d of NGLs.Our primary business objective is to increase the cash distributions that we pay to our unitholders. We expect to position Crestwood Midstream to increase itscash distributions by providing strong general partner support and using Crestwood Midstream as the primary vehicle through which we grow our midstreambusiness. We intend to grow our business, safely through the development, acquisition and operation of additional midstream assets situated near developedand emerging shale resources and premium demand centers. We plan to increase Crestwood Midstream’s cash available for distribution through organicgrowth and increased operational efficiencies, including commercial and operational synergies resulting from the Crestwood Merger. We also anticipate growingour business through Crestwood Midstream’s strategic and bolt-on acquisitions, including asset contributions from us, with an emphasis on acquisitions that(i) facilitate our development of an integrated midstream platform that enables us to continue to expand the services we offer to customers in key geographicmarkets, and/or (ii) provide the scale we need to realize greater economies of scale (from cash flow, cost, credit and other perspectives) that translate intoincreased cash distributions to our unitholders. We also intend to grow our NGL and crude services business by leveraging our industry knowledge, expertiseand relationships with Legacy Crestwood’s relationships and operational experience to offer unparalleled takeaway solutions from the wellhead to the end user.Our three business segments include (i) gathering and processing, which includes our natural gas G&P operations; (ii) NGL and crude services, whichincludes our proprietary NGL and crude oil business, crude oil gathering systems and rail terminals, NGL processing, fractionation and storage facilities,and salt production business; and (iii) storage and transportation, which includes our natural gas storage and transportation operations. Except for ourproprietary supply and logistics business, West Coast NGL business and Tres Palacios, all of our operations are conducted by or through CrestwoodMidstream.Gathering and ProcessingOur G&P operations provide gathering, compression, treating, and processing services to producers in multiple unconventional resource plays across theUnited States. We have established footprints in “core of the core” areas of several shale plays with delineated condensate and rich gas windows offeringattractive producer economics, while maintaining operations in several prolific dry gas plays. We believe that our strategy of focusing on liquids-rich playswithout abandoning prolific lean gas plays positions us well to (i) generate greater returns in the near term while natural gas prices remain depressed, (ii)capture greater upside economics when natural gas prices normalize, and (iii) in general, manage through commodity price cycles and production changesassociated therewith.49Table of ContentsOur G&P operations primarily include:•Marcellus Shale. We own and operate (i) a low-pressure natural gas gathering system with a gathering capacity of approximately 600 MMcf/d ofrich gas produced by our customers in Harrison and Doddridge Counties, West Virginia; (ii) six compression and dehydration stations located onour gathering systems in the East AOD; and (iii) one compressor station located in the Western Area;•PRB Niobrara Shale. We own a 50% ownership interest in Jackalope, which is developing a system to gather and process rich natural gas producedin Converse County, Wyoming from a 311,000 gross acreage dedication from Chesapeake and RKI. We funded a significant portion of our Jackalopepurchase in July 2013 with the sale to GE of non-voting preferred equity securities in our Crestwood Niobrara subsidiary. We consolidate CrestwoodNiobrara’s results in our financial statements, and we account for Crestwood Niobrara’s 50% interest in Jackalope as an equity investment;•Barnett Shale. We own and operate (i) a low-pressure natural gas gathering system with a gathering capacity of approximately 425 MMcf/d of richgas produced by our customers in Hood, Somervell and Johnson Counties, Texas, which delivers the rich gas to our two processing plants whereNGLs are extracted from the natural gas stream; and (ii) low-pressure gathering systems with a gathering capacity of 530 MMcf/d of dry natural gasproduced by our customers in Tarrant and Denton Counties, Texas;•Fayetteville Shale. We own and operate five low-pressure gas gathering systems with a gathering capacity of approximately 510 MMcf/d of drynatural gas produced by our customers in Conway, Faulkner, Van Buren, and White Counties, Arkansas; and•Other. We own and operate (i) a low-pressure natural gas gathering system with a gathering capacity of approximately 36 MMcf/d of rich gasproduced by our customers in Roberts County, Texas, and a processing plant that extracts NGLs from the natural gas stream (Granite Washsystem); (ii) three low-pressure natural gas gathering systems with a gathering capacity of approximately 50 MMcf/d of rich gas produced by ourcustomers in Eddy County, New Mexico (Avalon/Bone Springs system); and (iii) high-pressure natural gas gathering pipelines with a gatheringcapacity of approximately 100 MMcf/d that provide gathering and treating services to our customers located in Sabine Parish, Louisiana(Haynesville/Bossier system).The cash flows from our G&P operations are predominantly fee-based with creditworthy counterparties under contracts with terms that average 5-20 years.The results of our G&P operations are significantly influenced by the volumes of natural gas gathered and processed through our systems. We gather,process, treat, compress, transport and sell natural gas pursuant to fixed-fee and, to a lesser extent, percent-of-proceeds contracts. We do not take title tonatural gas or NGLs under our fixed-fee contracts, whereas under our percent-of-proceeds contracts, we take title to the residue gas, NGLs and condensate andremit a portion of the sale proceeds to the producer based on prevailing commodity prices. Our election to enter primarily into fixed-fee contracts minimizes ourG&P segment’s commodity price exposure and provides us more stable operating performance and cash flows. For the year ended December 31, 2013, the netrevenues from our percent-of-proceeds contracts accounted for approximately 2% of our gross profit (defined as revenues less costs of product/services sold) inour G&P operations.NGL and Crude ServicesOur NGL and crude services segment consists of our proprietary NGL and crude supply and logistics business, crude oil gathering systems and railterminals, NGL processing, fractionation and storage facilities, and US Salt. We have facilities located in and around some of the most prolific crude oilshales and premium demand markets in North America. We utilize these facilities to provide gathering, storage and terminal services to our anchor customers,and we utilize our crude oil and NGL assets on a portfolio basis to provide integrated supply and logistics solutions to producers, refiners and othercustomers.Our NGL and crude services operations primarily include:•Supply and logistics business. Our proprietary NGL and crude oil supply and logistics business utilizes assets under our ownership or control toeffectively provide supply “flow assurance” to producers, refiners and other customers. We are able to offer services that ensure uninterruptible NGLand crude oil supply flows at attractive economic values by optimizing our fleet of rail and rolling stock (including approximately 290 tractors, 458transports and 7 truck terminals), West Coast NGL operations, NGL storage facilities, and leased storage capacity at major crude and NGL hubs;50Table of Contents•Bakken Shale - Arrow. We own and operate substantial crude oil, natural gas and produced water gathering systems (the Arrow system) located onthe Fort Berthold Indian Reservation in the core of the Bakken Shale in McKenzie and Dunn Counties, North Dakota. The Arrow system consists ofmore than 485 miles of gathering pipeline, including approximately 153 miles of crude oil gathering lines, 171 miles of natural gas gathering linesand 164 miles of produced water gathering lines. We purchased the Arrow system in November 2013;•Bakken Shale - COLT Hub. We own and operate the COLT Hub, which is one the largest crude oil rail terminals in the Bakken Shale based onactual throughput and which complements our recent Arrow acquisition. Located approximately 60 miles away from Arrow’s central delivery point,the COLT Hub interconnects with the Arrow system through the Hiland and Tesoro pipeline systems. The hub, which can be sourced by numerouspipeline systems or truck, is capable of loading up to 120,000 Bbls/d and has 960,000 barrels of crude oil storage capacity;•PRB Niobrara Shale. We own a 50.01% ownership interest in PRBIC, which owns an early stage crude oil rail terminal in Douglas County,Wyoming. We account for our interest in PRBIC as an equity investment. The terminal, which when completed will provide unit train takeaway-solutions for crude producers in the PRB Niobrara, is supported by a long-term contract with a major oil producer under which the producer hascommitted to deliver a minimum volume of crude oil to the rail facility for throughput;•West Coast NGL business. Our West Coast NGL business provides processing, fractionation, storage, transportation and marketing services toproducers, refiners and other customers. Located near Bakersfield, California, our West Coast facilities include 24 million gallons of abovegroundNGL storage capacity, 25 MMcf/d of natural gas processing capacity, 12,000 Bbls/d of NGL fractionation capacity, 8,000 Bbls/d of butaneisomerization capacity, and NGL rail and truck take-away options;•NGL storage facilities. We own and operate the Seymour storage facility, which has 21 million gallons of underground NGL storage capacity and1.2 million gallons of aboveground “bullet” storage capacity, and the Bath storage facility, which has 1.7 million barrels of underground NGLstorage capacity; and•US Salt. Our salt production business, which has a plant near Watkins Glen, New York, is capable of producing more than 400,000 tons ofevaporated salt products annually. US Salt’s solution mining process creates underground caverns that can be developed into natural gas and NGLstorage capacity.The PRBIC joint venture is also an example of how the Crestwood Merger is delivering commercial synergies, as this opportunity resulted from a combinationof the crude rail terminal and NGL logistics experience of Inergy Midstream and Legacy Crestwood’s relationships with RKI and Jackalope.The cash flows from our supply and logistics business (including our NGL processing, fractionation and storage facilities) represent sales to creditworthycustomers typically under contracts with durations of one year or less, and tend to be seasonal in nature due to customer profiles and their tendencies topurchase NGLs during peak winter periods. The cash flows from the Arrow operations are primarily fee-based with creditworthy counterparties under 10-to-20 year contracts, and can be impacted in the short term by changing commodity prices, seasonality and weather fluctuations. The cash flows from ourBakken Shale COLT Hub are predominantly fee-based with creditworthy counterparties under three-to-five year contracts, and are generally economicallystable and not significantly affected in the short term by changing commodity prices, seasonality or weather fluctuations. The cash flows from our saltoperations represent sales to creditworthy customers typically under contracts that are less than one year in duration, and are relatively stable and not subjectto seasonal or cyclical variation due to the use of, and demand for, salt products in everyday life.Storage and TransportationOur storage and transportation segment consists of our natural gas storage and transportation assets. We have four natural gas storage facilities (Stagecoach,Thomas Corners, Steuben and Seneca Lake) and three transportation pipelines (North/South Facilities, MARC I and the East Pipeline) located in theNortheast in or near the Marcellus Shale, and one storage facility (Tres Palacios) in Texas near the Eagle Ford Shale. Our storage facilities provide 79.4 Bcf offirm storage capacity to producers, utilities, marketers and other customers. We believe the location of our storage and transportation assets in the Northeastrelative to New York City and other premium demand markets along the East Coast helps to insulate our operations from production and commodity pricechanges that can more easily impact storage and transportation operators in other geographic regions, including Texas. We also believe that Tres Palacios’location relative to major supply areas and Gulf Coast petrochemical and LNG export facilities will provide meaningful revenue opportunities over the longrun, although as described below, we are taking action to weather considerable headwinds in the near term for our Texas storage operation.51Table of ContentsThe cash flows from our storage operations are predominantly fee-based with creditworthy counterparties under one-to-ten year contracts in the Northeast andone-to-three year contracts in Texas, and the cash flows from our transportation operations are predominantly fee-based with creditworthy counterparties underfive-to-ten year contracts. Our cash flows from interruptible and other hub services tends to increase during the peak winter season. Outlook and TrendsOur long-term profitability will be influenced primarily by our ability to (and to cause Crestwood Midstream to) execute our growth strategy, including bothgrowth projects and strategic acquisitions, and to increase cash available for distribution from the assets we own or control. An integral part of our growthstrategy entails capitalizing on commercial synergies from the Crestwood Merger. We continue to expand the services from which we generate revenues from ourgathering and processing customer base, and we anticipate generating increased cash flows as our producer customers rely on us for more integrated NGL andcrude oil takeaway solutions and flow assurances. We also anticipate pursuing (through Crestwood Midstream) acquisitions that would not have been possiblewithout the combined expertise and relationships resulting from the business combination. The continued integration of our gathering, processing, marketing,storage and transportation experience will be instrumental to our ability to derive such commercial synergies.Organic growth projects, including both expansions and greenfield development projects, can provide cost-effective options for us to grow our infrastructurebase. The ongoing expansion of our Bakken assets, including the COLT Hub and the Arrow system, and continued build out of our Marcellus and PRBNiobrara systems are examples of our ability to internally grow our operations at very low multiples. In general, purchasers of energy infrastructure have paidrelatively high prices (measured in terms of a multiple of EBITDA or another financial metric) to acquire midstream assets and operations in recent arms-length transactions. Although the prices paid for certain types of midstream assets are likely to remain robust for the foreseeable future, acquisitions willcontinue to permit us to gain access to new markets (with respect to geographic footprint and product offerings) and develop the scale required to continue togrow our businesses quickly and successfully. Our Arrow acquisition and our Jackalope and PRBIC investments are examples of where we believe we cancost-effectively accelerate growth through third-party acquisitions. We therefore expect to grow our business in the near term through both organic growthprojects and acquisitions.Our long-term profitability will also depend on our ability to contract and re-contract with customers and to manage increasingly difficult regulatory processesat the federal, state and local levels. The time required to secure the authorizations necessary for development projects and expansions, for both unregulatedand regulated projects, and the amounts we pay to secure authorizations and land rights are increasing in most markets in which we participate. Our WatkinsGlen NGL storage project is a prime example of the increased political and regulatory challenges we face in certain regions, despite the obvious market need forNGL storage solutions in the Northeast. However, we remain confident that the incremental time and money required to pursue and complete market-drivensolutions will deliver meaningful value to our unitholders, as the combination of the ongoing regulatory climate and the location of our assets relative to bothhigh-demand markets and prolific shale basins effectively provides a significant barrier to entry that other market participants may find difficult to overcome.We remain confident that production levels in the Marcellus, Bakken and PRB Niobrara Shale plays will remain strong, particularly as new gas processingcapacity and pipeline takeaway options come online in the next few years. We expect the producer economics in these oily (Bakken) and rich gas (Marcellus)windows to remain strong based on published supply and demand forecasts. In general, we believe that producers will continue to shift their resources to crudeoil and liquids-rich regions until natural gas demand increases and prices normalize. Accordingly, certain producers may continue to divert resources awayfrom dry gas plays (e.g., Fayetteville and Haynesville), which could negatively impact the volumes flowing through our gathering systems in these plays.Based on current market conditions and forecasts, we anticipate robust demand for the supply, marketing and logistics services that our propriety NGL andcrude business offers to customers. Our ability to control hydrocarbons across the distribution spectrum - from the wellhead to the end user - using ourtransportation fleet and contracted pipeline and storage capacity not only enables us to offer “flow assurance” on a geographic basis, but our ability to storestorage crude oil and NGLs in our facilities enables us to provide flow assurance over periods of time. As the energy sector continues to undergo significantchange on both the supply and the demand side, and we increase our ability to control supplies at the wellhead as a result of our G&P operations andrelationships, we anticipate that our ability to offer multiple delivery options nationwide will remain in high demand.We continue to forecast strong demand for natural gas and NGL storage in the Northeast, due mainly by a shortage in supply deliverability options andstorage infrastructure near key demand markets and a higher than average annual demand growth. We expect strong demand for natural gas pipelines thatmove production volumes directly to the market, and softer demand for pipeline capacity that can be displaced by new pipelines and expansion projectsbrought on line (particularly, new capacity used52Table of Contentsto move local production directly to local demand centers). We also believe that the location of our facilities in the Northeast positions us well to capitalize onopportunities associated with both (i) the current downward trend of increasingly lower import volumes of NGLs and liquefied natural gas along the EastCoast and (ii) anticipated increases in exported volumes of liquefied natural gas as new liquefaction facilities along the East Coast come online.We anticipate that demand for firm storage service in Texas will remain depressed in the near term due to low commodity prices, an abundance of Gulf Coaststorage capacity and low seasonal spreads. We continue to explore ways to optimize Tres Palacios and reduce associated costs through this trough of thecommodity cycle, including abandoning working gas storage capacity and reducing our annual lease payments that we make for use of Tres Palacios’underground storage caverns. At the same time, we believe that Tres Palacios’s location and design capabilities positions us well to capitalize on longer-termgrowth opportunities associated with forecast demand growth in Mexico (natural gas exports via pipeline) and increased liquefied natural gas exports (naturalgas exports via Gulf Coast liquefaction facilities).How We Evaluate Our Operations We evaluate our overall business performance based primarily on EBITDA and Adjusted EBITDA. We evaluate our ability to make distributions to ourunitholders based on cash available for distribution and distributions received from Crestwood Midstream.We do not utilize depreciation, depletion and amortization expense in our key measures because we focus our performance management on cash flow generationand our assets have long useful lives.EBITDA and Adjusted EBITDA - We believe that EBITDA and Adjusted EBITDA are widely accepted financial indicators of a company's operationalperformance and its ability to incur and service debt, fund capital expenditures and make distributions. EBITDA is defined as income before income taxes,plus net interest and debt expense, and depreciation, amortization and accretion expense. In addition, Adjusted EBITDA considers the adjusted earningsimpact of our unconsolidated affiliates by adjusting our equity earnings or losses from our unconsolidated affiliates for our proportionate share of theirdepreciation and interest, the impact of certain significant items, such as such as non-cash equity compensation expenses, gains and impairments of long-lived assets and goodwill, third party costs incurred related to potential and completed acquisitions, loss on contingent consideration, change in fair value ofderivative contracts, and other transactions identified in a specific reporting period. EBITDA and Adjusted EBITDA are not measures calculated inaccordance with GAAP, as they do not include deductions for items such as depreciation, amortization and accretion, interest and income taxes, which arenecessary to maintain our business. EBITDA and Adjusted EBITDA should not be considered an alternative to net income, operating cash flow or any othermeasure of financial performance presented in accordance with GAAP. EBITDA and Adjusted EBITDA calculations may vary among entities, so ourcomputation may not be comparable to measures used by other companies.See our reconciliation of net income to EBITDA and Adjusted EBITDA in Results of Operations below.53Table of ContentsResults of OperationsThe following table summarizes our results of operations for each of the three years ended December 31 (in millions). Financial data presented for periods priorto June 19, 2013, solely reflect the operations of Legacy Crestwood GP. In addition, during 2013, we recorded a $31.4 million loss on contingent considerationwhich reflects the fair value of an earn-out premium associated with the original acquisition of our Marcellus G&P assets from Antero in 2012. Year Ended December 31, 2013 2012 2011Revenues$1,426.7 $239.5 $205.8Costs of product/services sold1,002.3 39.0 38.8Operating and administrative expense198.1 72.7 60.4Depreciation, amortization and accretion expense167.9 73.2 53.9Goodwill impairment(4.1) — —Gain on long-lived assets5.3 — 1.1Gain (loss) on contingent consideration(31.4) 6.8 17.2Operating income28.261.471.0Loss from unconsolidated affiliates, net(0.1) — —Interest and debt expense, net(77.9) (35.8) (27.6)Other income0.2 — —Provision for income taxes(1.0) (1.2) (1.3)Net income (loss)(50.6)24.442.1Add: Interest and debt expense, net77.9 35.8 27.6Provision for income taxes1.0 1.2 1.3Depreciation, amortization and accretion167.9 73.2 53.9EBITDA$196.2 $134.6 $124.9Non-cash equity compensation expense17.4 1.9 0.9(Gain) loss on contingent consideration31.4 (6.8)(17.2)Gain on long-lived assets(5.3) — (1.1)Goodwill impairment4.1 — —Loss from unconsolidated affiliates, net0.1 — —Adjusted EBITDA from unconsolidated affiliates2.5 — —Change in fair value of derivative contracts10.7 — —Significant transaction related costs and other items40.6 4.7 3.4Adjusted EBITDA$297.7 $134.4 $110.954Table of Contents Year Ended December 31, 2013 2012 2011EBITDA: Net cash provided by operating activities$188.3 $102.1 $86.3Net changes in operating assets and liabilities(19.6) (4.1) (4.2)Provision for doubtful accounts1.1 — —Amortization of debt-related deferred costs, discounts and premiums(9.2) (5.5) (3.5)Market adjustment on interest rate swap1.7 — —Gain (loss) on contingent consideration(31.4) 6.8 17.2Gain on long-lived assets5.3 — 1.1Goodwill impairment(4.1) — —Loss from unconsolidated affiliates, net(0.1) — —Non-cash equity compensation expense(17.4) (1.9) (0.9)Deferred income taxes2.8 — —Interest and debt expense, net77.9 35.8 27.6Provision for income taxes1.0 1.2 1.3Other non-cash income(0.1) 0.2 —EBITDA$196.2$134.6$124.9Non-cash equity compensation expense17.4 1.9 0.9(Gain) loss on contingent consideration31.4 (6.8) (17.2)Gain on long-lived assets(5.3) — (1.1)Goodwill impairment4.1 — —Loss from unconsolidated affiliates, net0.1 — —Adjusted EBITDA from unconsolidated affiliates2.5 — —Change in fair value of derivative contracts10.7 — —Significant transaction related costs and other items40.6 4.7 3.4Adjusted EBITDA$297.7 $134.4 $110.955Table of ContentsThe following tables summarize the EBITDA of our segments (in millions): Year Ended December 31, 2013 Gathering andProcessing NGL and CrudeServices Storage andTransportationOperating revenues$291.2 $1,031.3 $104.2Costs of product/services sold56.6 930.0 15.7Operating and administrative expense (1)54.9 37.6 12.1Goodwill impairment(4.1) — —Gain (loss) on long-lived assets5.4 (0.1) —Loss on contingent consideration(31.4) — —Earnings (loss) from unconsolidated affiliates0.1 (0.2) —EBITDA$149.7 $63.4 $76.4 Year Ended December 31, 2012 Gathering andProcessing NGL and CrudeServices Storage andTransportationOperating revenues$239.5 $— $—Costs of product/services sold39.0 — —Operating and administrative expense (1)43.1 — —Gain on contingent consideration6.8 — —EBITDA$164.2 $— $— Year Ended December 31, 2011 Gathering andProcessing NGL and CrudeServices Storage andTransportationOperating revenues$205.8 $— $—Costs of product/services sold38.8 — —Operating and administrative expense (1)36.3 — —Gain on contingent consideration17.2 — —Gain on long-lived assets1.1 — —EBITDA$149.0$—$—(1)Operating and administrative expense related to our Corporate operations totaled $93.5 million, $29.6 million and $24.1 million for the years ended December 31, 2013, 2012and 2011.Segment ResultsBelow is a discussion of the factors that impacted EBITDA by segment for the three years ended December 31, 2013, 2012 and 2011.Gathering and Processing:Revenues for our gathering and processing ("G&P") segment increased by approximately $51.7 million (or 22%) during the year ended December 31, 2013compared to the same period in 2012, although our G&P segment’s EBITDA decreased by $14.5 million for that same period. The decrease in EBITDA wasprimarily the result of a $31.4 million loss on contingent consideration recorded during 2013. This non-cash accrual reflects the fair value of an earn-outpremium associated with the original acquisition of our Marcellus G&P assets from Antero in 2012. This earn-out provision allows Antero to receive anadditional $40 million payment during the first quarter of 2015 if gathering volumes exceed a certain threshold in the acquisition agreements, which was basedon original acquisition forecasts. Based on our current forecasts, we believe our Marcellus gathering volumes will exceed that threshold in 2014.56Table of ContentsPartially offsetting this decrease in EBITDA year-over-year was a $22.3 million increase in the operating margin (defined as operating revenues less costs ofproduct/services sold and operating and administrative expense) due to a 21% increase in gathering volumes and an increase in compression volumes in 2013compared to 2012. We gathered approximately 365 Bcf of natural gas on our G&P systems in 2013, compared to 301 Bcf in 2012, which was primarilydriven by our acquisition of assets from Antero and Devon Corporation (“Devon”) in 2012 and continued expansion of our assets in the Marcellus Shale inorder to capitalize on increased producer activity. We compressed approximately 107 Bcf of natural gas on our Marcellus system during 2013, which relatedprimarily to the acquisition of assets from Enerven Compression, LLC (“Enerven”) in December 2012 and construction of additional compression assets inthe Marcellus Shale.Our G&P EBITDA for the year ended December 31, 2012 increased by approximately $15.2 million compared to the same period in 2011. This was dueprimarily to an increase in our gathering volumes resulting from the acquisitions from Antero and Devon.During the years ended December 31, 2013, 2012, and 2011, several other significant transactions impacted our G&P segment which were not related to ourcore operating activities:Year Ended December 31, 2013:•$4.4 million gain on sale of a cryogenic plant and associated equipment;•$4.1 million impairment of goodwill on our Haynesville/Bossier Shale operations as a result of a decrease in anticipated revenues due primarily toour inability to renew and extend a significant revenue contract that expired in mid-2013; and•$31.4 million loss on contingent consideration in connection with the acquisition of the Antero assets. See “Critical Accounting Estimates” below fora further discussion of the contingent consideration.Year Ended December 31, 2012:•$6.8 million gain on contingent consideration as result of the reduction in the fair value of the conditional consideration we agreed to pay Quicksilverrelated to the Crestwood TransactionYear Ended December 31, 2011:•$17.2 million gain on contingent consideration as result of the reduction the fair value of the conditional consideration we agreed to pay Quicksilverrelated to the Crestwood Transaction; and•$1.1 million gain on the exchange of property, plant and equipmentOn July 19, 2013, Crestwood Niobrara acquired a 50% interest in a gathering system located in the PRB Niobrara for $107.5 million. For the year endedDecember 31, 2013, we recorded earnings from our unconsolidated affiliate, Jackalope, of approximately $0.1 million, which primarily related to (i) ourproportionate share of Jackalope’s net income and (ii) the amortization of the excess of our investment balance compared to Jackalope’s net assets which wasapproximately $1.4 million for the year ended December 31, 2013. For the period from July 19, 2013 to December 31, 2013, Jackalope gathered 45 MMcf/d ofnatural gas through its assets.NGL and Crude Services:Our NGL and crude services segment reflects only the results of our operations from June 19, 2013 (the date that Crestwood Holdings acquired control of ourgeneral partner) to December 31, 2013. Accordingly, the following discusses the results of operations of our NGL and crude services segment for the sixmonths ended December 31, 2013.Our NGL and crude services segment’s EBITDA was significantly impacted by our COLT Hub crude oil terminal in the Bakken Shale, which contributed amajority of the segment's EBITDA during the six months ended December 31, 2013. We have entered into contracts with several customers to provideadditional throughput and storage services starting in the fourth quarter of 2013, which we believe will positively contribute to the EBITDA generated by theCOLT Hub in the future.Our other NGL and crude businesses benefited from colder weather and high demand for NGL products during the six months ended December 31, 2013.57Table of ContentsOn November 8, 2013, we acquired Arrow Midstream Holdings, LLC ("Arrow"), which owns substantial crude oil, natural gas and water gathering systemslocated in the Bakken Shale. Accordingly, Arrow's operations only contributed to our NGL and crude services segment's EBITDA for the period fromNovember 8, 2013 to December 31, 2013. We believe that these operations will contribute additional EBITDA in the future to our NGL and crude servicessegment through its core crude, natural gas and water gathering services, and by enhancing commercial opportunities for our COLT Hub and our other NGLand crude businesses.Storage and Transportation:Our storage and transportation segment reflects only the results of our operations from June 19, 2013 (the date that Crestwood Holdings acquired control of ourgeneral partner) to December 31, 2013. Accordingly, the following discusses the results of operations of our storage and transportation segment for the sixmonths ended December 31, 2013.Our storage and transportation segment’s EBITDA was driven primarily by our Stagecoach natural gas storage facility and our MARC I pipeline located in theMarcellus Shale, which combined contributed $58.7 million of the segment’s EBITDA during the six months ended December 31, 2013. Our MARC Ipipeline has experienced favorable revenues from its interruptible services as well as continued demand for transportation capacity in the region. Our North-South Facilities continue to benefit from high demand for their interruptible wheeling services from producers and other customers given transportation basisspreads in the region.Our remaining operations in the segment continue to perform consistently, other than our Tres Palacios natural gas storage facility, which continues toexperience lower demand for its services due to depressed natural gas prices, lower seasonal natural gas spreads and less natural gas price volatility.Other ResultsOur consolidated EBITDA for the year ended December 31, 2013 was $196.2 million, an increase of $61.6 million from 2012 and an increase of $9.7million for the year ended December 31, 2012 compared to 2011. Our consolidated Adjusted EBITDA for the year ended December 31, 2013 was $297.7million, an increase of $163.3 million from 2012 and an increase of $23.5 million for the year ended December 31, 2012 compared to 2011.The increase in our EBITDA and Adjusted EBITDA was primarily driven by our segment results described above. Partially offsetting those results were theoperating and administrative costs of our Corporate and other operations, which totaled $93.5 million, $29.6 million and $24.1 million for the years endedDecember 31, 2013, 2012 and 2011. The increase in these operating and administrative costs were driven by the assets acquired as a result of the CrestwoodMerger in 2013 and the Antero, Devon and Enerven acquisitions during 2012. Also contributing to the increase was primarily legal and other consultingexpenses we incurred to evaluate certain transaction opportunities, which were approximately $40.6 million, $4.7 million and $3.4 million during the yearsended December 31, 2013, 2012 and 2011. We also had increases in payroll and related benefit costs, which reflects the increased scope of our businessoperations, and an increase of $15.5 million and $1.0 million of expenses related to our equity compensation plans during the years ended December 31, 2013and 2012.Items not affecting EBITDA include the following:Depreciation, Amortization and Accretion Expense - During the year ended December 31, 2013, our depreciation, amortization and accretion expenseincreased compared to 2012 and 2011 primarily due to the assets acquired from Antero, Devon and Enerven during 2012. In addition, we recordedapproximately $75.7 million of depreciation and amortization expense related to our NGL and crude services assets and our storage and transportation assetsfrom June 19, 2013 (the date that Crestwood Holdings acquired control of our general partner) to December 31, 2013, which contributed to our increase yearover year.Interest and Debt Expense - Interest and debt expense increased for the year ended December 31, 2013 compared to 2012 and 2011, primarily due to (i) higheroutstanding balances on our credit facilities, net of repayments; (ii) the issuance of an additional $150 million of 7.75% senior notes in November 2012; (iii)the assumption of $1.1 billion of long-term debt due to the Crestwood Merger; and (iv) the issuance of $600 million of 6.125% senior notes in November2013.58Table of ContentsThe following table provides a summary of interest and debt expense (in millions): Year Ended December 31, 2013 2012 2011Credit facilities$25.4 $17.6 $13.0Senior notes49.8 17.8 12.2Bridge loan— — 2.5Capital lease interest0.2 0.2 0.1Other debt-related costs5.9 0.4 —Gross interest and debt expense81.3 36.0 27.8Less: capitalized interest3.4 0.2 0.2Interest and debt expense, net$77.9 $35.8 $27.6Liquidity and Sources of CapitalWe are a partnership holding company that derives all of our operating cash flow from our operating subsidiaries. Our principal sources of liquidity includecash generated by operating activities, credit facilities, debt issuances, and sales of our common units. Our operating subsidiaries use cash from theirrespective operations to fund their operating activities and maintenance capital expenditures. We use cash generated by our operating subsidiaries and, ifapplicable, borrowings under our CEQP credit facility to service our outstanding indebtedness, fund growth capital expenditures, and make distributions tounitholders. We do not guarantee indebtedness of, or have similar commitments to, our affiliates, including Crestwood Holdings or Crestwood Midstream.We believe that anticipated cash from operations, cash distributions from Crestwood Midstream, available borrowing capacity under our credit facility and theissuances of additional debt and equity in the capital markets will be sufficient to meet our liquidity needs for the foreseeable future. Moreover, given that asubstantial portion of our consolidated assets are conducted through Crestwood Midstream, we do not anticipate the need to raise additional capital in theforeseeable future. However, to the extent we need to raise additional capital, we cannot provide assurances that we will be able to raise the additional capital tomeet these needs. As of December 31, 2013, we had $116.3 million of remaining capacity under our CEQP credit facility.Contemporaneously with the closing of the Crestwood Merger, Crestwood Midstream entered into a new $1 billion five-year senior secured credit facility witha syndicate of financial institutions. We believe this facility is sized sufficiently to fund its growth plans and working capital needs. From time to timethereafter, Crestwood Midstream may borrow funds under the revolving credit facility for general partnership purposes, including acquisitions. Subject tolimited exception, the credit facility is secured by substantially all of the equity interests and assets of Crestwood Midstream's domestic restricted subsidiaries,and is jointly and severally guaranteed by substantially all of Crestwood Midstream's domestic restricted subsidiaries. As of December 31, 2013, CrestwoodMidstream had $554.4 million of remaining capacity under the credit facility.See Part IV, Item 15, Exhibits and Financial Statement Schedules, Note 9 for a more detailed description of our CEQP credit facility and CrestwoodMidstream’s $1 billion secured credit facility. The following table provides a summary of our cash flows by category (in millions): Year Ended December 31, 2013 2012 2011Net cash provided by operating activities$188.3 $102.1 $86.3Net cash used in investing activities(1,042.9) (616.6) (456.5)Net cash provided by financing activities859.7 513.8 371.059Table of ContentsOperating ActivitiesDuring the year ended December 31, 2013, we experienced an increase in our operating revenues compared to 2012 and 2011 primarily due to (i) assetacquisitions during 2012; and (ii) revenues of approximately $1.1 billion related to our NGL and crude and storage and transportation segments from June19, 2013 (the date that Crestwood Holdings acquired control of our general partner) to December 31, 2013. Partially offsetting these increases in operatingrevenues was higher operating and administrative expenses and costs of product/services sold. In addition, our interest costs increased due to higheroutstanding balances on our credit facilities.Investing ActivitiesThe energy midstream business is capital intensive, requiring significant investments for the acquisition or development of new facilities. We categorize ourcapital expenditures as either:•growth capital expenditures, which are made to construct additional assets, expand and upgrade existing systems, or acquire additional assets; or•maintenance capital expenditures, which are made to replace partially or fully depreciated assets, to maintain the existing operating capacity of ourassets, extend their useful lives or comply with regulatory requirements.The following table summarizes our capital expenditures for the year ended December 31, 2013 (in millions). We have identified additional growth capitalproject opportunities for each of our reporting segments. Additional commitments or expenditures will be made at our discretion, and any discontinuation of theconstruction of these projects will likely result in less future cash flow and earnings.Growth capital$319.7Maintenance capital13.4Other(1)13.9Total$347.0(1) Represents capital expenditures that are reimbursable by third parties.During 2014, we anticipate growth capital expenditures of approximately $405 million to $430 million, which includes contributions to our equity investmentsrelated to their capital projects. In addition, we expect to spend between $23 million to $26 million on maintenance capital expenditures. We anticipate that ourgrowth capital expenditures in 2014 will increase the gathering, processing, compression and overall capacity of our systems, primarily in the Marcellus,Bakken and PRB Niobrara Shales. We expect to finance our growth and maintenance capital expenditures with a combination of cash provided by operationsand borrowing on the Crestwood Midstream senior secured credit facility.Our cash flows from investing activities were impacted by the following significant items during the three years ended December 31, 2013, 2012 and 2011.Year Ended December 31, 2013:In November 2013, Crestwood Midstream paid approximately $750 million to acquire the Arrow crude oil, natural gas and produced water gathering systemsin the Bakken. In addition, during the year ended December 31, 2013, we invested an additional $24.9 million in the Arrow system to fund its continuedbuild out.In September 2013, Crestwood Crude Logistics LLC paid approximately $22.5 million to acquire a 50.01% interest in PRBIC, which is developing a crudeoil rail terminal to serve producers in the PRB Niobrara. In addition, during the year ended December 31, 2013, we contributed an additional $1.9 million toPRBIC to funds its construction plans.In July 2013, Crestwood Niobrara paid $107.5 million to acquire a 50% interest in Jackalope, which is developing a gathering and processing system locatedin the PRB Niobrara play for Chesapeake, RKI and other producers. In addition, during the year ended December 31, 2013, Crestwood Niobrara contributedan additional $19.6 million to Jackalope to fund its construction projects.60Table of ContentsYear Ended December 31, 2012:During the year ended December 31, 2012, we paid approximately $564.0 million to acquire assets from Antero, Devon and Enerven. In addition, we spentapproximately $52.6 million on capital expenditures, including $4.1 million related to maintenance capital expenditures.Year Ended December 31, 2011:During the year ended December 31, 2011, we paid approximately $414.1 million to acquire our Fayetteville, Granite Wash, Las Animas and Sabine systems.In addition, we received approximately $6.0 million related to the exchange of property, plant and equipment.Financing ActivitiesSignificant items impacting our financing activities during the years ended December 31, 2013, 2012 and 2011 included the following:Equity Transactions•$595.5 million of net proceeds from the issuance of Inergy Midstream common units in 2013;•$118.5 million, $217.5 million and $53.6 million of net proceeds from the issuance of Legacy Crestwood common units in 2013, 2012 and2011;•$152.7 million in net proceeds from the issuance of Legacy Crestwood Class C units in 2011;•$8.7 million contribution from the member of Legacy Crestwood GP during 2011;Debt Transactions•$2,466.9 million, $706.7 million and $415.2 million of net proceeds from the issuance of long-term debt in 2013, 2012 and 2011;•$1,967.6 million, $534.0 million and $186.2 million of principal payments on our long-term debt in 2013, 2012 and 2011; andOther•The payment of Sabine System acquisition deferred payment of approximately $8 million in 2012.In January 2013, Legacy Crestwood acquired Crestwood Holdings’ 65% membership interest in CMM for approximately $258.0 million, which was fundedthrough $129.0 million of borrowings under its credit facility and the issuance of approximately $129.0 million of equity to Crestwood Holdings.In July 2013, Crestwood Niobrara acquired a 50% interest in a joint venture which was funded through (i) a capital contribution of approximately $26.9million by Legacy Crestwood, which it funded with borrowings under its credit facility, and (ii) Crestwood Niobrara’s issuance of approximately $80.6million of preferred securities to GE. Crestwood Niobrara expects to fund up to 75% of its future capital contributions to Jackalope through the issuance ofadditional preferred securities to GE (up to a maximum of an additional $53.9 million), with the remaining portion of such capital contributions to be fundedby Crestwood Midstream capital contributions to Crestwood Niobrara. During the year ended December 31, 2013, GE contributed an additional $15.5million to Crestwood Niobrara in exchange for an equivalent number of preferred units. Crestwood Midstream serves as the managing member of CrestwoodNiobrara and, subject to certain restrictions, has the ability to redeem GE’s preferred securities in either cash or Crestwood Midstream common units.In November 2013, Crestwood Midstream issued 8,826,125 common units as part of the consideration paid for the acquisition of Arrow.Off-Balance Sheet ArrangementsWe had no significant off-balance sheet arrangements as of December 31, 2013.61Table of ContentsContractual ObligationsWe are party to various contractual obligations. A portion of these obligations are reflected in our financial statements, such as long-term debt and otheraccrued liabilities, while other obligations, such as operating leases, capital commitments and contractual interest amounts are not reflected on our balancesheet. The following table and discussion summarizes our contractual cash obligations as of December 31, 2013 (in millions): Less than 1 Year 1-3 Years 3-5 Years Thereafter TotalLong-term debt: Principal$5.1 $380.2 $422.5 $1,452.3 $2,260.1Interest(a)116.4 228.0 209.2 182.2 735.8Future minimum payments under operatingleases(b)18.2 34.5 30.1 247.5 330.3Future minimum payments under capitalleases(b)2.6 1.9 0.3 — 4.8Asset retirement obligations— — — 15.1 15.1Fixed price commodity purchase commitments(c)232.9 1.2 — — 234.1Standby letters of credit83.4 — — — 83.4Growth capital-related purchase commitmentsand other contractual obligations(d)97.6 — — — 97.6Total contractual obligations$556.2 $645.8 $662.1 $1,897.1 $3,761.2 (a)$570.9 million of our long-term debt, including interest rate swaps, is variable interest rate debt at prime rate or LIBOR plus an applicable spread. These rates plus theirapplicable spreads were between 2.67% and 4.75% at December 31, 2013. These rates have been applied for each period presented in the table.(b)See Part IV, Item 15, Exhibits and Financial Statement Schedules, Note 15 for a further discussion of these obligations.(c)Fixed price purchase commitments are volumetrically offset by third party fixed price sale contracts.(d)Includes identified growth projects primarily related to the Watkins Glen NGL development project, the COLT Hub growth project, growth projects related to the expansion ofour compression facilities in the Marcellus Shale and certain upgrades to the US Salt facility, as well as environmental obligations included in other current liabilities on ourbalance sheet. Other contractual purchase obligations are defined as legally enforceable agreements to purchase goods or services that have fixed or minimum quantities andfixed or minimum variable price provisions, and that detail approximate timing of the underlying obligations.Critical Accounting EstimatesThe preparation of financial statements in conformity with GAAP requires management to select appropriate accounting estimates and to make estimates andassumptions that affect the reported amount of assets, liabilities, revenues and expenses and the disclosures of contingent assets and liabilities. We considerour critical accounting estimates to be those that require difficult, complex, or subjective judgment necessary in accounting for inherently uncertain mattersand those that could significantly influence our financial results based on changes in those judgments. Changes in facts and circumstances may result inrevised estimates and actual results may differ materially from those estimates. We have discussed the development and selection of the following criticalaccounting estimates and related disclosures with the Audit Committee of the board of directors of our general partner.Long-Lived AssetsOur long-lived assets consist primarily of property, plant and equipment and intangible assets that have been obtained through multiple historical businesscombinations. The initial recording of a majority of these long-lived assets was at fair value, which is estimated by management primarily utilizing market-related information and other projections on the performance of the assets acquired. Management reviews this information to determine its reasonableness incomparison to the assumptions utilized in determining the purchase price of the assets in addition to other market-based information that was received throughthe purchase process and other sources. These projections also include projections on potential and contractual obligations assumed in these acquisitions, suchas the cavern lease obligation associated with our Tres Palacios facility. Due to the imprecise nature of the projections and assumptions utilized in determiningfair value, actual results can, and often do, differ from our estimates.62Table of ContentsWe also utilize assumptions related to the useful lives and related salvage value of our property, plant and equipment in order to determine depreciation andamortization expense each period. Due to the imprecise nature of the projections and assumptions utilized determining useful lives, actual results can, andoften do, differ from our estimates.To estimate the useful life of our finite lived intangible assets we utilize assumptions of the period over which the assets are expected to contribute directly orindirectly to our future cash flows. Generally this requires us to amortize our intangible asset based on the expected future cash flows, to the extent they arereadily determinable, of the acquired contracts or customer relationship. Due to the imprecise nature of the projections and assumptions utilized determiningfuture cash flows, actual results can, and often do, differ from our estimates.We continually monitor our business, the business environment and the performance of our operations to determine if an event has occurred that indicates thata long-lived asset may be impaired. If an event occurs, which is a determination that involves judgment, we may be required to utilize cash flow projections toassess our ability to recover the carrying value of our assets based on our long-lived assets' ability to generate future cash flows on an undiscounted basis.Projected cash flows of the asset are generally based on current and anticipated future market conditions, which require significant judgment to makeprojections and assumptions about pricing, demand, competition, operating costs, construction costs, legal and regulatory issues and other factors that mayextend many years into the future and are often outside of our control. If those cash flow projections indicate that the long-lived asset's carrying value is notrecoverable, we record an impairment charge for the excess of carrying value of the asset over its fair value. The estimate of fair value considers a number offactors, including the potential value we would receive if we sold the asset, discount rates and projected cash flows. Due to the imprecise nature of theseprojections and assumptions, actual results can and often do, differ from our estimates.The value of the assets to be disposed of is estimated at the date a commitment to dispose the asset is made. Our estimate of any loss associated with an assetsale is dependent on certain assumptions we make with respect to the net realizable value of the particular asset.We have not recorded any significant impairments of our long-lived assets during 2013, 2012 or 2011.Goodwill ImpairmentOur goodwill represents the excess of the amount we paid for a business over the fair value of the net identifiable assets acquired. We evaluate goodwill forimpairment annually, and whenever events or changes indicate that it is more likely than not that the fair value of a reporting unit could be less than itscarrying amount. This evaluation requires us to compare the fair value of each of our reporting units to its carrying value (including goodwill). If the fair valueexceeds the carrying amount, goodwill of the reporting unit is not considered impaired. In conjunction with the reverse merger, we modified our segments andnow our financial statements reflect three operating and reporting segments; (i) gathering and processing operations; (ii) NGL and crude services operations;and (iii) storage and transportation operations. We have identified 13 reporting units within these three operating and reporting segments. We had approximately$2.6 billion of goodwill as of December 31, 2013, the substantial majority of which was related to our storage and transportation assets in or near theMarcellus Shale, our COLT Hub terminal and related operations in the Bakken Shale, our NGL and crude supply and logistics operations and our gatheringand processing operations in the Barnett Shale.We estimate the fair value of our reporting units based on a number of factors, including the potential value we would receive if we sold the reporting unit,enterprise value, discount rates and projected cash flows. Estimating projected cash flows requires us to make certain assumptions as it relates to futureoperating performance. When considering operating performance, various factors are considered such as current and changing economic conditions and thecommodity price environment, among others. Due to the imprecise nature of these projections and assumptions, actual results can and often do, differ fromour estimates. If the growth assumptions embodied in the current year impairment testing prove inaccurate, we could incur an impairment charge.We utilized a qualitative goodwill impairment assessment at December 31, 2013 for the goodwill recorded as part of the reverse acquisition on June 19, 2013.The qualitative assessment was utilized for this goodwill due to the recent fair value calculation performed as part of the purchase accounting for the reverseacquisition. No impairment indicators were identified as part of this qualitative assessment. We utilized a quantitative goodwill impairment assessment for allother goodwill at December 31, 2013.63Table of ContentsBased on our goodwill impairment analysis at December 31, 2013, we believe that a 5% decrease in the estimated future cash flows or a 1% increase in thediscount rate used to estimate the fair value of our reporting units would not have resulted in a material impairment of our goodwill related to any of ourreporting units for which we performed a quantitative goodwill impairment assessment, other than potentially $257.2 million of the goodwill related to ourBarnett Shale reporting unit and $14.2 million of goodwill related to our Granite Wash reporting unit.During the year ended December 31, 2013, we recorded an impairment of goodwill of approximately $4.1 million on our Haynesville/Bossier Shale system asa result of a decrease in anticipated revenues to be generated from those operations due primarily to our inability to renew and extend a significant revenuecontract that expired in mid-2013.Revenue RecognitionWe gather, treat, compress, process, store, transport and sell various commodities pursuant to fixed-fee and percent-of-proceeds contracts. We recognizerevenue on these contracts when certain criteria are met, the most important of which is that the delivery of the service has been performed. Certain of ourcontracts in our NGL and crude services segment and our gathering and processing segment contain minimum volume features under which the customersmust deliver a set quantity of crude or gas or pay a deficiency fee based on the amount the customers’ actual volume is short of the contractual minimumvolume. The minimum volume feature generally allows customers a recoupment period in subsequent periods to make up certain previous volumetricshortfalls by delivering additional crude or gas above their minimum threshold. We recognize revenue from these contracts based on the physical volume thatis delivered to our systems in the current period and any minimum volume deficiency amounts billable to customers under the minimum volume features arerecorded as a deferred revenue liability until we determine that the revenue is earned. We will recognize the deferred revenue as income at such time as thecustomer does not have the physical ability to make up the deficiency due to system capacity limitations or the contractually allowed recoupment periodexpires. At December 31, 2013 and 2012, we had deferred revenue of approximately $2.1 million and $2.6 million, which is reflected as accrued expensesand other liabilities on our consolidated balance sheets.Contingent ConsiderationWe record earn-out provisions related to certain acquisitions at their fair value as of the date of the acquisition. We estimate the fair value of our liability basedon the probability-weighted discounted cash flows and estimated production levels of the acquired assets. As additional information becomes available, weadjust the fair value of the earn-out provision and recognize a gain or loss in our statement of income. In connection with the acquisition of the Antero assets,we agreed to pay Antero conditional consideration in the form of potential additional cash payments of up to $40 million, depending on the achievement ofcertain defined average annual production levels achieved during 2012, 2013 and 2014. During 2012 and 2013, Antero did not meet the annual productionlevel to earn additional payments. Based on our estimates of Antero’s 2014 production, we believe their production levels may exceed the annual productionthreshold in the earn-out provision and accordingly we have recognized a $31.4 million liability that represents the fair value of the potential payments thatmay be made under this earn-out provision. Due to the imprecise nature of these projections and assumptions, actual results can and often do, differ from ourestimates.Item 7A. Quantitative and Qualitative Disclosures About Market RiskInterest Rate RiskIn order to maintain a cost effective capital structure, it is our policy to borrow funds using a mix of fixed rate debt and variable rate debt. The market riskinherent in our debt instruments is the potential change arising from increases or decreases in interest rates as discussed below.For fixed rate debt, changes in the interest rates generally affect the fair value of the debt instrument, but not our earnings or cash flows. Conversely, forvariable rate debt, changes in interest rates generally do not impact the fair value of the debt instrument, but may affect our future earnings and cash flows. As of December 31, 2013, the carrying value and fair value of our fixed rate debt instruments (including debt fair value adjustments) was approximately$1,467.3 million and $1,522.0 million, respectively. As of December 31, 2012, the carrying value and fair value of our fixed rate debt instruments wasapproximately $351.5 million and $365.9 million. For a further discussion of our fixed rate debt, see Part IV, Item 15, Exhibits and Financial StatementSchedules, Note 9.64Table of ContentsWe have two credit facilities that are subject to the risk of loss associated with changes in interest rates. At December 31, 2013, we had obligations totaling$570.9 million borrowed under these credit facilities (net of certain interest rate swaps, which convert the interest rate on one of our credit facilities to a fixedrate). These obligations expose us to the risk of increased interest payments in the event of increases in short-term interest rates. Floating rate obligations exposeus to the risk of increased interest expense in the event of increases in short-term interest rates. If the interest rate on our credit facilities were to fluctuate by 1%from the rate as of December 31, 2013, our annual interest expense would have changed by a total of $5.7 million.Commodity Price, Market and Credit RiskInherent in our business are certain business risks, including market risk and credit risk.Market RiskIn our businesses other than our NGL and crude logistics operations, we typically do not take title to the natural gas, NGLs or crude oil that we gather, store,or transport for our customers. However, we do take title to (i) NGLs under certain of our percent-of-proceeds contracts (G&P segment); (ii) crude oilpurchased from certain of our Arrow producer customers for our marketing operations (NGL and crude oil segment); and (iii) line pack and base gas that wepurchase for our natural gas storage and transportation facilities (storage and transportation segment). Our current business model is designed to minimize ourexposure to fluctuations in commodity prices, although we are willing to assume commodity price risk in certain processing and marketing activities. Weremain subject to volumetric risk under contracts without minimal volume commitments or take-or-pay pricing terms, but absent other market factors thatcould adversely impact our operations (e.g., market conditions that negatively influence our producer customers’ decisions to develop or producehydrocarbons), changes in the price of natural gas, NGLs or crude oil should not materially impact our operations. In our NGL and crude logistics operations, we consider market risk to be the risk that the value of our NGL and crude services segment's portfolio willchange, either favorably or unfavorably, in response to changing market conditions. We take an active role in managing and controlling market risk and haveestablished control procedures, which are reviewed on an ongoing basis. We monitor market risk through a variety of techniques, including daily reporting ofthe portfolio's position to senior management. We attempt to minimize credit risk exposure through credit policies and periodic monitoring procedures as well asthrough customer deposits, letters of credit and entering into netting agreements that allow for offsetting counterparty receivable and payable balances forcertain financial transactions, as deemed appropriate. The counterparties associated with assets from price risk management activities as of December 31,2013 were energy marketers, propane retailers, resellers, and dealers.We engage in hedging and risk management transactions, including various types of forward contracts, options, swaps and futures contracts, to reduce theeffect of price volatility on our product costs, protect the value of our inventory positions and to help ensure the availability of propane during periods of shortsupply. We attempt to balance our contractual portfolio by purchasing volumes only when we have a matching purchase commitment from our marketingcustomers. However, we may experience net unbalanced positions from time to time, which we believe to be immaterial in amount. In addition to our ongoingpolicy to maintain a balanced position, for accounting purposes we are required, on an ongoing basis, to track and report the market value of our derivativeportfolio. These derivatives are not designated as hedges for accounting purposes.The fair value of the derivatives and inventory exchange contracts related to price risk management activities as of December 31, 2013 were assets of $14.5million and liabilities of $34.9 million. We use observable market values for determining the fair value of our trading instruments. In cases where activelyquoted prices are not available, other external sources are used that incorporate information about commodity prices in actively quoted markets, quoted pricesin less active markets and other market fundamental analysis. Our risk management department regularly compares valuations to independent sources andmodels on a quarterly basis. A theoretical change of 10% in the underlying commodity value would result in a $5.3 million change in the market value of thesecontracts as there were 41.7 million gallons of net unbalanced positions at December 31, 2013. Inventory positions of 42.2 million gallons would substantiallyoffset this theoretical change at December 31, 2013.65Table of ContentsCredit RiskCredit risk is the risk of loss from nonperformance by suppliers, customers or financial counterparties to a contract. We take an active role in managing andcontrolling credit risk and have established control procedures, which are reviewed on an ongoing basis. Our primary credit risk relates to our dependency onQuicksilver for a portion of our revenues, which causes us to be subject to the risk of nonpayment or late payment by Quicksilver. Quicksilver's creditratings are below investment grade, where they may remain for the foreseeable future. We have diversified this risk through having long term contracts withmany investment grade customers and creditworthy producers. Additionally, we perform credit analyses of our customers on a regular basis pursuant to ourcorporate credit policy. We have not had any significant losses due to failures to perform by our counterparties.Item 8. Financial Statements and Supplementary Data.Reference is made to the financial statements and report of independent registered public accounting firm included later in this report under Item 15.Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure.None.Item 9A. Controls and Procedures.Disclosure Controls and ProceduresAs of December 31, 2013, we carried out an evaluation under the supervision and with the participation of our management, including the Chief ExecutiveOfficer and Chief Financial Officer of our General Partner, as to the effectiveness, design and operation of our disclosure controls and procedures (as definedin the Securities Exchange Act of 1934, as amended (Exchange Act) Rules 13a-15(e) and 15d-15(e)). This evaluation considered the various processes carriedout under the direction of our disclosure committee in an effort to ensure that information required to be disclosed in the SEC reports we file or submit underthe Exchange Act is accurate, complete and timely. Our management, including the Chief Executive Officer and Chief Financial Officer of our General Partner,does not expect that our disclosure controls and procedures or our internal controls will prevent and/or detect all errors and all fraud. A control system, nomatter how well conceived and operated, can provide only reasonable, not absolute, assurance that the objectives of the control system are met. Further, thedesign of a control system must reflect the fact that there are resource constraints, and the benefits of controls must be considered relative to their costs. Ourdisclosure controls and procedures are designed to provide reasonable assurance of achieving their objectives and our Chief Executive Officer and ChiefFinancial Officer of our General Partner concluded that our disclosure controls and procedures were effective at the reasonable assurance level as ofDecember 31, 2013.Changes in Internal Control over Financial ReportingWe completed the Crestwood Merger on October 7, 2013. We have extended our oversight and monitoring processes that support our internal control overfinancial reporting to include Legacy Inergy’s operations. Except for this extension, we did not make any changes to our internal control over financialreporting during the fourth quarter of 2013 that have materially affected, or are reasonably likely to materially affect our internal control over financialreporting.Management’s Report on Internal Control Over Financial ReportingOur management is responsible for establishing and maintaining adequate internal control over financial reporting, pursuant to Exchange Act Rules 13a-15(f).Our internal control system was designed to provide reasonable assurance to management and our board of directors regarding the preparation and fairpresentation of published financial statements in accordance with GAAP.Management recognizes that there are inherent limitations in the effectiveness of any system of internal control, and accordingly, even effective internal controlcan provide only reasonable assurance with respect to financial statement preparation and fair presentation. Further, because of changes in conditions, theeffectiveness of internal control may vary over time.66Table of ContentsOn November 8, 2013, we acquired Arrow Midstream Holdings, LLC ("Arrow"). Management’s assessment of and conclusion on the effectiveness of internalcontrol over financial reporting excluded Arrow from its assessment and conclusion on the effectiveness of our internal control over financial reporting as ofDecember 31, 2013. The financial reporting systems of Arrow were not integrated into our financial reporting systems throughout 2013. Therefore, we did nothave the practical ability to perform an assessment of their internal controls in time for this current year-end. We fully expect to include Arrow in next year’sassessment. Arrow constituted $930.6 million and $218.8 million in total assets and revenues, respectively, in our consolidated financial statements.Under the supervision and with the participation of our management, including our Chief Executive Officer and Chief Financial Officer, we assessed theeffectiveness of our internal control over financial reporting as of December 31, 2013. In making this assessment, we used the criteria set forth by theCommittee of Sponsoring Organizations of the Treadway Commission in Internal Control-Integrated Framework. Based upon our assessment, we concludethat, as of December 31, 2013, our internal control over financial reporting is effective, based upon those criteria.Our independent registered public accounting firm, Ernst & Young LLP, issued an attestation report dated February 28, 2014, on the effectiveness of ourinternal control over financial reporting, which is included herein.Item 9B. Other Information.None.67Table of ContentsPART IIIItem 10. Directors, Executive Officers and Corporate Governance.Our General Partner Manages Crestwood Equity Partners LPCrestwood Equity GP LLC, our general partner, manages our operations and activities. Our general partner is not elected by our unitholders and will not besubject to re-election on a regular basis in the future. Our general partner may not be removed unless that removal is approved by the vote of the holders of notless than 66 2/3% of the outstanding units, including units held by the general partner and their affiliates, and we receive an opinion of counsel regardinglimited liability and tax matters. Any removal of the general partner is also subject to the approval of a successor general partner by the vote of the holders of amajority of the outstanding common units. Unitholders do not directly or indirectly participate in our management or operation. Our general partner owes afiduciary duty to the unitholders. Our general partner is liable, as a general partner, for all of our debts (to the extent not paid from our assets), except forspecific nonrecourse indebtedness or other obligations. Whenever possible, our general partner intends to incur indebtedness or other obligations that arenonrecourse. As is commonly the case with publicly-traded limited partnerships, we are managed and operated by the officers of our general partner and are subject to theoversight of the directors of our general partner. The board of directors of our general partner is presently composed of nine directors. Directors and Executive Officers The following table sets forth certain information with respect to the executive officers and members of the board of directors of our general partner. Executiveofficers and directors will serve until their successors are duly appointed or elected.Executive Officers and DirectorsAgePosition with our General PartnerRobert G. Phillips59President, Chief Executive Officer and DirectorJ. Heath Deneke40President, Natural Gas Business UnitWilliam C. Gautreaux50President, Liquids and Crude Business UnitMichael J. Campbell44Senior Vice President, Chief Financial OfficerSteven M. Dougherty41Senior Vice President, Chief Accounting OfficerJoel C. Lambert45Senior Vice President, General Counsel and Corporate SecretaryWilliam H. Moore34Senior Vice President, Strategy and Corporate DevelopmentJoel D. Moxley55Senior Vice President, Operations ServicesAlvin Bledsoe65DirectorMichael G. France36DirectorWarren H. Gfeller61DirectorArthur B. Krause72DirectorRandy E. Moeder53DirectorJohn J. Sherman58DirectorJohn W. Somerhalder II58DirectorDavid M. Wood56Director Robert G. Phillips was elected Chairman, President and Chief Executive Officer of our general partner and CMLP’s general partner in June 2013 and hasserved on the Management Committee of Crestwood Holdings since May 2010. He served as Chairman, President and CEO of Legacy Crestwood fromNovember 2007 until October 2013. Previously, Mr. Phillips served as President and Chief Executive Officer and a Director of Enterprise Products PartnersL.P. from February 2005 until June 2007 and Chief Operating Officer and a Director of Enterprise Products Partners L.P. from September 2004 until February2005. Mr. Phillips also served on the Board of Directors of Enterprise GP Holdings L.P., the general partner of Enterprise Products Partners L.P., fromFebruary 2006 until April 2007. He previously served as Chairman of the Board and CEO of GulfTerra Energy Partners, L.P. (GTM), from 1999-2004,prior to GTM's merger with Enterprise Product Partners, LP, and held senior executive management positions with El Paso Corporation, including President ofEl Paso Field Services from 1996-2004. Prior to that he was Chairman, President and CEO of Eastex Energy, Inc. from 1981-1995. Mr. Phillips previouslyserved as a Director of Pride International, Inc. from October 2007 to May 31, 2011, one of the world’s largest offshore drilling contractors, and was a memberof its audit committee. Mr. Phillips is an Advisory Director of Triten Corporation, a leading international engineering firm and alloy products manufacturer.Mr. Phillips was selected to serve as the Chairman of the Board68Table of Contentsof our general partner because of his deep experience in the midstream business, expansive knowledge of the oil and gas industry, as well as his experience inexecutive leadership roles for public companies in the energy industry and operational and financial expertise in the oil and gas business generally.J. Heath Deneke was appointed President, Natural Gas Business Unit of our general partner and CMLP’s general partner in October 2013. He served asSenior Vice President and Chief Commercial Officer of Legacy Crestwood from August 2012 until October 2013. Prior to joining Legacy Crestwood, Mr.Deneke served in various management positions at El Paso Corporation and its affiliates, including Vice President of Project Development and Engineering forthe Pipeline Group, Director of Marketing and Asset Optimization for Tennessee Gas Pipeline Company, LLC and Manager of Business Development andStrategy for Southern Natural Gas Company, LLC. Mr. Deneke holds a bachelor’s degree in Mechanical Engineering from Auburn University.William C. Gautreaux was appointed President, Liquids and Crude Business Unit of our general partner and CMLP’s general partner in October 2013. Heserved as President - Inergy Services from November 2011until October 2013. He was with Legacy Inergy since its inception in 1997 and was previouslyemployed by Ferrellgas and later co-founded and managed supply and risk management for LPG Services Group, Inc., which was acquired by Dynegy, Inc.in 1996.Michael J. Campbell has served as the Senior Vice President - Chief Financial Officer our general partner and CMLP’s general partner since September 2012.He joined Legacy Inergy in 2002 and served as the Vice President and Treasurer from May 2005 to September 2012. He previously served as Director ofFinancial Analysis in the Corporate Development department at Aquila, Inc., and as Manager of Crude and Structured Products Trading Support at KochIndustries.Steven M. Dougherty was appointed Senior Vice President, Chief Accounting Officer of our general partner and CMLP’s general partner in October 2013. Heserved as Senior Vice President, Interim Chief Financial Officer and Chief Accounting Officer of Legacy Crestwood from January 2013 to October 2013. Mr.Dougherty had served as Vice President and Chief Accounting Officer of Legacy Crestwood since June 2012. Prior to joining Legacy Crestwood, Mr.Dougherty was Director of Corporate Accounting at El Paso Corporation since 2001, with responsibility over El Paso’s corporate segment and in leading ElPaso’s efforts in addressing complex accounting matters. Mr. Dougherty also had seven years of experience with KPMG LLP, working with public and privatecompanies in the financial services industry. Mr. Dougherty holds a Master of Public Accountancy from The University of Texas at Austin and is a certifiedpublic accountant in the State of Texas.Joel C. Lambert was appointed Senior Vice President, General Counsel and Corporate Secretary of our general partner and CMLP’s general partner in October2013. He served as a director of Legacy Crestwood from October 2010 to October 2013. From 2007 until October 2013, Mr. Lambert served as Vice President,Legal of First Reserve Corporation, a private equity company which invests exclusively in the energy industry. From 1998 to 2006, Mr. Lambert was anattorney in the Business and International Section of Vinson & Elkins LLP. In 1997, he was an Intern at the Texas Supreme Court, and has served as aMilitary Intelligence Specialist for the United States Army. Mr. Lambert holds a Bachelor of Environmental Design from Texas A&M University and a JurisDoctorate from The University of Texas School of Law.William H. Moore was appointed Senior Vice President, Strategy and Corporate Development of our general partner and CMLP’s general partner in October2013. He joined Legacy Inergy in 2005 as a legal analyst and has held various positions in corporate and business development. Most recently, he served asVice President, Corporate Development. Mr. Moore holds an M.B.A from Fort Hays State University, and a Juris Doctorate from the University of KansasSchool of Law.Joel D. Moxley was appointed Senior Vice President, Operations Services of our general partner and CMLP’s general partner in October 2013. He wasappointed Senior Vice President Legacy Crestwood in October 2010 and appointed Chief Operating Officer of Legacy Crestwood in August 2011. From April2008 until joining Legacy Crestwood, Mr. Moxley was Senior Vice President of Crestwood Midstream Partners, LLC. From November 2005 to March 2008,he was Senior Vice President of Crosstex Energy, L.P. From September 2004 to November 2005, Mr. Moxley was a Senior Vice President for EnterpriseProducts Partners, L.P. From January 2001 to August 2004 he was Vice President of El Paso Corporation. From 1997 to 2000 he was a Vice President forPG&E Corporation. Mr. Moxley holds a Bachelor of Science in Chemical Engineering from Rice University.Alvin Bledsoe was appointed a director of our general partner and CMLP’s general partner in October 2013. He served as a director of Legacy Crestwood fromJuly 2007 until October 2013. Since June 2011, Mr. Bledsoe has also served as a director of SunCoke Energy, Inc. Prior to his retirement in 2005, Mr. Bledsoeserved as a certified public accountant and various senior roles for 33 years at PricewaterhouseCoopers (PwC). From 1978 to 2005, he was a senior clientengagement and audit partner for large, publicly-held energy, utility, pipeline, transportation and manufacturing companies. From 1998 to 2000, Mr. Bledsoeserved as Global Leader of PwC’s Energy, Mining and Utilities Industries Assurance and Business Advisory Services Group,69Table of Contentsand from 1992 to 2005 as a managing partner and regional managing partner. During his career, Mr. Bledsoe also served as a member of PwC’s governingbody. Mr. Bledsoe was selected to serve as a director of our general partner due to his extensive background in public accounting and auditing, includingexperience advising publicly-traded energy companies.Michael G. France was appointed as a director of our general partner and CMLP’s general partner in June 2013. He served as a director of Legacy Crestwoodfrom October 2010 to October 2013. Since 2007, Mr. France has served as a Director of First Reserve Corporation, a private equity company which investsexclusively in the energy industry. Additionally, Mr. France has served on the Management Committee of Crestwood Holdings since May 2010. From 2003 to2007, Mr. France served as a Vice President in the Natural Resources Group, Investment Banking Division, at Lehman Brothers. From 1999 to 2001, heserved as a Senior Consultant at Deloitte & Touche LLP. Mr. France currently serves on the board of directors of Cobalt International Energy, Inc. Mr. Franceholds a B.B.A. (Cum Laude) in Finance from The University of Texas at Austin and a Master of Business Administration from Jones Graduate School ofManagement at Rice University. Mr. France was elected to serve as a director of our general partner due to his years of experience in financing energy relatedcompanies including his energy investment experience at First Reserve and his general knowledge of upstream and midstream energy companies.Warren H. Gfeller has been a member of our general partner’s board of directors since March 2001 and CMLP GP’s board of directors since December 2011.He has engaged in private investments since 1991. From 1984 to 1991, Mr. Gfeller served as president and chief executive officer of Ferrellgas, Inc., a retailand wholesale marketer of propane and other natural gas liquids. Mr. Gfeller began his career with Ferrellgas in 1983 as an executive vice president andfinancial officer. Prior to joining Ferrellgas, Mr. Gfeller was the Chief Financial Officer of Energy Sources, Inc. and a CPA at Arthur Young & Co. He alsoserved as a director of Inergy Holdings GP, LLC, Zapata Corporation and Duckwall-Alco Stores, Inc. Mr. Gfeller worked for many years in the energyindustry. This experience has given him a unique perspective on our operations, and, coupled with his extensive financial and accounting training andpractice, has made him a valuable member of our board of directors. Arthur B. Krause has been a member of our general partner’s board of directors since May 2003. He served as a member of the board of directors of CMLPGP from December 2011 to October 2013. Mr. Krause retired from Sprint Corporation in 2002, where he served as Executive Vice President and ChiefFinancial Officer from 1988 to 2002. He was President of United Telephone-Eastern Group from 1986 to 1988. From 1980 to 1986, he was Senior VicePresident of United Telephone System. He currently serves as a director of Westar Energy and served as a director of Inergy Holdings GP, LLC from April2005 until November 2010. Mr. Krause’s prior leadership experience and his extensive financial and accounting training and practice have made him avaluable member of our board of directors.John J. Sherman has served as a director of our general partner since March 2001 and as a director of CMLP GP since December 2011. He served as ChiefExecutive Officer and President of our general partner from March 2001 until June 2013 and of our predecessor from 1997 until July 2001. Prior to joining ourpredecessor, he was a vice president with Dynegy Inc. from 1996 through 1997. He was responsible for all downstream propane marketing operations,which at the time were the country’s largest. From 1991 through 1996, Mr. Sherman was the president of LPG Services Group, Inc., a company he co-founded and grew to become one of the nation’s largest wholesale marketers of propane before Dynegy acquired LPG Services in 1996. From 1984 through1991, Mr. Sherman was a vice president and member of the management committee of Ferrellgas. He also served as President, Chief Executive Officer anddirector of Inergy Holdings GP, LLC and is currently a director of Great Plains Energy Inc. We believe the breadth of Mr. Sherman’s experience in the energyindustry and his past employment described above, as well as his current board of director positions, has given him valuable knowledge about our businessand our industry that makes him an asset to our board of directors.Randy Moeder was appointed as a director of our general partner in October 2013. He served as a member of the board of director of CMLP GP from March2012 to until October 2013. Mr. Moeder currently is the Chief Executive Officer and President of Moeder Oil & Gas, LLC. Mr. Moeder previously served asthe Chief Executive Officer and President of Hiland Partners, LP and Hiland Partners, GP. He also held various positions with Continental Resources, Inc.and its affiliates from 1990 to 2004. Mr. Moeder brings a wealth of oil and gas industry experience to our board. His experience with the midstream sector aswell as publicly traded master limited partnership give him valuable insight into the successful execution of our long-term growth objectives and makes him avaluable member of our board.John W. Somerhalder II was appointed as a director of our general partner in October 2013. He served as a director of Legacy Crestwood from July 2007 toOctober 2013. Mr. Somerhalder has served as the President, Chief Executive Officer and a director of AGL Resources Inc. (AGL Resources), a publicly-tradedenergy services holding company whose principal business is the distribution of natural gas, since March 2006 and as Chairman of the Board of AGLResources since November 2007. From 2000 to May 2005, Mr. Somerhalder served as the Executive Vice President of El Paso Corporation, a natural gas andrelated energy products provider and one of North America’s largest independent natural gas producers, where he continued service under a professionalservices agreement from May 2005 to March 2006. From 2001 to 2005, he served as the President70Table of Contentsof El Paso Pipeline Group. From 1996 to 1999, Mr. Somerhalder served as the President of Tennessee Gas Pipeline Company, an El Paso subsidiarycompany. From April 1996 to December 1996, Mr. Somerhalder served as the President of El Paso Energy Resources Company. From 1992 to 1996, heserved as the Senior Vice President, Operations and Engineering, of El Paso Natural Gas Company. From 1990 to 1992, Mr. Somerhalder served as the VicePresident, Engineering of El Paso Natural Gas Company. From 1977 to 1990, Mr. Somerhalder held various other positions at El Paso Corporation and itssubsidiaries until being named an officer in 1990. Mr. Somerhalder was selected to serve as a director of our general partner due to his years of experience inthe oil and gas industry and his extensive business and management expertise, including as President, Chief Executive Officer and a director of a publicly-traded energy company.David M. Wood was appointed as a director of our general partner and CMLP’s general partner in August 2013. He served as the Chief Executive Officer,President and a director of Murphy Oil Corporation from January 1, 2009 to June 2012. Mr. Wood served as the President of Murphy Exploration &Production Company for Murphy Oil Corporation since January 1, 2007 and served as its Executive Vice President of Worldwide Exploration & ProductionOperations since January 1, 2007. Prior to joining Murphy Oil Corp., Mr. Wood held various senior positions with Ashland Exploration and Production. Heserved as the President of Murphy Exploration & Production Company-International from March 2003 to December 2006 and also served as Senior VicePresident of Frontier Exploration & Production from April 1999 to February 2003. Mr. Wood served as Vice President of Frontier Exploration & Productionfor Murphy Oil Corporation from 1997 to March 1999, General Manager of Frontier Exploration from 1995 to 1997 and Manager of Frontier Explorationfrom 1994 to 1995. He served as a member of the board of directors of the American Petroleum Institute and was a member of the National PetroleumCouncil. Mr. Wood holds a Bachelor's degree in Geology from Nottingham University in England. Mr. Wood was selected to serve as a director of our generalpartner because he has over 30 years of experience within the oil and gas industry.Independent DirectorsBecause we are a limited partnership, the listing standards of the NYSE do not require that we or our general partner have a majority of independent directorson the board, nor that we establish or maintain a nominating or compensation committee of the board. We are, however, required to have an audit committeeconsisting of at least three members, all of whom are required to be independent as defined by the NYSE. The board of directors has determined that AlvinBledsoe, Warren Gfeller, Philip Gettig and David Lumpkins qualify as independent pursuant to independence standards established by the NYSE as set forthin Section 303A.02 of the manual. To be considered an independent director under the NYSE listing standards, the board of directors must affirmativelydetermine that a director has no material relationship with us other than as a director. In making this determination, the board of directors adheres to all of thespecific tests for independence included in the NYSE listing standards and considers all other facts and circumstances it deems necessary or advisable.Board CommitteesAudit CommitteeThe members of the audit committee are Alvin Bledsoe, Arthur Krause and Randy Moeder. Our board has determined that each of the members of our auditcommittee meet the independence standards of the NYSE and is financially literate. In addition, the board has determined that Mr. Bledsoe is an auditcommittee financial expert based upon the experience stated in his biography. The audit committee's primary responsibilities are to monitor: (a) the integrity ofour financial reporting process and internal control system; (b) the independence and performance of the independent registered public accounting firm; and(c) the disclosure controls and procedures established by management. Our audit committee charter may be found on our website at www.crestwoodlp.com.Compensation CommitteeAlthough we are not required by NYSE listing standards to have a compensation committee, two members of our board of directors also serve as members ofour compensation committee, which oversees compensation decisions for the executive officers of Crestwood Equity GP LLC, as well as the compensationplans described below. The members of the compensation committee are David Wood and Warren Gfeller. Our compensation committee charter may be foundon our website at www.crestwoodlp.com.71Table of ContentsConflicts CommitteeOur general partner has established a conflicts committee to review specific matters which the board of directors believes may involve conflicts of interest. Themembers of our conflicts committee are Randy Moeder and John Somerhalder. A conflicts committee will determine if the resolution of any conflict of interestsubmitted to it is fair and reasonable to us. In addition to satisfying certain other requirements, the members of the conflicts committee must meet theindependence standards for service on an audit committee of a board of directors, which standards are established by the NYSE. Any matters approved bythe conflicts committee will be conclusively deemed to be fair and reasonable to us, approved by all of our partners and not a breach by our general partner ofany duties it may owe us or our unitholders.Board Leadership StructureThe board has no policy that requires that the positions of the Chairman of the Board (the “Chairman”) and the Chief Executive Officer be separate or thatthey be held by the same individual. The board believes that this determination should be based on circumstances existing from time to time, including thecomposition, skills and experience of the board and its members, specific challenges faced by us or the industry in which it operates, and governanceefficiency. Based on these factors, Robert Phillips serves as our Chairman and Chief Executive Officer.Risk OversightWe face a number of risks, including environmental and regulatory risks, and others, such as the impact of competition. Management is responsible for theday-to-day management of risks our company faces, while the board of directors, as a whole and through its committees, has responsibility for the oversightof risk management. In fulfilling its risk oversight role, the board of directors must determine whether risk management processes designed and implementedby our management are adequate and functioning as designed. Senior management regularly delivers presentations to the board of directors on strategicmatters, operations, risk management and other matters, and is available to address any questions or concerns raised by the board. Specifically, at theFebruary 2014 audit committee meeting, senior management provided a comprehensive risk assessment to the audit committee focused on the key risks facingour company. Our board committees assist the board in fulfilling its oversight responsibilities in certain areas of risk. The audit committee assists with risk managementoversight in the areas of financial reporting, internal controls and compliance with legal and regulatory requirements and our risk management policy relatingto our hedging program. The compensation committee assists the board of directors with risk management relating to our compensation policies and programs.Meetings of Non-Management Directors Our non-management directors meet in regularly scheduled sessions. Our non-management directors have appointed Warren H. Gfeller as the lead director topreside at such meetings. In addition, our independent directors meet in executive session at least once a year.Communication with the Board of DirectorsWe have established a procedure by which unitholders or interested parties may communicate directly with the board of directors, any committee of the board,any of the independent directors or any one director serving on the board of directors by sending written correspondence addressed to the desired person,committee or group to the attention of Joel C. Lambert, Senior Vice President, General Counsel, 700 Louisiana Street, Suite 2060, Houston, TX 77002.Communications are distributed to the board of directors, or to any individual director or directors as appropriate, depending on the facts and circumstancesoutlined in the communication.Code of Ethics/Governance Guidelines We have adopted a Code of Business Conduct and Ethics that applies to our principal executive officer, principal financial officer, principal accountingofficer or controller or persons performing similar functions, as well as to all of our other employees. Additionally, the board of directors has adopted corporategovernance guidelines for the directors and the board. The Code of Business Conduct and Ethics and corporate governance guidelines may be found on ourwebsite at www.crestwoodlp.com.72Table of ContentsSection 16(a) Beneficial Ownership Reporting Compliance Section 16(a) of the Securities Exchange Act of 1934 requires our company’s directors and executive officers, and persons who own more than 10% of anyclass of equity securities of our company registered under Section 12 of the Exchange Act, to file with the Securities and Exchange Commission initial reportsof ownership and report of changes in ownership in such securities and other equity securities of our company. Securities and Exchange Commissionregulations require directors, executive officers and greater than 10% unitholders to furnish our company with copies of all Section 16(a) reports they file. Toour knowledge, based solely on review of the reports furnished to us and written representations that no other reports were required, during the fiscal yearended December 31, 2013, all section 16(a) filing requirements applicable to our directors, executive officers and greater than 10% unitholders, were met.Item 11. Executive Compensation.Compensation Discussion and Analysis IntroductionWe do not directly employ any of the persons responsible for managing our business. Crestwood Equity GP LLC, our general partner, currently manages ouroperations and activities, and its board of directors and officers make decisions on our behalf. The compensation of the directors and the executive officers ofour general partner is determined by the compensation committee of the board of directors of our general partner. All of our executive officers also serve insimilar capacities as executive officers of Crestwood Midstream GP LLC, the general partner of Crestwood Midstream Partners LP and the compensation ofthe named executive officers discussed below reflects total compensation for services to all Crestwood entities, except for prior awards of incentive units inCrestwood Holdings Partners LLC described in more detail below. Our general partner has entered into an Omnibus Agreement with us, Crestwood MidstreamGP LLC and Crestwood Midstream Partners LP wherein our general partner is reimbursed for, among other things, salaries and related benefits and expensesof persons employed by our general partner or its affiliates who render services to Crestwood Midstream Partners LP and its affiliates.During the fiscal year that began on October 1, 2012 and ended on September 30, 2013 (“Fiscal 2013”), we completed a series of transactions following whichour business and the business of Inergy Midstream, L.P. were combined with that of Crestwood Midstream Partners LP and following the completion of whichour name was changed to Crestwood Equity Partners LP and the name of Inergy Midstream, L.P. was changed to Crestwood Midstream Partners LP (the“Inergy/Crestwood Transaction”). As part of the Inergy/Crestwood Transaction, on June 19, 2013 our general partner was acquired by Crestwood GasHoldings, in connection with which certain changes to our management structure were made. Specifically, in connection with the sale of our general partner aspart of the Inergy/Crestwood Transaction, our Chief Executive Officer, our President, our Executive Vice President - Strategy, and our Senior Vice Presidentand General Counsel all terminated employment with the company during Fiscal 2013.In addition, we instituted certain changes to our compensation structure to address the anticipated turnover in our management arising in connection with theacquisition of our general partner, including the adoption of an officer severance plan and the amendment of the terms of our outstanding restricted unitawards and those of Inergy Midstream, L.P. (now known as Crestwood Midstream Partners LP) to provide for certain early vesting benefits.Due to our change in fiscal year end from September 30 to December 31, this Compensation and Analysis covers two distinct periods: (i) Fiscal 2013 and (ii) atransition period that commenced on October 1, 2013 and ended on December 31, 2013 (the “Transition Period”). For purposes of this Compensation Discussion and Analysis our named executive officers for Fiscal 2013 were comprised of:•Robert G. Phillips, our current President and Chief Executive Officer and Director (Principal Executive Officer);•John J. Sherman, Director and our former Chief Executive Officer (former Principal Executive Officer);•Michael J. Campbell, our Chief Financial Officer (Principal Financial Officer)•William C. Gautreaux, our President, Liquids and Crude Business Unit;•Michael D. Lenox, our Chief Accounting Officer during Fiscal 2013;*•Laura L. Ozenberger, our Senior Vice President and General Counsel during Fiscal 2013;*•R. Brooks Sherman, our former President; and•Phillip L. Elbert, our former Executive Vice President - Strategy.73Table of Contents*Ms. Ozenberger’s employment with the Company terminated effective as of the last day of Fiscal 2013. Mr. Lenox was constructively terminated pursuant tothe officer severance plan as of October 8, 2013.Our named executive officers for the Transition Period were comprised of:•Robert G. Phillips, our President and Chief Executive Officer and Director (Principal Executive Officer);•Michael J. Campbell, our Chief Financial Officer (Principal Financial Officer);•Joel D. Moxley, our Senior Vice President, Operations Services;•Joel C. Lambert, our Senior Vice President, General Counsel and Secretary;•J. Heath Deneke, our Senior Vice President, Chief Commercial Officer; and•Michael D. Lenox, our former Chief Accounting Officer.Because John J. Sherman, Laura L. Ozenberger and R. Brooks Sherman terminated employment prior to the commencement of the Transition Period, nocompensation was received by them with respect to the Transition Period (other than fees John J. Sherman received in respect of his service as a director,which are reflected in the “Director Compensation Table”).Compensation Philosophy and ObjectivesWe employ a compensation philosophy that emphasizes pay for performance. The primary measure of our performance long-term is our ability to increasesustainable cash distributions to our unitholders and the related unitholder value realized. We believe that by tying a substantial portion of each namedexecutive officer’s total compensation to financial, operational and safety performance metrics, our pay-for-performance approach aligns the interests ofexecutive officers with that of our unitholders. Accordingly, the objectives of our total compensation program consist of:•aligning executive compensation incentives with the creation of unitholder value and the growth of cash earnings on behalf of our unitholders;•balancing short and long-term performance;•tying short-and long-term compensation to the achievement of performance objectives (company, business unit, department and/or individual); and•attracting and retaining the best possible executive talent for the benefit of our unitholders.By accomplishing these objectives, we hope to optimize long-term unitholder value.Compensation Setting Process (applicable to Fiscal 2013 and the Transition Period)Chief Executive Officer’s Role in the Compensation Setting ProcessOur Chief Executive Officer plays a significant role in the compensation setting process. The most significant aspects of his role are:•assisting in establishing business performance goals and objectives;•evaluating executive officer and company performance;•recommending compensation levels and awards for executive officers other than himself; and•implementing the approved compensation plans.The Chief Executive Officer makes recommendations to the compensation committee with respect to financial metrics to be used for performance-based awardsas well as other recommendations regarding non-CEO executive compensation, which may be based on our performance, individual performance and the peergroup compensation market analysis. The compensation committee considers this information when establishing the total compensation package of theexecutive officers. The Chief Executive Officer’s performance and compensation is reviewed, evaluated and established separately by the compensationcommittee based on criteria similar to those used for non-CEO executive compensation.Prior to the appointment of our current Chief Executive Officer during Fiscal 2013, our former Chief Executive Officer had a similar role in the compensationsetting process.74Table of ContentsMarket AnalysisIn connection with the sale of our general partner as part of the Inergy/Crestwood Transaction, we retained Pearl Meyer & Partners (“PM&P”) as acompensation consultant to do a market analysis of the executive compensation of the combined partnership.PM&P collected market data from two primary data sources:•Peer group 10-K data for a group of 18 midstream master limited partnerships (“MLPs”) (14 from Crestwood’s compensation peer group, plus fouradditional MLPs selected in order to arrive at median enterprise value for the group closer to the $7.5 billion expected for the combined partnership).•Survey data for midstream oil and gas, broader energy, and general industry companies with revenues of around $2 billion (roughly the same ascombined gross revenues for Legacy Crestwood and Legacy Inergy pre-merger).In order to limit the impact of outliers, PM&P’s focus was on the “middle range” from 25th to 75th percentile (or the range of the market into which 50 percentof the data points fall). After developing market rates for each position, PM&P developed a model of the implications of moving each executive into thecombined partnership positions, assuming that (i) there will be no reduction in current base salaries; and (ii) the combined partnership will target the midpointbetween the 50th and 75th percentiles of the market data, PM&P’s approach was consistent with the approach taken for Legacy Crestwood’s cashcompensation for 2013 for executives. The model also incorporated some “smoothing” of incentive targets and salaries by executive “tier” such that executivesat a similar rate of pay in the market data have similar incentive targets.Elements of CompensationThe principal elements of compensation for the named executive officers are the following:•base salary;•incentive awards;•long-term incentive plan awards; and•retirement and health benefits.Base SalaryBase salary is designed to compensate executives commensurate with the level of the position they hold and for sustained individual performance (includingexperience, scope of responsibility, results achieved and future potential).We historically have not made annual adjustments to the salaries of our named executive officers. The salaries of our named executive officers were reviewedon an annual basis as well as at the time of promotion, or when entering into or renewing an employment agreement and may adjust salaries due to changes inresponsibilities or market conditions. In determining the amount of any adjustments, the compensation committee used market data as a tool for assessing thereasonableness of the base salary amounts of the named executive officers as compared to the compensation of executives in similar positions with similarresponsibility levels in our industry and in our region. However, the final determination of base salary amounts was within the compensation committee’ssubjective discretion.Going forward, with the assistance of our compensation consultant, we will conduct an annual review of compensation practices and payouts deemed to bemarket-based and competitive for the midstream industry. Base salary, annual cash bonus plan targets based on key performance indicators (“KPIs”) andannual equity grants will be approved by the compensation committee each year based upon 10-K data for members of our peer group and survey data for themidstream oil and gas, broader energy, and general industry companies within the same revenue targets.Base Salary during Fiscal 2013Consistent with our historic policy of not making any systematic or annual adjustments to base salary, there were no broad based changes to the annual basesalaries of our named executive officers during Fiscal 2013. As a result, during Fiscal 2013 base salaries of each of John Sherman, William C. Gautreaux,Laura L. Ozenberger and Phillip Elbert remained $400,000, $250,000, $250,000, and $300,000 respectively.75Table of ContentsThe compensation committee determined that the base salaries for R. Brooks Sherman, Jr. and Michael J. Campbell should be increased to $365,000 (effectiveNovember 1, 2012) and $250,000 (effective October 1, 2012), respectively. We believe the increases were warranted based on (i) the increased responsibilitiesof these executives in their new roles as President (R. Brooks Sherman, Jr.) and Chief Financial Officer (Michael J. Campbell) and (ii) comparablecompensation of executives in similar positions with similar responsibility levels in our industry and our region.The initial base salary for Robert G. Phillips was established at the time of his appointment as President and Chief Executive Officer which coincided with thesale of control of our general partner on June 19, 2013. Mr. Phillips’ initial base salary of $655,000 (effective April 29, 2013) was based upon his existingcompensation with Legacy Crestwood. Mr. Moxley’s initial base salary of $435,000 was also based on his upon his existing compensation with LegacyCrestwood.Base Salary during the Transition PeriodThe base salaries for Joel C. Lambert and J. Heath Deneke were established at $360,000 and $435,000, respectively based upon individual negotiation withRobert G. Phillips and compensation expertise from PM&P in connection with their appointment as our Senior Vice President and General Counsel andPresident - Natural Gas Business Unit, respectively, on October 7, 2013 in connection with the closing of the Inergy/Crestwood Transaction. Effective October7, 2013, the base salary of Michael J. Campbell was increased to $400,000 to align his executive compensation to market rates for the new leadership teamroles.Base Salary for 2014During January 2014, each of our named executive officers who remained employed by us entered into new employment agreements with our subsidiary,Crestwood Operations LLC (the “2014 Employment Agreements”). The 2014 Employment Agreements, among other things, established the following basesalary levels for 2014:Named Executive Officer 2014 Base SalaryRobert G. Phillips $655,000Michael J. Campbell $400,000Joel D. Moxley $435,000Joel C. Lambert $360,000J. Heath Deneke $435,000For a more detailed description of the 2014 Employment Agreements, see “Narrative Disclosure to Summary Compensation and Grants of Plan Based AwardsTables-2014 Employment Agreements”.Annual Incentive AwardsIncentive awards are designed to reward the performance of key employees, including the named executive officers, by providing annual incentiveopportunities for the partnership’s achievement of its annual financial performance goals. In particular, these bonus awards are provided to the namedexecutive officers in order to provide competitive incentives to these executives who can significantly impact performance and promote achievement of ourshort-term business objectives.Annual Incentive Awards during Fiscal 2013Under the terms of their respective employment agreements in effect during Fiscal 2013, certain of our named executive officers (including John J. Sherman, R.Brooks Sherman, Michael J. Campbell, William C. Gautreaux, Laura L. Ozenberger and Phillip L. Elbert) were eligible, upon the achievement of certainsubjective and objective criteria, to receive a cash incentive award in amount up to 100% of the named executive officer’s base salary.The sole metric used to determine whether bonuses would be paid to the named executive officers for Fiscal 2013 was our achievement of the target of earningsbefore income taxes, plus net interest expense, depreciation and amortization expense, further adjusted to exclude the gain or loss on the disposal of assets,long-term incentive and equity compensation expenses and transaction costs (“Adjusted EBITDA”). We selected this metric because we believe it closely alignsthe focus of our named executive officers with the increase in unitholder value. In addition, this target was communicated to our unitholders and analysts asguidance at the beginning of the Fiscal 2013.76Table of ContentsHowever, following completion of the Inergy/Crestwood Transaction, our Chief Executive Officer determined that the prior performance goals relating toAdjusted EBITDA would not apply for Fiscal 2013 due to the Inergy/Crestwood Transaction, and that in lieu of the bonuses based upon Adjusted EBITDAdescribed above, bonuses would be paid with respect to Fiscal 2013 for each of our named executive officers employed as of the end of the fiscal year otherthan our current Chief Executive Officer. Accordingly, our named executive officers received the following bonuses with respect to Fiscal 2013:Named Executive Officer FY 2013 BonusMichael J. Campbell $400,000William C. Gautreaux $391,500Laura L. Ozenberger $250,000Michael D. Lenox $200,000Annual Incentive Awards during 2014For 2014, annual incentive targets were established for each of our named executive officers who remained employed by us pursuant to the 2014 EmploymentAgreements. The 2014 Employment Agreements establish the following cash incentive targets for such named executive officers:Named Executive Officer 2014 Target Bonus (% of Base Salary)Robert G. Phillips 100%Michael J. Campbell 100%Joel D. Moxley 85%Joel C. Lambert 75%J. Heath Deneke 90%For a more detailed description of the 2014 Employment Agreements, see “Narrative Disclosure to Summary Compensation and Grants of Plan Based AwardsTables-2014 Employment Agreements.”Actual bonuses for 2014 will be determined based on our achievement of certain KPI targets (Adjusted EBITDA, operational and administrative costs, andsafety) which have been approved by our compensation committee. Actual results between the minimum and maximum target thresholds would be pro-ratedbased on the percentage of target reached. Actual results above the maximum threshold would be capped at 125%, results below the minimum threshold wouldresult in 0% achievement for that KPI.Long-Term Incentive Plan AwardsLong-term incentive awards for the named executive officers are granted under the Crestwood Equity Partners LP Long Term Incentive Plan (formerly theInergy Long Term Incentive Plan) and the Crestwood Midstream Partners LP Long Term Incentive Plan (formerly the Inergy Midstream, L.P. Long TermIncentive Plan) in order to promote achievement of our primary long-term strategic business objective of increasing distributable cash flow and increasingunitholder value. These plans are designed to align the economic interests of key employees and directors with those of our common unitholders and thecommon unitholders of Crestwood Midstream Partners LP and to provide an incentive to management for continuous employment with the general partner andits affiliates. Long-term incentive compensation is based upon the common units representing limited partnership interests in us and in Crestwood MidstreamPartners LP. Recently our awards have consisted solely of grants of restricted common units which vest either based upon continued service or performanceconditions. Restricted units are designed to furnish additional compensation to employees and directors and to align their economic interests with those ofcommon unitholders.77Table of ContentsLong-Term Incentive Awards during Fiscal 2013On November 28, 2012, our compensation committee approved grants of restricted units under the Crestwood Equity Partners LP Long Term Incentive Plan(formerly the Inergy Long Term Incentive Plan) to the named executive officers as follows:Employee UnitsR. Brooks Sherman, Jr. 25,000Laura L. Ozenberger 12,500William C. Gautreaux 15,000Michael J. Campbell 10,000The awards were scheduled to vest in one-third annual increments beginning on the first anniversary of the grant date and were awarded based on suchemployees extraordinary efforts in fiscal 2012. Additionally, in connection with his appointment as Senior Vice President and Chief Financial Officer, MichaelJ. Campbell was awarded 30,000 restricted units under the Crestwood Equity Partners LP Long Term Incentive Plan (formerly the Inergy Long Term IncentivePlan), which were scheduled to vest 25%, 25%, and 50% on the third, fourth and fifth anniversaries of the grant date.In connection with the Inergy/Crestwood Transaction, the award agreements evidencing all restricted common units granted to our named executive officersunder the Crestwood Equity Partners LP Long Term Incentive Plan (formerly the Inergy Long Term Incentive Plan) and the Crestwood Midstream Partners LPLong Term Incentive Plan (formerly the Inergy Midstream, L.P. Long Term Incentive Plan) (in each case, other than those restricted units held by non-employeedirectors) that were outstanding at the time of the transaction were amended, such that each such restricted common unit held would vest upon the earlier tooccur of the vesting date set forth in the applicable original award agreement or on December 31, 2013 (or, in the case of Mr. Gautreaux, June 19, 2014). Inaddition, such restricted common units were amended to be subject to earlier vesting upon termination of a named executive officer’s employment by his or heremployer other than for “cause” or resignation by the named executive officer following the occurrence of a “constructive termination event.” Accordingly, allrestricted units held by our named executive officers during Fiscal 2013 (other than Mr. Gautreaux) vested on or before December 31, 2013.Long-Term Incentive Awards during Transition PeriodIn connection with his appointment as our Senior Vice President and General Counsel, Joel C. Lambert received a grant of 18,634 restricted units of CrestwoodEquity Partners LP, which time-vest in equal annual installments over a three-year period following the date of grant. No other long-term incentive awards weregranted to the named executive officers during the Transition Period.Long-Term Incentive Awards for 2014For 2014 and beyond, equity incentive targets were established for each of our named executive officers who remained employed by us pursuant to the 2014Employment Agreements. The 2014 Employment Agreements establish the following equity incentive targets for such named executive officers:Named Executive Officer Target Equity Compensation Grant (% of BaseSalary) (1)Robert G. Phillips 250% (2)Michael J. Campbell 150%Joel D. Moxley 110%(2)Joel C. Lambert 150%(2)J. Heath Deneke 175%(2)(1)Includes both awards with respect to Crestwood Equity Partners LP and Crestwood Midstream Partners LP.(2)The level of equity compensation to be awarded to Mr. Phillips, Mr. Moxley, Mr. Lambert and Mr. Deneke will be reduced one-third in 2014 and two-thirds in 2015 from the targetgrants set forth above to reflect their prior awards of incentive units in Crestwood Holdings Partners LLC.In February 2014, in connection with its review of the performance of our chief executive officer, the board approved a one-time, discretionary award of $3.1million in equity to be allocated equally between CEQP and CMLP restricted units based on the closing price of CEQP and CMLP common units on the grantdate. The awards will vest ratably over a three-year period beginning one year from the grant date. The equity award was granted in recognition of our chiefexecutive officer’s significant role and leadership in consummating the Inergy/Crestwood Transaction and post-transaction integration efforts. The size of the78Table of Contentsaward was determined in the board’s sole discretion in light of the significance of the transaction and was not based on any objective criteria.For a more detailed description of the 2014 Employment Agreements, see “Narrative Disclosure to Summary Compensation and Grant of Plan-Based AwardsTables-2014 Employment Agreements”.Risk Assessment Related to our Compensation Structure.We believe that the compensation plans and programs for our executive officers, as well as other employees, are appropriately structured and are notreasonably likely to result in a material risk. We believe these compensation plans and programs are structured in a manner that does not promote excessiverisk-taking that could reward poor judgment. We also believe that we have allocated compensation among base salary and short and long-term compensation insuch a way as to not encourage excessive risk-taking. In particular, we generally do not adjust base annual salaries for executive officers and other employeessignificantly from year to year, and therefore the annual base salary of our employees is not generally impacted by our overall financial performance or thefinancial performance of an operating segment.Severance and Change of Control BenefitsSeverance and Change of Control Benefits during Fiscal 2013 and the Transition PeriodDuring Fiscal 2013 and the Transition Period, we maintained employment agreements with all our named executive officers (other than our current ChiefExecutive Officer, our current Senior Vice President and General Counsel, our current Senior Vice President - Operations Services, our current President-Natural Gas, and our former Chief Accounting Officer) to ensure they performed their roles for an extended period of time and not compete with us upontermination of employment. These agreements are described in more detail elsewhere in this annual report. Please read “Narrative Disclosure to SummaryCompensation Table and Grants of Plan-Based Awards Table - Employment Agreements.” These agreements did not provide any form of severance paymentupon a change in control. However, the agreements did provide for continued salary payments following termination of employment without cause (as definedin the employment agreements).In connection with the Inergy/Crestwood Transaction, our general partner adopted the Inergy Group Officer Severance Plan (the “Officer Severance Plan”),which entitles each of our named executive officers (other than our current Chief Executive Officer, our current Senior Vice President and General Counsel, ourcurrent Senior Vice President - Operations Services, and our current President-Natural Gas) to receive severance payments and benefits if his or heremployment is terminated by other than for “cause” or he or she resigned due to the occurrence of a “constructive termination event” (which has a substantiallysimilar definition as under the amended restricted unit agreements, described above), in each case, during the 18-month period following the completion of theacquisition of Inergy, L.P.’s general partner. Upon such a qualifying termination, subject to such individual’s execution, delivery and non-revocation, to theextent applicable, of a release of claims, each named executive officer would be entitled to receive an amount equal to two or three times the sum of his or herannual base salary and annual bonus opportunity, as well as continued participation in medical and dental plans at no cost to such executive for a one or twoyear period following the date of termination. The severance payments and benefits payable pursuant to the Officer Severance Plan will not be duplicative ofany amounts that may become payable upon such termination under any existing employment agreement.In connection with the Inergy/Crestwood Transaction, the employment of each of John J. Sherman, Phillip L. Elbert, R. Brooks Sherman, Laura L.Ozenberger was terminated without “cause” and, accordingly, each such individual received severance payments and benefits pursuant to the OfficerSeverance Plan. Additionally, effective October 8, 2013, Michael D. Lenox was constructively terminated and, accordingly, he also received severancepayments and benefits pursuant to the Officer Severance Plan.Severance and Change of Control Benefits during 2014As described above, in January 2014 we entered into a new employment agreement with each named executive officer who remained employed by us at suchtime. The 2014 Employment Agreements replaced any existing employment agreement and supersede the named executive officer’s participation in the OfficerSeverance Plan. For a more detailed description of the severance provided for pursuant to the 2014 Employment Agreements, see “Narrative Disclosure toSummary Compensation and Grants of Plan Based Awards Tables”.79Table of ContentsOther Compensation Related Matters (applicable to both Fiscal 2013 and the Transition Period)Retirement and Health BenefitsWe offer a variety of health and welfare and retirement programs to all eligible employees. The named executive officers are eligible for the same programs onthe same basis as other employees. We maintain a 401(k) retirement plan that provides eligible employees with an opportunity to save for retirement on a taxadvantaged basis. We historically matched 50% of the first 6% of the deferral to the retirement plan (not to exceed the maximum amount permitted by law)made by eligible participants. Beginning January 1, 2014, we match 6% of the deferral to the retirement plan (not to exceed the maximum amount permitted bylaw) made by eligible participants. Our executive officers are also eligible to participate in additional employee benefits available to our other employees.Perquisites and Other CompensationWe do not provide perquisites or other personal benefits to any of the named executive officers.Tax Deductibility of CompensationWith respect to the deduction limitations under Section 162(m) of the Code, we are a limited partnership and do not meet the definition of a “corporation”under Section 162(m). Thus the compensation that we pay to our employees is not subject to the deduction limitations under Section 162(m) of the Code.Compensation Committee ReportWe have reviewed and discussed the foregoing Compensation Discussion and Analysis with management. Based on our review and discussion withmanagement, we have recommended that the Compensation Discussion and Analysis be included in this Annual Report on Form 10-K for the year endedSeptember 30, 2013 and the Transition Period.David WoodWarren GfellerMembers of the Compensation Committee80Table of ContentsSummary Compensation Table for Fiscal 2013The following table sets forth the cash and non-cash compensation earned for the fiscal years ended September 30, 2013, September 30, 2012 and September30, 2011 for each of our named executive officers during Fiscal 2013.Name and Principal Position FiscalYear Salary($) Bonus($) UnitAwards($)(5) Non-EquityIncentive PlanCompensation ($) All OtherCompensation ($)(6) Total($) Robert G. Phillips(1)President, Chief ExecutiveOfficer and Director 2013 176,347 347,550(7) — — — 523,897John. J. Sherman(2)Former Chief ExecutiveOfficer 2013 304,615 — — — 1,942,445 2,247,060 2012 400,000 — — — 11,692 411,692 2011 393,653 — — — 11,319 404,972Michael J. CampbellSenior Vice President-Chief Financial Officer 2013 247,115 400,000 789,300 — 6,548 1,442,963 2012 175,000 200,000 434,000 — 6,750 815,750William C. GautreauxPresident, Inergy Services 2013 250,000 391,500 280,800 — 6,538 928,838 2012 235,577 300,000 651,000 — 6,356 1,192,933Laura L. Ozenberger(3)Former Senior VicePresident and GeneralCounsel 2013 250,000 250,000 234,000 — 1,423,481 2,157,481 2012 250,000 250,000 868,000 — 7,789 1,375,789 2011 235,385 — 3,264,800 — 7,842 3,508,027Michael D. Lenox(3)(4)Former ChiefAccounting Officer 2013 199,039 200,000 365,900 — 4,385 769,324R. Brooks Sherman(2)Former President 2013 267,962 — 468,000 — 2,112,391 2,848,353 2012 278,365 500,000 1,085,000 — 7,736 1,871,101 2011 225,000 — — — 6,516 231,516Phillip L. Elbert(2)Former Executive VicePresident - Strategy 2013 228,462 — — — 1,804,569 2,033,031 2012 292,300 — — — 11,712 304,012 2011 275,000 — — — 14,310 289,310(1)Robert G. Phillips was appointed as our President and Chief Executive Officer in June 2013. Amounts shown in the table do not reflect compensation paid by predecessorCrestwood Midstream Partners LP prior to Mr. Phillips’ appointment as our President and Chief Executive Officer.(2)The employment of John J. Sherman, Laura L. Ozenberger, R. Brooks Sherman and Phillip L. Elbert as executive officers terminated in during Fiscal 2013 (or, in the case ofMs. Ozenberger, upon completion of Fiscal 2013). Amounts payable in respect of such terminations are reflected in the column entitled “All Other Compensation”.(3)Michael D. Lenox was constructively terminated on October 8, 2013. Amounts payable in respect of Mr. Lenox’s termination are reflected in the column entitled “All OtherCompensation” in the Summary Compensation Table for the Transition Period.(4)Mr. Lenox was not a named executive officer in our Annual Reports on Form 10-K for Fiscal 2011 and 2012. Therefore, this table does not provide 2011 and 2012 data for him.(5) The material terms of our outstanding LTIP awards to our executive officers are described in “Compensation Discussion and Analysis - Long-Term Incentive Plan Awards.” Unitaward amounts reflect the aggregate grant date fair value of unit awards granted during the periods presented calculated in accordance with Accounting Standards Codification718, disregarding forfeitures. See Part IV, Item 15, Exhibits and Financial Statement Schedules, Note 12 for a discussion of the assumptions used to determine the FASBASC Topic 718 value of the awards. As described in the “Compensation Discussion and Analysis”, in connection with the Inergy/Crestwood Transaction, the vestingschedule of these awards was modified such that they would vest upon the earlier to occur of December 31, 2013 or upon certain terminations of employment81Table of Contents(6) “All Other Compensation” for Fiscal Year 2013 consisted of the following: Unit Purchase PlanEmployer Match 401(k) MatchingContributions Severance Benefits TotalRobert G. Phillips — — — —John. J. Sherman 2,000 4,692 1,935,753 1,942,445Michael J. Campbell — 6,548 — 6,548William C. Gautreaux 2,500 4,038 — 6,538Laura L. Ozenberger 1,250 4,423 1,417,808 1,423,481Michael D. Lenox — 4,385 — 4,385R. Brooks Sherman — 5,391 2,107,000 2,112,391Phillip L. Elbert — 4,569 1,800,000 1,804,569(7) Mr. Phillips received a $655,000 bonus payment in January 2014 pursuant to a Legacy Crestwood incentive plan. The amount reflected in the table above represents the pro-rata portion of the bonus in Fiscal 2013. The remaining portion of the bonus appears in the summary compensation table for the Transition Period below.Summary Compensation Table for Transition PeriodThe following table sets forth the cash and non-cash compensation earned for each of our named executive officers for the Transition Period commencing onOctober 1, 2013 and ending on December 31, 2013. As described above, John J. Sherman, R. Brooks Sherman and Laura L. Ozenberger terminatedemployment prior to the commencement of the Transition Period, and as such did not receive any compensation with respect to the Transition Period.Name and Principal Position FiscalYear Salary($) Bonus($)(5) UnitAwards($) Non-Equity IncentivePlan Compensation($) All OtherCompensation ($)(4) Total($) Robert G. PhillipsPresident, Chief ExecutiveOfficer and Director 10/1/13-12/31/13 176,347 307,450 — — — 483,797Michael J. CampbellSenior Vice President-Chief Financial Officer 10/1/13-12/31/13 96,154 — — — 1,119 97,273Joel C. Lambert(1)Senior Vice President-andGeneral Counsel 10/1/13-12/31/13 83,077 360,000 257,149(3) — 2,769 702,995Joel D. MoxleyPresident, Liquids andCrude Business Unit 10/1/13-12/31/13 108,750 369,750 — — — 478,500J. Heath Deneke President, Natural GasBusiness Unit 10/1/13-12/31/13 116,442 391,500 — — 1,339 509,281Michael D. Lenox(2)Former Chief AccountingOfficer 10/1/13-12/31/13 53,846 — — — 800,000 853,846(1)Joel C. Lambert was appointed as our Senior Vice President and General Counsel on October 1, 2013(2)The employment of Michael D. Lenox as executive officers terminated during the Transition Period. Amounts payable in respect of Mr. Lenox’s terminations are reflected in thecolumn entitled “All Other Compensation”.(3)The material terms of our outstanding LTIP awards to our executive officers are described in “Compensation Discussion and Analysis - Long-Term Incentive Plan Awards.”Unit award amounts reflect the aggregate grant date fair value of unit awards granted during the periods presented calculated in accordance with Accounting StandardsCodification 718, disregarding forfeitures. See Part IV, Item 15, Exhibits and Financial Statement Schedules, Note 12 for a discussion of the assumptions used to determinethe FASB ASC Topic 718 value of the awards.(4)Consists of employer matching contributions to our 401(k) plan and unit purchase plans and, in the case of Mr. Lenox, includes severance benefits in the amount of$800,000.(5)Represents bonus amounts paid in January 2014 pursuant to a Legacy Crestwood incentive compensation plan for the Legacy Crestwood full fiscal year. Mr. Phillips receiveda $655,000 bonus payment in January 2014 pursuant to a Legacy Crestwood incentive plan. The amount reflected in the table above represents the pro-rata portion of thebonus in the Transition Period. The remaining portion of the bonus appears in the summary compensation table for the Fiscal Year above.82Table of ContentsGrants of Plan-Based Awards Table for Fiscal 2013The following table provides information concerning each grant of an award made to our named executive officers during Fiscal 2013, including awards thathave been transferred. Estimated Future Payouts Under Non-EquityIncentive Plan Awards Name Grant Date Threshold ($) Target ($) Maximum($)(1) All Other UnitAwards(#)(2) Grant Date FairValue of Unit andOption Awards ($)Robert G. Phillips — — — — — —John. J. Sherman — — 400,000 400,000 — —Michael J. Campbell 11/5/2012 — — — 30,000 602,100 11/28/2012 — — — 10,000 187,200 — 400,000 400,000 — —William C. Gautreaux 11/28/12 — — — 15,000 280,800 — 391,500 391,500 — —Laura L. Ozenberger 11/28/12 — — — 12,500-- 234,000-- — 250,000 250,000 — —Michael D. Lenox 11/28/2012 — — — 10,000 187,200 12/10/2012 — — — 10,000 178,700 — 200,000 200,000 — —R. Brooks Sherman 11/28/12 — 365,000 365,000 25,000 468,000Phillip L. Elbert — 300,000 300,000 — —(1)The amounts in these columns reflect the “Target” and “Maximum” bonus award amounts for our named executive officers with respect to cash bonuses awarded pursuant tosuch named executive officer’s employment agreement in effect during Fiscal 2013. The “Maximum” amount may be increased by the discretion of the Compensation Committee asdescribed above in the “Compensation Discussion and Analysis -Incentive Awards.”(2)Amounts in this column reflect grants of restricted common units of Crestwood Equity Partners LP (known as Inergy, L.P. at the time of grant). The November 28, 2012 awardswere scheduled to vest ratably over a three year period beginning on the first anniversary of the grant. The November 5, 2012 grant and the December 10, 2012 grant werescheduled to vest 25%, 25%, 50% on the third, fourth and fifth anniversaries of the grant date. The material terms of our Fiscal 2013 restricted unit awards to our namedexecutive officers are described in the narrative disclosure following the “Grants of Plan-Based Awards” table.Grants of Plan-Based Awards Table for Transition PeriodThe following table provides information concerning each grant of an award made to each of our named executive officers during the Transition Periodcommencing on October 1, 2013 and ending on December 31, 2013Name All Other Stock Awards(#) Grant Date Fair Value ofStock and Option Awards($)Robert G. Phillips — —Michael J. Campbell — —Joel C. Lambert 18,634(1) 257,149William C. Gautreaux — —J. Heath Deneke — —Michael D. Lenox — —(1)Reflects an initial grant of restricted common units of Crestwood Equity Partners LP granted to Joel C. Lambert on October 1, 2013 in connection with his commencement ofemployment. These restricted units vest in equal annual installments over the first three years of grant.83Table of ContentsNarrative Disclosure to Summary Compensation Table and Grants of Plan-Based Awards TableA discussion of Fiscal 2013 and Transition Period salaries, bonuses and equity compensation is included above in “Compensation Discussion andAnalysis.” The following is a discussion of other material factors necessary to an understanding of the information disclosed in the Summary CompensationTable.Employment Agreements in Effect during Fiscal 2013 and Transition Period During Fiscal 2013 and the Transition Period the following named executive officers were party to employment agreements with us or one of our subsidiaries: •John J. Sherman, our former Chief Executive Officer;•Michael J. Campbell, our Senior Vice President - Chief Financial Officer;•William C. Gautreaux, our President, Liquids and Crude Business Unit;•R. Brooks Sherman, Jr., our former President;•Phillip L. Elbert, our former Executive Vice President - Strategy and•Laura L. Ozenberger, our former Senior Vice President - General Counsel and Secretary.The following is a summary of the material provisions of these employment agreements, each of which is incorporated by reference herein as an exhibit to thisreport.The employment agreements established the named executive officers base salary (subject to adjustment) and generally provide for the individual to be eligiblefor non-equity incentive compensation bonuses upon meeting certain established criteria for each year during the term of his or her employment. Generally, unless waived by the general partner, in order for any of these individuals to receive any benefits under (i) the Inergy Long Term Incentive Plan,Inergy Midstream Long Term Incentive Plan, or (ii) the non-equity incentive compensation bonus, the individual must have been continuously employed bythe general partner or one of our affiliates from the date of his or her employment agreement up to the date for determining eligibility to receive such amounts. Each employment agreement contains confidentiality and noncompetition provisions. Also, each employment agreement contained a disclosure and assignmentof inventions clause that requires the employee to disclose the existence of any invention and assign such employee’s right in such invention to the generalpartner.With respect to each of the named executive officers party to an employment agreement during , in the event such person’s employment is terminated withoutcause, we would have been required to make salary continuation payments equal to the aggregate amount of salary that would have been payable over the termof the agreement. The severance provisions in the employment agreements were generally superseded by the amounts payable under the Officer Severance Plan. Each of these employment agreements that was still in effect as of January 2014 was replaced by new employment agreements entered into between CrestwoodOperations LLC and the named executive officers.Officer Severance PlanDuring Fiscal 2013 and the Transition Period, each of our named executive officers other than Robert G. Phillips, Joel D. Moxley, Joel C. Lambert and J. HeathDeneke participated in the Inergy Group Officer Severance Plan, which is described in the “Compensation Discussion and Analysis”. In connection with theInergy/Crestwood Transaction, the employment of each of John J. Sherman, Phillip L. Elbert, R. Brooks Sherman, and Laura L. Ozenberger was terminatedwithout “cause” and Michael D. Lenox was constructively terminated and, accordingly, each such individual received severance payments and benefitspursuant to the Officer Severance Plan. These amounts are reflected in the applicable Summary Compensation Table for the respective period in which theapplicable termination took place.Employment Agreements Entered into During Fiscal 2014During January 2014, Crestwood Operations, LLC entered into new employment agreements (the “Employment Agreements”) with each of our named executiveofficers who remained employed by us at such time. The Employment Agreements each have an initial term ending December 31, 2015 and will renewautomatically for additional one-year periods thereafter if neither party gives advance notice of non-renewal. The Employment Agreements replace any currentemployment agreement,84Table of Contentsrights under the Officer Severance Plan and provide for the base salary, target bonus amounts and target 2014 equity compensation grant described in our“Compensation Discussion and Analysis”.Under the terms of the 2014 Employment Agreements, if the named executive officer’s employment is terminated during the initial term or a subsequent one-year renewal by Crestwood Operations without “employer cause” or the executive resigns due to “employee cause” or the named executive officer’s employmentwith Crestwood Operations terminates as a result of Crestwood Operations’ election not to renew the 2014 Employment Agreement, the executive will be entitledto receive, subject to the executive’s execution of a release of claims, severance equal to two (or, in the case of Mr. Phillips, three) times the sum of theexecutive’s base salary and average annual bonus for the prior two years, payable in equal installments over an 18-month period following termination. Inaddition, the executive would be entitled to certain subsidized medical benefits over such 18-month period.The foregoing summary of the material provisions of the 2014 Employment Agreements is intended to be general in nature and is qualified by the full text ofthe 2014 Employment Agreements, each of which is incorporated by reference herein as an exhibit to this report.Outstanding Equity Awards at 2013 Fiscal Year-EndThe following table summarizes the options and restricted units outstanding as of the end of Fiscal 2013, for the named executive officers during Fiscal 2013.The table includes unit options and restricted units of Crestwood Equity Partners LP (NYSE: CEQP) granted under the Inergy Long Term Incentive Plan andrestricted units of Crestwood Midstream Partners L.P. (NYSE: CMLP) granted under the Inergy Midstream, L.P. Long Term Incentive Plan. OPTION AWARDS UNIT AWARDSName Number ofSecuritiesUnderlyingUnexercised Options(#)Exercisable Number of SecuritiesUnderlyingUnexercised Options(#)Unexercisable Option ExercisePrice($) Option ExpirationDate Number of Units ThatHave Not Vested (#)(1) Market Value of UnitsThat Have Not Vested($)(2)Robert G. Phillips — — — — — —John. J. Sherman — — — — — —Michael J. Campbell — — — — CEQP 67,325CMLP 20,000 927,065441,600William C. Gautreaux — — — — CEQP 115,000CMLP 30,000 1,583,550662,400Laura L. Ozenberger — — — — — —Michael D. Lenox 11,550 — $3.39 4/1/18 CEQP 36,750CMLP 20,000 506,048441,600R. Brooks Sherman(3) — — Phillip L. Elbert(3) (1)As described above in the “Compensation Discussion & Analysis”, all restricted unit awards reflected in the table above were modified such that they vested no later thanDecember 31, 2013.(2)Market value for CEQP units based on the NYSE closing price of $13.77 on September 30, 2013 and market value for CMLP units based on the NYSE closing price of $22.08on September 30, 2013.(3)All restricted units previously held by R Brooks Sherman, Phillip L. Elbert and Laura L. Ozenberger vested upon their termination of employment and thus they held no equityawards as of September 30, 2013.85Table of ContentsOutstanding Equity Awards at the End of the Transition PeriodThe following table summarizes the options and restricted units outstanding as of the end of the Transition Period, for the named executive officers during theTransition Period. The table includes unit options and restricted units of Crestwood Equity Partners LP (NYSE: CEQP) granted under the Inergy Long TermIncentive Plan and restricted units of Crestwood Midstream Partners LP (NYSE: CMLP) granted under the Inergy Midstream, L.P. Long Term Incentive Plan. OPTION AWARDS UNIT AWARDSName Number ofSecuritiesUnderlyingUnexercisedOptions (#)Exercisable Number of SecuritiesUnderlying UnexercisedOptions (#)Unexercisable Option ExercisePrice($) Option ExpirationDate Number of Units ThatHave Not Vested (#)(1) Market Value ofUnits That HaveNot Vested ($)(2)Robert G. Phillips — — — — — —Michael J. Campbell — — — — — —Joel C. Lambert — — — — CEQP 18,634 257,708Joel D. Moxley — — — — — —J. Heath Deneke — — — — — —Michael D. Lenox 11,550 — $3.39 4/1/18 — —(1) As described above in the “Compensation Discussion & Analysis”, all restricted unit awards outstanding as of the completion of the Inergy/Crestwood Transaction were modified suchthat they vested no later than December 31, 2013 (or, in the case of awards held by Mr. Gautreaux, June 19, 2014). Thus, other than with respect to certain restricted units heldby Mr. Gautreaux and certain restricted units granted to Mr. Lambert following the completion of the Inergy/Crestwood Transaction, no units held by our named executive officersremained unvested as of December 31, 2013.(2) The market value for CEQP units is based on the NYSE closing price of $13.83 on December 31, 2013 and the market value for CMLP units is based on the NYSE closing price of$24.89 on December 31, 2013.Option Exercises and Units Vested During Fiscal 2013The following table provides information regarding option exercises and restricted unit vesting during Fiscal 2013, for the named executive officers. Valuerealized on exercise or upon vesting was calculated by using the closing price of Crestwood Equity Partners LP (or, prior to the completion of theInergy/Crestwood Transaction, Inergy, L.P.) and Crestwood Midstream Partners LP (or, prior to the completion of the Inergy/Crestwood Transaction, InergyMidstream, L.P.) on the date that the award was exercised or was vested, as applicable. OPTION AWARDS UNIT AWARDSName Number of UnitsAcquired OnExercise (#) Value Realizedon Exercise ($) Number of Units AcquiredOn Vesting (#) Total Value Realized onVesting ($)Robert G. Phillips — — — —John. J. Sherman — — — —Michael J. Campbell — — CEQP 3,000 60,870William C. Gautreaux — — CEQP 28,875 577,500Laura L. Ozenberger 36,358 478,064 CEQP 121,375CMLP 40,000 2,839,241Michael D. Lenox — — CEQP 750 14,970R. Brooks Sherman — — CEQP 247,475CMLP 50,000 5,109,496Phillip L. Elbert — — CEQP 289,450 4,716,97886Table of ContentsOption Exercises and Units Vested During Transition PeriodThe following table provides information regarding restricted unit vesting during the Transition Period, for the named executive officers. Value realized onupon vesting was calculated by using the closing price of Crestwood Equity Partners LP and Crestwood Midstream Partners LP on the date that the award wasexercised or was vested, as applicable. No named executive officer exercised options during the Transition Period. UNIT AWARDSName Number of UnitsAcquired On Vesting(#) Value Realized on Vesting($)Robert G. Phillips — —Michael J. Campbell CEQP 67,325CMLP 20,000 1,423,119Joel C. Lambert — —Joel D. Moxley — —J. Heath Deneke — —Michael D. Lenox CEQP 36,750CMLP 20,000 964,660Pension Benefits during Fiscal 2013 and the Transition PeriodWe do not offer any pension benefits.Non-qualified Deferred Compensation during Fiscal 2013 and the Transition PeriodWe have no non-qualified deferred compensation plans.Potential Payments upon a Change in Control or Termination during Fiscal 2013 and the Transition PeriodDuring Fiscal 2013 and the Transition Period, each of our named executive officers other than our current Chief Executive Officer, our current Senior VicePresident and General Counsel, our current Senior Vice President - Operations Services and our current Senior Vice President - Natural Gas Business Unitwas a participant in the Officer Severance Plan, which provides upon which each of our named executive officers would become entitled to receive severancepayments and benefits if his or her employment was terminated by other than for “cause” or he or she resigned due to the occurrence of a “constructivetermination event”, in each case, during the 18 month period following the completion of the acquisition of Inergy L.P’s general partner. The Officer SeverancePlan provided for severance in lieu of what otherwise would have been payable upon termination without “cause” under the named executive officer’s respectiveemployment agreement.Upon such a qualifying termination, subject to such individual’s execution, delivery and non-revocation, to the extent applicable, of a release of claims, eachnamed executive officer would be entitled to receive an amount equal to two or three times the sum of his or her annual base salary and annual bonusopportunity, as well as continued participation in medical and dental plans at no cost to such executive for a one or two year period following the date oftermination. The severance payments and benefits payable pursuant to the Officer Severance Plan will not be duplicative of any amounts that may becomepayable upon such termination under any existing employment agreement.In addition, upon a change of control or a termination of the named executive officer’s employment without “cause” or due to resignation upon a “constructivetermination”, pursuant to the terms of the amended restricted unit agreements with our named executive officers during Fiscal 2013 (other than our currentChief Executive Officer), all restricted units in Crestwood Equity Partners LP and Crestwood Midstream Partners LP would vest in full.87Table of ContentsPayments upon Change of Control and/or Termination on the Last Day of Fiscal 2013The following table presents information about the gross payments paid or potentially payable to our named executive officers pursuant to the OfficerSeverance Plan or restricted unit agreements, assuming each such named executive officer experienced a qualifying termination of employment on September30, 2013 (or, if applicable, the date such named executive officer actually experienced a qualifying termination):Name Cash Severance ($)(1) Accelerated Vesting ofRestricted Units ($)(2) Benefit Continuation($)(3) Total ($)Robert G. Phillips(4) — — — —John. J. Sherman 2,400,000 — 31,000 2,431,000Michael J. Campbell 1,500,000 1,368,665 31,000 2,899,665William C. Gautreaux 1,500,000 2,245,950 31,000 3,776,950Laura L. Ozenberger 1,500,000 1,891,350 31,000 3,422,350Michael D. Lenox 800,000 947,648 15,500 1,763,148R. Brooks Sherman 2,190,000 3,428,147 31,000 5,649,147Phillip L. Elbert 1,800,000 2,457,179 31,000 4,288,179(1) As described above, amounts reflect cash severance payments payable upon a qualifying termination without “cause” or resignation due to “constructive termination” in accordancewith the Officer Severance Plan. Amounts are equal to three times (or, in the case of Michael D. Lenox, two times) the sum of the named executive officer’s base salary and targetbonus. In the case of John J. Sherman, Laura L. Ozenberger, R. Brooks Sherman, Phillip L. Elbert, and Michael D. Lenox these amounts were paid in connection with such namedexecutive officer’s termination.(2) The amounts reflected in the table above includes the value of restricted units in Crestwood Equity Partners LP and Crestwood Midstream Partners LP which would be subject toaccelerated vesting upon a change of control of Crestwood Equity Partners LP or Crestwood Midstream Partners LP, respectively, or upon the named executive officer’s terminationwithout “cause” or resignation due to “constructive termination’. The value reflected for restricted units is based on the NYSE closing price of $13.77 for CEQP units on September30, 2014 and the NYSE closing price of $22.08 on for CMLP units September 30, 2014 (or, in the case of R. Brooks Sherman , Phillip L. Elbert, Laura L. Ozenberger andMichael D. Lenox the date upon which their employment actually terminated during Fiscal 2013 or the Transition Period).(3) Reflects estimated value of two years (or, in the case of Mr. Lenox, one year) continued participation in welfare benefit plans provided under the Officer Severance Plan upon a“qualifying termination”.(4) Mr. Phillips was not a participant in the Officer Severance Plan or party to an employment agreement which provided for severance benefits as of September 30, 2013. As describedabove, during January 2014 Mr. Phillips, Mr. entered into a new employment agreement with a subsidiary of the company which provides for severance benefits.Payments upon Change of Control and/or Termination on the Last Day of Transition PeriodThe following table presents information about the gross payments paid or potentially payable to our named executive officers pursuant to the OfficerSeverance Plan or restricted unit agreements, assuming each such named executive officer experienced a qualifying termination of employment on December31, 2013 (or, if applicable, the date such named executive officer actually experienced a qualifying termination):Name Cash Severance ($)(1) Accelerated Vesting ofRestricted Units ($)(2) Benefit Continuation($)(3) Total ($)Robert G. Phillips(4) — — — —Michael J. Campbell 1,500,000 1,371,890 31,000 2,902,890Joel C. Lambert(4) — — — —Joel D. Moxley(4) — — — —J. Heath Deneke(4) — — — —Michael D. Lenox 800,000 964,600 31,000 1,795,600(1) As described above, amounts reflect cash severance payments payable upon a qualifying termination without “cause” or resignation due to “constructive termination” in accordancewith the Officer Severance Plan. Amounts are equal to three times (or, in the case of Mr. Lenox, two times) the sum of the named executive officer’s base salary and target bonus. Inthe case of Michael Lenox, this amount was paid in connection with the constructive termination of his employment.(2) The amounts reflected in the table above for Mr. Lenox is the value of restricted units in Crestwood Equity Partners LP and Crestwood Midstream Partners LP which were subjectto accelerated vesting on the date of Mr. Lenox’s constructive termination The value reflected for Mr. Campbell is based on the NYSE closing price CEQP and CMLP units onDecember 31, 2013.(3) Reflects estimated value of two years continued participation in welfare benefit plans provided under the Officer Severance Plan upon a “qualifying termination”.88Table of Contents(4) Robert G. Phillips, Joel D. Moxley, Joel C. Lambert and J. Heath Deneke were not participants in the Officer Severance Plan or party to an employment agreement which provided forseverance benefits as of December 31, 2013. As described above, during January 2014 Messrs. Phillips, Moxley, Lambert and Deneke entered into new employment agreements witha subsidiary of the company which provides for severance benefits.Director Compensation Table for the Fiscal 2013The following table sets forth the cash and non-cash compensation for the fiscal year ended September 30, 2013, by each person who served as a non-employee director of our general partner during such timeName Fees Earned or Paid inCash ($) Unit Awards ($)(2) Total ($)Michael France 10,000 — 10,000Warren Gfeller 78,000 50,000 128,000Arthur Krause 86,000 50,000 136,000John Sherman (1) 10,000 — 10,000David Wood 10,000 — 10,000Robert Taylor 86,500 50,000 136,500(1)On June 19, 2013, John Sherman resigned as Chief Executive Officer and President of our general partner, but continued to serve as a non-employee director. The compensation forMr. Sherman in the above chart only reflects fees and awards paid to him after June 19, 2013 in his role as a non-employee director. Information concerning Mr. Sherman’scompensation as President and Chief Executive Officer can be found in the Summary Compensation Table.(2)Reflects the value of restricted unit awards, calculated in accordance with ASC 718, disregarding estimated forfeitures. These restricted unit grants will vest on each of the firstthree anniversaries of grant. See Part IV, Item 15, Exhibits and Financial Statement Schedules, Note 12 for a discussion of the assumptions used to determine the FASB ASC 718value of the awards. As of September 30, 2013, Mr. Gfeller and Mr. Krause each held 4,853 restricted units.Director Compensation Table for the Transition PeriodThe following table sets forth the cash and non-cash compensation for the Transition Period commencing on October 1, 2013 and ending on December 31,2013, by each person who served as a non-employee director of our general partner during such time.Name Fees Earned or Paidin Cash ($) Unit Awards ($)(3) Total ($)Alvin Bledsoe 20,000 20,000 40,000Michael France 15,000 20,000 35,000Warren Gfeller 20,000 20,000 40,000Arthur Krause 20,000 20,000 40,000Randy Moeder 25,000 113,460(4) 138,460John Sherman(1) 15,000 20,000 35,000John Somerhalder II 20,000 20,000 40,000David Wood 17,500 20,000 37,500Robert Taylor(2) — — —(1) On June 19, 2013, John Sherman resigned as Chief Executive Officer and President of our general partner, but continued to serve as a non-employee director. The compensation forMr. Sherman in the above chart only reflects fees and awards paid to him after June 19, 2013 in his role as a non-employee director. Information concerning Mr. Sherman’scompensation as President and Chief Executive Officer can be found in the Summary Compensation Table.(2) Robert Taylor resigned from the board effective October 7, 2013.(3) Reflects the value of restricted unit awards, calculated in accordance with ASC 718, disregarding estimated forfeitures. See Part IV, Item 15, Exhibits and Financial StatementSchedules, Note 12 for a discussion of the assumptions used to determine the FASB ASC Topic 718 value of the awards. These restricted unit grants will vest on the firstanniversary of grant. As of December 31, 2013, our non-employee directors held the following restricted unit awards: Mr. Bledsoe, Mr. France, Mr. Sherman, Mr. Somerhalder IIand Mr. Wood each held 1,315 restricted units; Mr. Krause and Mr. Gfeller each held 6,168 restricted units and Mr. Moeder held 7,674 restricted units.(4) Upon the closing of the Inergy/Crestwood transaction, Mr. Moeder resigned from the Crestwood Midstream GP LLC board of directors and was appointed to our board of directors.Upon his resignation he forfeited 3,660 CMLP restricted units. Our compensation committee awarded Mr. Moeder CEQP restricted units of equal value (6,332) to his forfeitedCMLP restricted units to vest on the same schedule as his forfeited CMLP restricted units.89Table of ContentsCompensation of Directors during Fiscal 2013 and the Transition Period Officers of our general partner who also serve as directors do not receive additional compensation. During Fiscal 2013, each director received cashcompensation of $40,000 per year for attending our regularly scheduled quarterly board meetings. Each non-employee director receives $1,000 for each specialmeeting of the board of directors attended and $1,000 per compensation or audit committee meeting attended. The chairman of the audit committee receives anannual fee of $10,000 per year and the chairman of the compensation committee receives an annual fee of $2,000 per year. Furthermore, each non-employeedirector received an annual grant of restricted units under the Inergy, L.P. Long Term Incentive Plan equal to $50,000 in value.Effective as of October 7, 2013, the board of directors of our general partner, upon recommendation of the compensation committee, approved a newcompensation package for non-employee directors. Officers of our general partner who also serve as directors do not receive additional compensation. Eachdirector receives cash compensation of $80,000 per year for serving on our board of directors; provided, however, that if a non-employee directors serves onboth our board of directors and the board of directors of CMLP GP, the director receives annual cash compensation of $60,000 for each board. The leaddirector, audit committee chairperson and conflicts committee chairperson each receive additional cash compensation of $20,000 per year and thecompensation committee chairperson receives additional cash compensation of $10,000 per year. All cash compensation is paid to the non-employee directorsin quarterly installments. Additionally, each non-employee director receives an annual grant of restricted units under our long-term incentive plan equal to$80,000 in value that vests on the first anniversary of the date of issuance. For the time period between October 7, 2013 and December 31, 2013, each directorreceived a grant of restricted units under our long term incentive plan equal to $20,000 in value, which will vest in January 2015.Each non-employee director is reimbursed for out-of-pocket expenses in connection with attending meetings of the board of directors or committees.Compensation Committee Interlocks and Insider Participation The compensation committee of the board of directors of our general partner oversees the compensation of our executive officers. David Wood and WarrenGfeller serve as the members of the compensation committee, and neither of them was an officer or employee of our company or any of its subsidiaries duringFiscal 2013 or the Transition Period.Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Unitholder Matters.The following table sets forth certain information as of February 14, 2014, regarding the beneficial ownership of our limited partner units by:•each person who then beneficially owned more than 5% of such units then outstanding;•each of the named executive officers of our general partner;•each of the directors of our general partner; and•all of the directors and executive officers of our general partner as a group.All information with respect to beneficial ownership has been furnished by the respective directors, executive officers or 5% or more unitholders, as the casemay be.90Table of ContentsName of Beneficial Owner (1) Limited Partner UnitsBeneficially Owned Percentage of Limited PartnerUnits Beneficially OwnedCrestwood Holdings Partners LLC(2)(4) 53,809,398 28.9%Crestwood Gas Services Holdings LLC(3)(4) 53,809,398 28.9%Neuberger Berman Group LLC(5) 22,413,083 12.0%Advisory Research, Inc.(6) 12,270,254 6.6%Robert G. Phillips 60,114 *J. Heath Deneke 27,946 *William C. Gautreaux 2,547,812 1.4%Michael J. Campbell 101,923 *Steven M. Dougherty 16,704 *Joel C. Lambert 38,458 *William H. Moore 101,461 *Joel D. Moxley 17,566 *John J. Sherman 19,110,181 10.3%Alvin Bledsoe 7,099 *Michael G. France 7,099 *Warren H. Gfeller 127,618 *Arthur B. Krause 123,008 *Randy Moeder 15,731 *John W. Somerhalder II 7,099 *David M. Wood 27,099 *Directors and executive officers as a group (16 persons) 22,336,918 12.0%* Indicates less than 1%(1) Unless otherwise indicated, the contact address for all beneficial owners in this table is 700 Louisiana Street, Suite 2060, Houston, Texas 77002.(2) Crestwood Holdings is the ultimate parent company of Crestwood Gas Services Holdings LLC and may, therefore, be deemed to beneficially own the units held by CrestwoodHoldings.(3) Crestwood Gas Services Holdings LLC, an indirect wholly owned subsidiary of Crestwood Holdings, owns a 100% interest in our General Partner and a 28.9% limited partnerinterest in us.(4) Crestwood Holdings has shared voting power and shared investment power with Crestwood Gas Services Holdings LLC, Crestwood Holdings LLC, Crestwood Holdings II LLC,FR XI CMP Holdings LLC, FR Midstream Holdings LLC, First Reserve GP XI, L.P., First Reserve GP XI, Inc., and William E. Macaulay over 49,421,509 common units and4,387,889 subordinated units of Crestwood Equity Partners LP. Crestwood Gas Services Holdings LP indirectly owns the sole general partner of CEQP.(5) According to a Schedule 13G filed by Neuberger Berman Group LLC, with the SEC on February 12, 2014, Neuberger Berman Group LLC has shared voting power over21,282,563 common units and dispositive power over 22,413,083 common units. The address of Neuberger Berman Group LLC is 605 Third Avenue, New York, New York10158. Neuberger Berman Group LLC disclaims beneficial ownership of these units.(6) According to a Schedule 13GF filed by Piper Jaffray Companies, with the SEC on February 12, 2014. Advisory Research, Inc., a wholly-owned subsidiary of Piper JaffrayCompanies, is the beneficial owner of 12,270,254 common units. The address of Advisory Research, Inc., is 180 N. Stetson, Chicago, IL 60601. Piper Jaffray Companies may bedeemed to be the beneficial owner of these 12,270,254 common units through control of Advisory Research, Inc. Piper Jaffray Companies disclaims beneficial ownership of theseunits.See Item 5 of this report for certain information regarding securities authorized for issuance under equity compensation plans.91Table of ContentsItem 13. Certain Relationships, Related Transactions and Director Independence.For a discussion of director independence, see Item 10 “Directors, Executive Officers and Corporate Governance.”Transactions with Related PersonsOmnibus AgreementWe have entered into an omnibus agreement with our general partner, CMLP and its general partner that governs certain aspects of our relationship with them,including:•the provision by us to CMLP of certain administrative services and CMLP’s agreement to reimburse us for such services;•the provision by us of such employees as may be necessary to operate and manage CMLP’s business, and CMLP’s agreement to reimburse us forthe expenses associated with such employees; and•certain indemnification obligations.Our indemnification obligations to CMLP include certain liabilities relating to:•for three years after CMLP’s December 2011 initial public offering ("IPO") , certain environmental liabilities attributable to the ownership andoperation of CMLP’s assets prior to the CMLP IPO, including (i) any violation or correction of a violation of environmental laws associated withCMLP’s assets, where a correction of violation would include assessment, investigation, monitoring, remediation, or other similar action and (ii) anyevent, omission or condition associated with the ownership or operation of CMLP’s assets (including the presence or release of hazardous materials),including (a) the cost and expense of any assessment, investigation, monitoring, remediation or other similar action, (b) the cost and expense of thepreparation and implementation of any closure activity or remedial or corrective action required under environmental laws, and (c) the cost andexpense of any environmental or toxic tort litigation;•environmental liabilities attributable with CMLP’s prior ownership and operation of Tres Palacios Gas Storage LLC;•the ownership and operation of CMLP’s assets prior to its IPO;provided, that (i) the aggregate amount payable to CMLP pursuant to the first bullet point above will not exceed $15 million and (ii) amounts are only payableto CMLP pursuant to the first and second bullet points above after liabilities relating to the first and second bullet points have exceeded $100,000 and then onlyfor such amounts in excess of $100,000;•until the first day after the applicable statute of limitations, any of CMLP’s federal, state and local income tax liabilities attributable to the ownershipand operation of CMLP’s assets prior to the CMLP IPO;•for three years after the closing of the CMLP IPO, the failure to have all necessary consents and governmental permits where such failure rendersCMLP unable to use and operate its assets in substantially the same manner in which they were used and operated immediately prior to the CMLPIPO; and•for three years after the closing of the CMLP IPO, CMLP’s failure to have valid and indefeasible easement rights, rights-of-way, leasehold and/or feeownership interest in and to the lands on which CMLP’s assets are located and such failure prevents CMLP from using or operating its assets insubstantially the same manner as they were used or operated immediately prior to the CMLP IPO.We will not be required to indemnify CMLP for any claims, losses or expenses or income taxes referred to above to the extent such were either (i) reserved for inCMLP’s financial statements as of the closing of the CMLP IPO or (ii) CMLP recovers any such amounts under available insurance coverage, fromcontractual rights or other recoveries against any third party.92Table of ContentsCMLP’s indemnification obligations to us, our general partner and to our affiliates (other than CMLP and its subsidiaries) include certain liabilities relating to:•certain environmental liabilities attributable to the ownership and operation of CMLP’s assets, but only to the extent the violations, events, omissionsor conditions giving rise to such covered environmental liabilities occur after the closing of the CMLP IPO; provided , that (i) our aggregate liabilityfor such covered environmental liabilities will not exceed $15 million and (ii) amounts are only payable by us pursuant to this bullet point afterliabilities relating to such covered environmental losses have exceeded $100,000 and then only for such amounts in excess of $100,000; and•losses suffered or incurred by us by reason of or arising out of events and conditions associated with the operation of CMLP’s assets that occur on orafter the CMLP IPO (other than covered environmental losses, which are covered by the preceding bullet).With respect to the provision by us of certain administrative services and such management and operating services as may be necessary to manage and operateCMLP’s business, the omnibus agreement addresses certain aspects of our relationship with CMLP, including:•the provision by us to CMLP of certain specified administrative services necessary to run CMLP’s business, including the provision of suchemployees as may be necessary to operate and manage CMLP’s business, and CMLP’s agreement to reimburse us for all reasonable costs andexpenses incurred in connection with such services;•CMLP’s agreement to reimburse us for all expenses we incurred as a result of CMLP becoming a publicly traded partnership; and•CMLP’s agreement to reimburse us for all expenses that we incurred or payments we make on CMLP’s behalf with respect to insurance coverage forour business.Except for the indemnification provisions, the omnibus agreement may be terminated by us with 180 days’ prior written notice if (i) Crestwood Midstream GPLLC is removed as CMLP’s general partner under circumstances where “cause” does not exist and the common units held by us and our affiliates were notvoted in favor of such removal; (ii) a change of control of CMLP occurs; or (iii) a change of control of us occurs. Except for the indemnification provisions,CMLP may terminate the omnibus agreement with 180 days’ prior written notice if a change of control of CMLP occurs, a change of control of us occurs orInergy Holdings GP, LLC, the indirect owner of our general partner, acquires MGP GP, LLC, the entity that controls CMLP’s general partner, pursuant to acertain membership interest purchase agreement.During the year ended December 31, 2013, CMLP paid approximately $5.0 million to us pursuant to the omnibus agreement.Tax Sharing AgreementWe have entered into a tax sharing agreement with CMLP pursuant to which CMLP will reimburse us for its share of state and local income and other taxesborne by us as a result of CMLP’s income being included in a combined or consolidated tax return filed by us with respect to taxable periods including orbeginning on the closing date of the CMLP IPO. The amount of any such reimbursement will be limited to the tax that CMLP (and its subsidiaries) wouldhave paid had CMLP not been included in a combined group with us. We may use our tax attributes to cause our combined or consolidated group, of whichCMLP may be a member for this purpose, to owe no tax. However, CMLP would nevertheless reimburse us for the tax CMLP would have owed had theattributes not been available or used for our benefit, even though we had no cash expense for that period.Registration Rights AgreementIn connection with the Crestwood Merger, we entered into a registration rights agreement with John J. Sherman, our former president and chief executive officerwho currently serves on our board of directors.Review, Approval or Ratification of Transactions with Related PersonsOur related person transactions policy applies to any transaction since the beginning of our fiscal year (or currently proposed transaction) in which we or anyof our subsidiaries was or is to be a participant, the amount involved exceeds $120,000 and any director, director nominee, executive officer, 5% or greaterunitholder (or their immediate family members) had, has or will have a direct or indirect material interest. A transaction that would be covered by this policywould include, but not be limited to, any financial transaction, arrangement or relationship (including any indebtedness or guarantee of indebtedness) or anyseries of similar transactions, arrangements or relationships.93Table of ContentsUnder our related person transactions policy, related person transactions may be entered into or continue only if the transaction is deemed to be “fair andreasonable” to us, in accordance with the terms of our partnership agreement. Under our partnership agreement, transactions that represent a “conflict ofinterest” may be approved in one of three ways and, if approved in any of those ways, will be considered “fair and reasonable” to us and the holders of ourcommon units. The three ways enumerated in our related person transactions Policy for reaching this conclusion include:(i)approval by the Conflicts Committee of the Board (the “Conflicts Committee”) under Section 7.9 of our partnership agreement (“Special Approval”);(ii)approval by our Chief Executive Officer applying the criteria specified in Section 7.9 of our partnership agreement if the transaction is in the normalcourse of the partnership’s business and is (a) on terms no less favorable to the partnership than those generally being provided to or available fromunrelated third parties or (b) fair to the partnership, taking into account the totality of the relationships between the parties involved (including othertransactions that may be particularly favorable or advantageous to the Partnership); and(iii)approval by an independent committee of the Board (either the Audit Committee or a Special Committee) applying the criteria in Section 7.9 of ourpartnership agreement.Once a transaction is approved in any of these ways, it is “fair and reasonable” and accordingly deemed (i) approved by all of our partners and (ii) not to be abreach of any fiduciary duties of general partner.Our general partner determines in its discretion which method of approval is required depending on the circumstances.Under our partnership agreement, when determining whether a related person transaction is “fair and reasonable,” if our general partner elects to adopt aresolution or a course of action that has not received Special Approval, then our general partner may consider:•the relative interests of any party to such conflict, agreement, transaction or situation and the benefits and burdens relating to such interest;•any customary or accepted industry practices and any customary or historical dealings with a particular person;•any applicable generally accepted accounting practices or principles; and•such additional factors as the general partner or conflicts committee determines in its sole discretion to be relevant, reasonable or appropriate underthe circumstances.A related person transaction that is approved by the conflicts committee is, as discussed in greater detail above, conclusively deemed to be fair and reasonableto us. Under our partnership agreement, the material facts known to our general partner or any of our affiliates regarding the transaction must be disclosed tothe conflicts committee at the time the committee gives its approval. When approving a related party transaction, the conflicts committee considers all factors itconsiders relevant, reasonable or appropriate under the circumstances, including the relative interests of any party to the transaction, customary industrypractices and generally accepted accounting principles.Under our partnership agreement, in the absence of bad faith by the general partner, the resolution, action or terms so made, taken or provided by the generalpartner with respect to approval of the related party transaction will not constitute a breach of our partnership agreement or any standard of fiduciary duty.Under our related person transactions policy, as well as under our partnership agreement, there is no obligation to take any particular conflict to the conflictscommittee-empanelling that committee is entirely at the discretion of the general partner. In many ways, the decision to engage the conflicts committee can beanalogized to the kinds of transactions for which a Delaware corporation might establish a special committee of independent directors. The general partnerconsiders the specific facts and circumstances involved. Relevant facts would include:•the nature and size of the transaction (e.g., transaction with a controlling unitholder, magnitude of consideration to be paid or received, impact ofproposed transaction on the general partner and holders of common units);•the related person’s interest in the transaction;•whether the transaction is on terms no less favorable than terms generally available to an unaffiliated third-party under the same or similarcircumstances;94Table of Contents•if applicable, the availability of other sources of comparable services or products; and•the financial costs involved, including costs for separate financial, legal and possibly other advisors at our expense.When determining whether a related person transaction is in the normal course of our business and is (a) on terms no less favorable to us than those generallybeing provided to or available from unrelated third parties or (b) fair to us, taking into account the totality of the relationships between the parties involved(including other transactions that may be particularly favorable or advantageous to us), the general partner considers any facts and circumstances that itdeems to be relevant, including:•the terms of the transaction, including the aggregate value;•the business purpose of the transaction;•the relative interests of any party to such conflict, agreement, transaction or situation and the benefits and burdens relating to such interest;•whether the terms of the transaction are comparable to the terms that would exist in a similar transaction with an unaffiliated third party;•any customary or accepted industry practices;•any applicable generally accepted accounting practices or principles; and•such additional factors as the general partner or the conflicts committee determines in its sole discretion to be relevant, reasonable or appropriateunder the circumstances.Item 14. Principal Accountant Fees and Services.Effective as of July 23, 2013, the Audit Committee of the Board (the “Board”) of Directors of Crestwood Equity GP LLC (f/k/a Inergy GP, LLC) dismissedDeloitte & Touche LLP (“Deloitte”) as the independent registered public accounting firm of Legacy Crestwood GP and approved the engagement of Ernst &Young LLP (“E&Y”) as the principal accountant to audit the partnership’s financial statements as of and for the fiscal year ending December 31, 2013. Thedismissal was effective as of the date of the completion by Deloitte of the audit of Legacy Crestwood GP. Legacy Crestwood GP is the accounting predecessor tothe partnership and its financial statements now constitute the primary financial statements of the partnership.The audit report on the financial statements of Legacy Crestwood GP for the fiscal years ended December 31, 2012 and December 31, 2011 issued by Deloittedid not contain any adverse opinion or disclaimer of opinion, nor was the report qualified or modified as to uncertainty, audit scope or accounting principles.Furthermore, during Legacy Crestwood GP’s two most recent fiscal years ended December 31, 2012 and December 31, 2011 and the subsequent interimperiod through July 23, 2013, (1) there were no disagreements between Legacy Crestwood GP and Deloitte on any matter of accounting principles or practices,financial statement disclosure or auditing scope or procedure, which disagreements, if not resolved to the satisfaction of Deloitte, would have caused Deloitte tomake reference thereto in its report on Legacy Crestwood GP’s financial statements for such periods, and (2) there were no “reportable events” as that term isdescribed in Item 304(a)(1)(v) of Regulation S-K.In addition, during Legacy Crestwood GP’s fiscal years ended December 31, 2012 and 2011 and the subsequent interim period ending July 23, 2013, LegacyCrestwood GP did not consult E&Y in regards to Legacy Crestwood GP’s financial statements, which were audited by Deloitte as its independent accountant,with respect to (1) the application of accounting principles to a specified transaction, either completed or proposed and (2) the type of audit opinion that wasrendered on Legacy Crestwood GP’s financial statements or might be rendered on Legacy Crestwood GP’s financial statements. During such fiscal years andsubsequent interim period ending July 23, 2013, Legacy Crestwood GP did not consult with E&Y in regards to Legacy Crestwood GP’s financial statementswith respect to any matter that was the subject of a “disagreement” or a “reportable event” as those terms are described in Item 304(a)(1) of Regulation S-K.95Table of ContentsThe following table presents fees billed for professional audit services rendered for the audit of our and CMLP's annual financial statements and for otherservices for the years ended December 31, 2013 and 2012 (in millions): Ernst & Young LLP Deloitte & Touche LLP 2013 2013 2012Audit fees(1)$4.2 $1.5 $1.7(1)Includes fees for the integrated audit of annual financial statements and internal control over financial reporting, reviews of related quarterly financial statements and reviews of andissuances of comfort letters related to other documents filed with the SEC.The audit committee of our general partner reviewed and approved all audit and non-audit services provided to us during 2013. For information regarding theaudit committee’s pre-approval policies and procedures related to the engagement by us of an independent accountant, see our audit committee charter on ourwebsite at www.crestwoodlp.com.96Table of ContentsPART IVItem 15. Exhibits and Financial Statement Schedules.(a)Exhibits, Financial Statements and Financial Statement Schedules:1.Financial Statements:See Index Page for Financial Statements located on page 102.2.Financial Statement Schedules:Schedule I: Parent Only Condensed Financial Statements located on page 157.Schedule II: Valuation and Qualifying Accounts located on page 162.Other financial statement schedules have been omitted because they are either not required, are immaterial or are not applicable or because equivalentinformation has been included in the financial statements, the notes thereto or elsewhere herein. 3.Exhibits:ExhibitNumber Description2.1 Agreement and Plan of Merger, dated August 7, 2010, among Inergy, L.P., Inergy GP, LLC, Inergy Holdings, L.P., NRGPLimited Partner, LLC and NRGP MS, LLC (incorporated herein by reference to Exhibit 2.1 to Inergy, L.P.’s Form 8-K filed onAugust 9, 2010) 2.2 First Amended and Restated Agreement and Plan of Merger, dated September 3, 2010, among Inergy, L.P., Inergy GP, LLC,Inergy Holdings, L.P., NRGP Limited Partner, LLC and NRGP MS, LLC (incorporated herein by reference to Exhibit 2.1 toInergy, L.P.’s Form 8-K filed on September 7, 2010) 2.3 Purchase and Sale Agreement, dated September 3, 2010, between TP Gas Holding LLC and Inergy Midstream, LLC(incorporated herein by reference to Exhibit 2.1 to Inergy, L.P.’s Form 8-K filed on September 7, 2010) 2.4 Contribution Agreement dated April 25, 2012 by and among Inergy, L.P., Inergy GP, LLC, Inergy Sales & Services, Inc. andSuburban Propane Partners, L.P. (incorporated herein by reference to Exhibit 2.1 to Inergy, L.P.'s Form 8-K filed April 26,2012) 2.5 Amendment to Contribution Agreement dated June 15, 2012 by and among Inergy, L.P., Inergy GP, LLC, Inergy Sales &Services, Inc. and Suburban Propane Partners, L.P. (incorporated herein by reference to Exhibit 2.1 to Inergy, L.P.’s Form 8-Kfiled June 15, 2012) 2.6 Second Amendment to Contribution Agreement dated July 6, 2012 by and among Inergy, L.P., Inergy GP, LLC, Inergy Sales &Services, Inc. and Suburban Propane Partners, L.P. (incorporated herein by reference to Exhibit 2.1 to Inergy, L.P.'s Form 8-Kfiled July 6, 2012) 2.7 Third Amendment to Contribution Agreement dated July 19, 2012 by and among Inergy, L.P., Inergy GP, LLC, Inergy Sales &Services, Inc. and Suburban Propane Partners, L.P. (incorporated herein by reference to Exhibit 2.1 to Inergy, L.P.'s Form 8-Kfiled July 19, 2012) 2.8 Contribution Agreement dated May 5, 2013, by and among Crestwood Holdings LLC, Crestwood Gas Services HoldingsLLC, Inergy GP, LLC and Inergy, L.P. (incorporated herein by reference to Exhibit 2.1 to Inergy, L.P.’s Form 8-K filed on May9, 2013) 2.9 Follow-On Contribution Agreement dated as of May 5, 2013, by and among Crestwood Holdings LLC, Crestwood GasServices Holdings LLC, Inergy GP, LLC and Inergy, L.P. (incorporated herein by reference to Exhibit 2.2 to Inergy, L.P.’s Form8-K filed on May 9, 2013) 3.1 Certificate of Limited Partnership of Inergy, L.P. (incorporated herein by reference to Exhibit 3.1 to Inergy, L.P.’s RegistrationStatement on Form S-1 (Registration No. 333-56976) filed on March 14, 2001) 3.1A Certificate of Correction of Certificate of Limited Partnership of Inergy, L.P. (incorporated herein by reference to Exhibit 3.1 toInergy, L.P.’s Form 10-Q filed on May 12, 2003) 97Table of ContentsExhibitNumber Description3.1B Amendment to the Certificate of Limited Partnership of Crestwood Equity Partners LP (f/k/a Inergy, L.P.) (the “Partnership”)dated as of October 7, 2013 (incorporated herein by reference to Exhibit 3.2 to the Partnership’s Form 8-K filed on October 10,2013) 3.2 Fourth Amended and Restated Agreement of Limited Partnership of Inergy, L.P. dated June 19, 2013 (incorporated herein byreference to Exhibit 10.1 to Inergy, L.P.’s Form 8-K filed on June 19, 2013) 3.2A Amendment No. 1 to Fourth Amended and Restated Agreement of Limited Partnership of Inergy L.P. entered into effectiveOctober 7, 2013 (incorporated herein by reference to Exhibit 3.1 to the Partnership’s Form 8-K filed on October 10, 2013) 3.3 Certificate of Formation of Inergy GP, LLC (incorporated herein by reference to Exhibit 3.5 to Inergy, L.P.’s RegistrationStatement on Form S-1/A (Registration No. 333-56976) filed on May 7, 2001) 3.3A Certificate of Amendment of Crestwood Equity GP LLC (f/k/a Inergy GP, LLC) dated October 7, 2013 (incorporated herein byreference to Exhibit 3.3A to the Partnership’s Form 10-Q filed on November 8, 2013) 3.4 First Amended and Restated Limited Liability Company Agreement of Inergy GP, LLC dated as of September 27, 2012(incorporated by reference to Exhibit 3.1 to Inergy, L.P.'s Form 8-K filed on September 27, 2012) 3.4A Amendment No. 1 to the First Amended and Restated Limited Liability Company Agreement of Crestwood Equity GP LLC(f/k/a Inergy GP, LLC) entered into effective October 7, 2013(incorporated herein by reference to Exhibit 3.4A to thePartnership’s Form 10-Q filed on November 8, 2013) 4.1 Specimen Unit Certificate for Common Units (incorporated herein by reference to Exhibit 4.3 to Inergy L.P.’s RegistrationStatement on Form S-1/A (Registration No. 333-56976) filed on May 7, 2001) 4.2 Indenture dated February 2, 2009, by and among Inergy, L.P., Inergy Finance Corp., the Subsidiary Guarantors named thereinand U.S. Bank National Association, as trustee (incorporated herein by reference to Exhibit 4.1 to Inergy, L.P.’s Form 8-K filedon February 3, 2009) 4.3 First Supplemental Indenture and Amendment-Subsidiary Guarantee dated November 5, 2010, to the Indenture, datedFebruary 2, 2009 (incorporated herein by reference to Exhibit 10.4 to Inergy, L.P.’s Form 8-K filed on November 5, 2010) 4.4 Indenture dated September 27, 2010, by and among Inergy, L.P., Inergy Finance Corp., the Subsidiary Guarantors namedtherein and U.S. Bank National Association, as trustee (incorporated herein by reference to Exhibit 4.1 to Inergy, L.P.’s Form 8-K filed on September 28, 2010) 4.5 First Supplemental Indenture and Amendment-Subsidiary Guarantee dated November 5, 2010, to the Indenture datedSeptember 27, 2010 (incorporated herein by reference to Exhibit 10.5 to Inergy, L.P.’s Form 8-K filed on November 5, 2010) 4.6 Indenture dated as of February 2, 2011, by and among Inergy, L.P., Inergy Finance Corp., the Subsidiary Guarantors namedtherein and U.S. Bank National Association, as trustee (incorporated herein by reference to Exhibit 4.3 to Inergy, L.P.’s Form 8-K filed on February 3, 2011) 4.7 Second Supplemental Indenture dated July 17, 2012, to the Indenture dated September 27, 2010 (incorporated herein byreference to Exhibit 4.1 to Inergy, L.P.’s Form 8-K filed on July 19, 2012) 4.8 Second Supplemental Indenture dated July 17, 2012, to the Indenture dated February 2, 2011 (incorporated herein by referenceto Exhibit 4.2 to Inergy, L.P.’s Form 8-K filed on July 19, 2012) 4.9 Third Supplemental Indenture dated August 1, 2012, to the Indenture dated September 27, 2010 (incorporated herein byreference to Exhibit 4.1 to Inergy, L.P.’s Form 8-K filed on August 3, 2012) 4.10 Third Supplemental Indenture dated August 1, 2012, to the Indenture dated February 2, 2011 (incorporated herein by referenceto Exhibit 4.2 to Inergy, L.P.’s Form 8-K filed on August 3, 2012) 4.11 Second Supplemental Indenture dated August 1, 2012, to the Indenture dated February 2, 2009 (incorporated herein byreference to Exhibit 4.3 to Inergy, L.P.’s Form 8-K filed on August 3, 2012) 4.12 Registration Rights Agreement dated June 19, 2013, by and among Inergy, L.P., John J. Sherman, Crestwood Holdings LLCand Crestwood Gas Services Holdings LLC (incorporated herein by reference to Exhibit 4.1 to Inergy, L.P.’s Form 8-K filed onJune 19, 2013) 98Table of ContentsExhibitNumber Description*10.1 Employment Agreement between Robert Phillips and Crestwood Operations LLC dated as of January 21, 2014 (incorporated byreference to Exhibit 10.1 to Crestwood Equity Partners LP’s Form 8-K filed on January 27, 2014) *10.2 Employment Agreement between Michael Campbell and Crestwood Operations LLC dated as of January 21, 2014 (incorporatedby reference Exhibit 10.2 to Crestwood Equity Partners LP’s Form 8-K filed on January 27, 2014) *10.3 Employment Agreement between William Gautreaux and Crestwood Operations LLC dated as of January 21, 2014(incorporated by reference to Exhibit 10.3 to Crestwood Equity Partners LP’s Form 8-K filed on January 27, 2014) **10.4 Employment Agreement between J. Heath Deneke and Crestwood Operations LLC **10.5 Employment Agreement between Joel C. Lambert and Crestwood Operations LLC **10.6 Employment Agreement between Joel D. Moxley and Crestwood Operations LLC **10.7 Crestwood Equity Partners LP Long Term Incentive Plan *10.8 Form of Inergy, L.P.’s Restricted Unit Award Agreement (incorporated herein by reference to Exhibit 10.11 to Inergy, L.P.’s Form10-K filed on November 29, 2007) *10.9 Amended and Restated Inergy Unit Purchase Plan (incorporated herein by reference to Exhibit 10.1 to Inergy L.P.’s Form 10-Qfiled on February 13, 2004) *10.10 Summary of Non-Employee Director Compensation(incorporated herein by reference to Exhibit 10.11 to Inergy, L.P.’s Form 10-K filed on November 29, 2010) *10.11 Inergy Group Officer Severance Plan (incorporated herein by reference to Exhibit 10.4 to Inergy, L.P.’s Form 8-K filed on May9, 2013) *10.12 Form of Amendment to Restricted Unit Agreements under Inergy Long Term Incentive Plan (incorporated herein by reference toExhibit 10.5 to Inergy, L.P.’s Form 8-K filed on May 9, 2013) 10.13 Amended and Restated Credit Agreement dated as of February 2, 2011 among Inergy, L.P., lenders named therein andJPMorgan Chase Bank, N.A. as administrative agent (incorporated herein by reference to Exhibit 10.1 to Inergy, L.P.’s Form 8-K filed on February 3, 2011) 10.14 Amendment No. 1 to Amended and Restated Credit Agreement, dated as of July 28, 2011 among Inergy, L.P., lenders namedtherein and JPMorgan Chase Bank, N.A. as administrative agent (incorporated herein by reference to Exhibit 10.1 to Inergy,L.P.’s Form 8-K filed on August 1, 2011) 10.15 Consent and Amendment No. 2 dated as of December 21, 2011 among Inergy, L.P., lenders named therein and JPMorganChase Bank, N.A. as administrative agent (incorporated herein by reference to Exhibit 10.1 to Inergy, L.P.’s Form 8-K filed onDecember 22, 2011) 10.16 Consent and Amendment No. 3 dated as of April 13, 2012 among Inergy, L.P., lenders named therein and JPMorgan ChaseBank, N.A. as administrative agent (incorporated herein by reference to Exhibit 10.1 to Inergy, L.P.’s Form 8-K filed onApril 19, 2012) 10.17 Consent and Amendment No. 4 dated as of July 26, 2012, to the Amended and Restated Credit Agreement, dated November 24,2009, as amended and restated as of February 2, 2011, among Inergy, L.P., lenders named therein and JPMorgan Chase Bank,N.A. as administrative agent (incorporated herein by reference to Exhibit 10.1 to Inergy, L.P.’s Form 8-K filed on July 27,2012) 10.18 Consent, Waiver and Amendment No. 5, dated May 23, 2013, to the Amended and Restated Credit Agreement, dated as ofNovember 24, 2009, as amended and restated as of February 2, 2011, by and among Inergy, L.P., JPMorgan Chase Bank,N.A., as administrative agent, and the financial institutions party thereto (incorporated herein by reference to Exhibit 10.1 toInergy, L.P.’s Form 8-K filed on May 30, 2013) 10.19 Amendment No. 6, dated August 28, 2013, to the Amended and Restated Credit Agreement, dated as of November 24, 2009,as amended and restated as of February 2, 2011, by and among Inergy, L.P., JPMorgan Chase Bank, N.A., as administrativeagent, and the financial institutions party thereto (incorporated herein by reference to Exhibit 10.1 to Inergy, L.P.’s Form 8-Kfiled on August, 30, 2013) 99Table of ContentsExhibitNumber Description10.20 Amendment No. 7, dated August 28, 2013, to the Amended and Restated Credit Agreement, dated asof November 24, 2009, as amended and restated as of February 2, 2011, by and among Crestwood Equity Partners LP,JPMorgan Chase Bank, N.A., as administrative agent, and the financial institutions party thereto (incorporated herein byreference to Exhibit 10.1 to Form 8-K filed on December 24, 2013) 10.21 Contribution, Conveyance and Assumption Agreement dated December 21, 2011, by and among Inergy GP, LLC, Inergy, L.P.,Inergy Propane, LLC, MGP GP, LLC, Inergy Midstream Holdings, L.P., NRGM GP, LLC, and Inergy Midstream, L.P.(incorporated by reference to Exhibit 10.2 to Inergy L.P.’s Form 8-K filed on December 22, 2011) 10.22 Omnibus Agreement, dated December 21, 2011 by and among Inergy GP, LLC, Inergy, L.P., NRGM GP, LLC and InergyMidstream, L.P. (incorporated by reference to Exhibit 10.3 to Inergy L.P.’s Form 8-K filed on December 22, 2011) 10.23 Membership Interest Purchase Agreement dated December 21, 2011, by and among Inergy , L.P. and Inergy Holdings GP, LLC(incorporated by reference to Exhibit 10.4 to Inergy L.P.’s Form 8-K filed on December 22, 2011) 10.24 Support Agreement dated August 1, 2012, by and among Inergy , L.P., Suburban Propane Partners, L.P. and SuburbanEnergy Finance Corp. (incorporated by reference to Exhibit 10.1 to Inergy L.P.’s Form 8-K filed on August 3, 2012) 10.25 Agreement and Plan of Merger dated May 5, 2013, by and among Inergy Midstream, L.P., NRGM GP, LLC, Intrepid MergerSub, LLC, Inergy, L.P., Crestwood Holdings LLC, Crestwood Midstream Partners LP and Crestwood Gas Services GP LLC(incorporated herein by reference to Exhibit 10.1 to Inergy L.P.’s Form 8-K filed on May 9, 2013) 10.26 Voting Agreement, dated May 5, 2013, by and among Inergy Midstream, L.P., NRGM GP, LLC, Intrepid Merger Sub, LLC,Crestwood Gas Services GP LLC, Crestwood Gas Services Holdings LLC, Crestwood Holdings LLC and CrestwoodMidstream Partners LP (incorporated herein by reference to Exhibit 10.2 to Inergy, L.P.’s Form 8-K filed on May 9, 2013) 10.27 Option Agreement, dated May 5, 2013, by and among Inergy, L.P., Inergy Midstream, L.P., NRGM GP, LLC, Intrepid MergerSub, LLC, Crestwood Gas Services GP LLC, Crestwood Gas Services Holdings LLC and Crestwood Holdings LLC(incorporated herein by reference to Exhibit 10.3 to Inergy, L.P.’s Form 8-K filed on May 9, 2013) *10.28 Employment Agreement dated as of November 24, 2010 between Inergy GP, LLC and John J. Sherman (incorporated herein byreference to Exhibit 10.1 to Inergy, L.P.’s Form 10-K filed on November 29, 2010) *10.29 Employment Agreement, dated as of January 27, 2011 between Inergy GP, LLC and Laura L. Ozenberger (incorporated hereinby reference to Exhibit 10.1 to Inergy L.P.'s Form 10-K filed on November 15, 2011) *10.30 Amended and Restated Employment Agreement, dated as of February 1, 2010, between Inergy GP, LLC and R. BrooksSherman, Jr. (incorporated by reference to Exhibit 10.1 to Inergy, L.P.’s Form 10-Q filed on February 3, 2010) *10.31 Amended and Restated Employment Agreement, dated as of October 1, 2012, between Inergy GP, LLC and Michael J.Campbell (incorporated by reference to Exhibit 10.20 to Inergy, L.P.’s Form 10-K filed on November 20, 2012) *10.32 Employment Agreement, dated as of April 21, 2011 between Inergy GP, LLC and William C. Gautreaux (incorporated herein byreference to Exhibit 10.121to Inergy L.P.'s ’s Form 10-K filed on November 20, 2012) **12.1 Computation of ratio of earnings to fixed charges 16.1 Letter Regarding Change in Certifying Accountant (incorporated herein by reference to Exhibit 16.1 to Inergy, L.P.’s Form 8-K/A filed on July 23, 2013) **21.1 List of subsidiaries of Crestwood Equity Partners LP **23.1 Consent of Ernst & Young LLP **23.2 Consent of Deloitte & Touche LLP 100Table of ContentsExhibitNumber Description**31.1 Certification of the Chief Executive Officer pursuant to Rule 13a-14(a) and Rule 15d-14(a) of the Securities Exchange Act, asamended **31.2 Certification of Chief Financial Officer pursuant to Rule 13a-14(a) and Rule 15d-14(a) of the Securities Exchange Act, asamended **32.1 Certification of the Chief Executive Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of theSarbanes-Oxley Act of 2002 **32.2 Certification of the Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of theSarbanes-Oxley Act of 2002 ***101.INS XBRL Instance Document ***101.SCH XBRL Taxonomy Extension Schema Document ***101.CAL XBRL Taxonomy Extension Calculation Linkbase Document ***101.LAB XBRL Taxonomy Extension Label Linkbase Document ***101.PRE XBRL Taxonomy Extension Presentation Linkbase Document ***101.DEF XBRL Taxonomy Extension Definition Linkbase Document*Management contracts or compensatory plans or arrangements**Filed herewith***Pursuant to Rule 406T of Regulation S-T, the Interactive Data Files on Exhibit 101 hereto are deemed not filed or part of a registration statementor prospectus for purposes of Sections 11 or 12 of the Securities Act of 1933, as amended, are deemed not filed for purposes of Section 18 ofthe Securities and Exchange Act of 1934, as amended, and otherwise are not subject to liability under those sections(b)Exhibits.See exhibits identified above under Item 15(a)3.(c)Financial Statement Schedules.See financial statement schedules identified above under Item 15(a)2.101Table of ContentsCrestwood Equity Partners LP (Formerly Inergy, L.P.)Consolidated Financial StatementsDecember 31, 2013 and 2012 and each of theThree Years in the Period EndedDecember 31, 2013Contents Report of Independent Registered Public Accounting Firm103 Report of Independent Registered Public Accounting Firm on Internal Controls Over Financial Reporting105 Audited Consolidated Financial Statements: Consolidated Balance Sheets106 Consolidated Statements of Operations107 Consolidated Statements of Comprehensive Income108 Consolidated Statements of Partners’ Capital109 Consolidated Statements of Cash Flows110 Notes to Consolidated Financial Statements112102Table of ContentsReport of Independent Registered Public Accounting FirmThe Board of Directors of Crestwood Equity GP LLC and Unitholders of Crestwood Equity Partners LPWe have audited the accompanying consolidated balance sheet of Crestwood Equity Partners LP (formerly Inergy, L.P.) (the Company) as of December 31,2013 and the related consolidated statements of operations, comprehensive income, partners' capital and cash flows for the year then ended. Our audit alsoincluded the financial statement schedules listed in the Index and Item 15(a) for the year ended December 31, 2013. These financial statements and schedulesare the responsibility of the Company's management. Our responsibility is to express an opinion on these financial statements and schedules based on ouraudit.We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require thatwe plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includesexamining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accountingprinciples used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our auditprovides a reasonable basis for our opinion.In our opinion, the financial statements referred to above present fairly, in all material respects, the consolidated financial position of Crestwood EquityPartners LP (formerly Inergy, L.P.) at December 31, 2013, and the consolidated results of its operations and its cash flows for the year then ended, inconformity with U.S. generally accepted accounting principles. Also, in our opinion, the related financial statement schedules for the year ended December 31,2013, when considered in relation to the basic financial statements taken as a whole, present fairly, in all material respects, the information set forth therein.We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), Crestwood Equity Partners LP’sinternal control over financial reporting as of December 31, 2013, based on criteria established in Internal Control-Integrated Framework issued by theCommittee of Sponsoring Organizations of the Treadway Commissions (1992 framework) and our report dated February 28, 2014, expressed an unqualifiedopinion thereon./s/ Ernst & Young LLPHouston, TexasFebruary 28, 2014103Table of ContentsReport of Independent Registered Public Accounting FirmTo the Board of Directors and Unitholders of Crestwood Equity Partners LPWe have audited the accompanying consolidated balance sheet of Crestwood Equity Partners LP (formerly known as Inergy, L.P. (formerly known asCrestwood Gas Services GP LLC)) and subsidiaries (the “Company”) as of December 31, 2012, and the related consolidated statements of operations,comprehensive income, cash flows, and partners’ capital for each of the two years in the period ended December 31, 2012. These financial statements are theresponsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our audits.We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require thatwe plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. The Company was notrequired to have, nor were we engaged to perform, an audit of its internal control over financial reporting. Our audits included consideration of internal controlover financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion onthe effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion. An audit also includes examining, on atest basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimatesmade by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.In our opinion, such consolidated financial statements, present fairly, in all material respects, the financial position of Crestwood Equity Partners LP andsubsidiaries at December 31, 2012, and the results of their operations and their cash flows for each of the two years in the period ended December 31, 2012, inconformity with accounting principles generally accepted in the United States of America.The consolidated financial statements give effect to the acquisition of Crestwood Marcellus Midstream LLC by the Company on January 8, 2013, which hasbeen accounted for at historical cost as a reorganization of entities under common control as described in Note 11 to the consolidated financial statements.As discussed in Note 8 to the consolidated financial statements, the 2012 and 2011 consolidated financial statements have been retrospectively adjusted forearnings per unit for the common and subordinated units issued to acquire Crestwood Gas Services GP, LLC on June 19, 2013, as if those units issued wereoutstanding for the entire period prior to the acquisition.As discussed in Note 17 to the consolidated financial statements, the 2012 and 2011 consolidated financial statements have been retrospectively adjusted for achange in segments as a result of the Crestwood Merger as described in Note 1 to the consolidated financial statements.Our audits were conducted for the purpose of forming an opinion on the basic financial statements taken as a whole. With respect to the unaudited pro formainformation presented in Note 4 for the acquisitions of Inergy Midstream, L.P. and Arrow Midstream Holdings, LLC, such information has not been subjectedto the auditing procedures applied in our audits of the basic financial statements and, accordingly, we express no opinion on them./s/ DELOITTE & TOUCHE LLPHouston, TexasJuly 23, 2013(August 5, 2013 as to net income per limited partner unit as described in Note 8)(February 28, 2014 as to retrospective adjustments for change in segments as described in Note 17)104Table of ContentsReport of Independent Registered Public Accounting Firm on Internal Control Over Financial ReportingThe Board of Directors of Crestwood Equity GP LLC and Unitholders of Crestwood Equity Partners LPWe have audited Crestwood Equity Partners LP’s (formerly Inergy L.P.) internal control over financial reporting as of December 31, 2013, based on criteriaestablished in Internal Control-Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (1992 framework)(the COSO criteria). Crestwood Equity Partners LP’s management is responsible for maintaining effective internal control over financial reporting, and for itsassessment of the effectiveness of internal control over financial reporting included in the accompanying Management’s Report on Internal Control overFinancial Reporting. Our responsibility is to express an opinion on the Company's internal control over financial reporting based on our audit.We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require thatwe plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all materialrespects. Our audit included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, testingand evaluating the design and operating effectiveness of internal control based on the assessed risk, and performing such other procedures as we considerednecessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.A company's internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting andthe preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company's internal control overfinancial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflectthe transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permitpreparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are beingmade only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention ortimely detection of unauthorized acquisition, use, or disposition of the company's assets that could have a material effect on the financial statements.Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation ofeffectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliancewith the policies or procedures may deteriorate.As indicated in the accompanying Management’s Report on Internal Control over Financial Reporting, management’s assessment of and conclusion on theeffectiveness of internal control over financial reporting did not include the internal controls of Arrow Midstream Holdings, LLC, which is included in the2013 consolidated financial statements of Crestwood Equity Partners LP (formerly Inergy, L.P.) and constituted $930.6 million of total assets as ofDecember 31, 2013 and $218.8 million and $1.7 million of revenues and operating income, respectively, for the year then ended. Our audit of internal controlover financial reporting of Crestwood Equity Partners LP (formerly Inergy L.P.) also did not include an evaluation of the internal control over financialreporting of Arrow Midstream Holdings, LLC.In our opinion, Crestwood Equity Partners LP maintained, in all material respects, effective internal control over financial reporting as of December 31, 2013,based on the COSO criteria.We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the 2013 consolidated financialstatements of Crestwood Equity Partners LP (formerly Inergy, L.P.) and our report dated February 28, 2014 expressed an unqualified opinion thereon./s/ Ernst & Young LLPHouston, TexasFebruary 28, 2014105Table of ContentsCRESTWOOD EQUITY PARTNERS LP (FORMERLY INERGY, L.P.)CONSOLIDATED BALANCE SHEETS(in millions, except unit information) December 31, 2013 2012 Assets Current assets: Cash and cash equivalents$5.2 $0.1Accounts receivable, less allowance for doubtful accounts of $0.1 million at December 31, 2013412.6 45.4Inventory (Note 3)73.6 —Assets from price risk management activities14.5 —Prepaid expenses and other current assets16.1 4.9Total current assets522.0 50.4 Property, plant and equipment (Note 3)4,108.7 1,197.4Less: accumulated depreciation and depletion203.4 95.0Property, plant and equipment, net3,905.3 1,102.4 Intangible assets (Note 3)1,466.4 845.2Less: accumulated amortization106.0 49.9Intangible assets, net1,360.4 795.3 Goodwill2,552.2 352.2Investment in unconsolidated affiliates151.4 —Other assets31.9 1.3Total assets$8,523.2 $2,301.6 Liabilities and partners’ capital Current liabilities: Accounts payable$379.0 $5.4Accrued expenses and other liabilities (Note 3)177.1 43.1Liabilities from price risk management activities34.9 —Current portion of long-term debt (Note 9)5.1 —Total current liabilities596.1 48.5 Long-term debt, less current portion (Note 9)2,260.9 685.2Other long-term liabilities140.4 17.2Deferred income taxes17.2 —Commitments and contingencies (Note 15) Partners’ capital (Note 11): Partners' capital (185,274,279 and 39,491,002 limited partner units issued and outstanding at December 31, 2013and December 31, 2012)831.6 31.7Total Crestwood Equity Partners LP partners’ capital831.6 31.7Interest of non-controlling partners in subsidiaries4,677.0 1,519.0Total partners’ capital5,508.6 1,550.7Total liabilities and partners’ capital$8,523.2 $2,301.6The accompanying notes are an integral part of these consolidated financial statements.106Table of ContentsCRESTWOOD EQUITY PARTNERS LP (FORMERLY INERGY, L.P.)CONSOLIDATED STATEMENTS OF OPERATIONS(in millions, except unit and per unit data) Year Ended December 31, 2013 2012 2011Revenues: Gathering and processing$216.3 $125.8 $74.6NGL and crude services1,031.3 — —Storage and transportation104.2 — —Related party (Note 16)74.9 113.7 131.2 1,426.7 239.5 205.8 Costs of product/services sold (excluding depreciation, amortization and accretion as shownbelow): Gathering and processing24.1 23.8 38.8NGL and crude services930.0 — —Storage and transportation15.7 — —Related party (Note 16)32.5 15.2 — 1,002.3 39.0 38.8Expenses: Operating and administrative198.1 72.7 60.4Depreciation, amortization and accretion167.9 73.2 53.9 366.0 145.9 114.3Other operating income (expense): Goodwill impairment(4.1) — —Gain on long-lived assets5.3 — 1.1Gain (loss) on contingent consideration (Note 15)(31.4) 6.8 17.2Operating income28.2 61.4 71.0 Loss from unconsolidated affiliates, net(0.1) — —Interest and debt expense, net(77.9) (35.8) (27.6)Other income0.2 — —Income (loss) before income taxes(49.6) 25.6 43.4Provision for income taxes1.0 1.2 1.3Net income (loss)(50.6) 24.4 42.1Net (income) loss attributable to non-controlling partners57.3 (9.5) (34.4)Net income attributable to Crestwood Equity Partners LP$6.7 $14.9 $7.7 Subordinated unitholders' interest in net income$0.3 $1.7 $0.9Common unitholders' interest in net income$6.4 $13.2 $6.8 Net income per limited partner unit: Basic$0.06 $0.38 $0.19Diluted$0.06 $0.38 $0.19 Weighted-average limited partners’ units outstanding (in thousands): Basic109,145 35,103 35,103Dilutive units4,388 4,388 4,388Diluted113,533 39,491 39,491The accompanying notes are an integral part of these consolidated financial statements.107Table of ContentsCRESTWOOD EQUITY PARTNERS LP (FORMERLY INERGY, L.P.)CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME(in millions) Year Ended December 31, 2013 2012 2011Net income (loss)$(50.6) $24.4 $42.1Change in Suburban Propane Partners, L.P. units(0.1) — —Comprehensive income (loss)$(50.7) $24.4 $42.1The accompanying notes are an integral part of these consolidated financial statements.108Table of ContentsCRESTWOOD EQUITY PARTNERS LP (FORMERLY INERGY, L.P.)CONSOLIDATED STATEMENTS OF PARTNERS’ CAPITAL(in millions) Partners Non-ControllingPartners Total Partners’CapitalBalance at December 31, 2010$10.7 $915.3 $926.0Net proceeds from the issuance of Legacy Crestwood common units— 206.3 206.3Issuance of Class C units to Crestwood Gas Services0.8 (0.8) —Contributions from partner8.7 — 8.7Unit-based compensation charges— 0.9 0.9Distributions to partners(5.9) (58.1) (64.0) Net income7.7 34.4 42.1Balance at December 31, 201122.0 1,098.0 1,120.0Net proceeds from the issuance of Legacy Crestwood common units— 217.5 217.5Issuance of Class C units to Crestwood Gas Services2.0 (2.0) —Contributions from partners6.6 284.2 290.8Unit-based compensation charges— 1.9 1.9Taxes paid for unit-based compensation vesting— (0.4) (0.4)Distribution to partners(13.8) (89.7) (103.5)Net income14.9 9.5 24.4Balance at December 31, 201231.7 1,519.0 1,550.7Net proceeds from issuance of common units by subsidiaries— 714.0 714.0Net proceeds from common unit options exercised0.1 — 0.1Issuance of Legacy Crestwood Class D units to non-controlling interest(126.3) 126.3 —Issuance of Legacy Crestwood Class C units to Crestwood Gas Services0.6 (0.6) —Issuance of preferred equity of subsidiary— 96.1 96.1Issuance of units for Arrow acquisition— 200.0 200.0Change in interest in Crestwood Marcellus Midstream LLC238.9 (238.9) —Gain (loss) on issuance of subsidiary units(12.6) 12.6 —Exchange of Crestwood Midstream Partners LP units for CEQP units182.3 (182.3) —Invested capital from Legacy Inergy, net of debt (Note 4)697.1 2,682.3 3,379.4Contribution from Crestwood Holdings LLC— 10.0 10.0Unit-based compensation charges1.7 15.7 17.4Taxes paid for unit-based compensation vesting(2.8) (5.5) (8.3)Distributions to partners(56.6) (214.5) (271.1)Distribution of Legacy Crestwood Class C units to non-controlling interests(0.1) 0.1 —Distribution for additional interest in Crestwood Marcellus Midstream LLC(129.0) — (129.0)Change in Suburban Propane Partners, L.P. units(0.1) — (0.1)Net income (loss)6.7 (57.3) (50.6)Balance at December 31, 2013$831.6 $4,677.0 $5,508.6The accompanying notes are an integral part of these consolidated financial statements.109Table of ContentsCRESTWOOD EQUITY PARTNERS LP (FORMERLY INERGY, L.P.)CONSOLIDATED STATEMENTS OF CASH FLOWS(in millions) Year Ended December 31, 2013 2012 2011Operating activities Net income (loss)$(50.6) $24.4 $42.1Adjustments to reconcile net income to net cash provided by operating activities: Depreciation, amortization and accretion167.9 73.2 53.9Amortization of debt related deferred costs9.9 5.5 3.5Amortization of bond premium(0.7) — —Market adjustment on interest rate swaps(1.7) — —(Gain) loss on contingent consideration31.4 (6.8) (17.2)Unit-based compensation charges17.4 1.9 0.9Provision for doubtful accounts(1.1) — —Goodwill impairment4.1 — —Gain on long-lived assets(5.3) — (1.1)Loss from unconsolidated affiliates, net0.1 — —Deferred income taxes(2.8) — —Other0.1 (0.2) —Changes in operating assets and liabilities, net of effects from acquisitions: Accounts receivable(39.9) (3.5) (11.7)Inventory(23.6) — —Prepaid expenses and other current assets11.2 0.8 0.2Accounts payable, accrued expenses and other liabilities44.2 6.8 15.7Net liabilities from price risk management activities27.7 — —Net cash provided by operating activities188.3 102.1 86.3 Investing activities Acquisitions, net of cash acquired (Note 4)(555.6) (564.0) (414.1)Purchases of property, plant and equipment(347.0) (52.6) (48.4)Proceeds from sale of assets11.2 — 6.0Investment in unconsolidated affiliates(151.5) — —Net cash used in investing activities(1,042.9) (616.6) (456.5)The accompanying notes are an integral part of these consolidated financial statements. 110Table of ContentsCRESTWOOD EQUITY PARTNERS LP (FORMERLY INERGY, L.P.)CONSOLIDATED STATEMENTS OF CASH FLOWS (continued)(in millions) Year Ended December 31, 2013 2012 2011Financing activities Proceeds from the issuance of Crestwood Equity Partners LP long-term debt$394.1 $— $—Proceeds from the issuance of Inergy Midstream, L.P. long-term debt1,573.4 — —Proceeds from the issuance of Legacy CMLP long-term debt357.5 563.2 415.2Proceeds from the issuance of Crestwood Marcellus Midstream LLC long-term debt141.9 143.5 —Principal payments on Crestwood Equity Partners LP long-term debt(333.3) — —Principal payments on Inergy Midstream, L.P. long-term debt(1,359.3) — —Principal payments on Legacy CMLP long-term debt(200.0) (517.5) (186.2)Principal payments on Crestwood Marcellus Midstream LLC long-term debt(75.0) (16.5) —Contributions from partners— 249.7 8.7Distributions to partners(68.4) (13.8) (5.9)Distributions paid to non-controlling partners(204.5) (89.7) (58.1)Distributions for additional interest in Crestwood Marcellus Midstream LLC(129.0) — —Payments on capital leases(4.3) (3.0) (2.0)Payments for deferred financing costs(33.1) (11.4) (7.0)Payments for deferred acquisition costs— (7.8) —Net proceeds from issuance of Crestwood Midstream Partners LP common units714.0 217.5 53.6Net proceeds from issuance of Crestwood Midstream Partners LP Class C units— — 152.7Proceeds from issuance of preferred equity of subsidiary, net96.1 — —Net proceeds from Crestwood Equity Partners LP common unit options exercised0.1 — —Taxes paid for unit-based compensation vesting(10.5) (0.4) —Net cash provided by financing activities859.7 513.8 371.0 Net increase (decrease) in cash5.1 (0.7) 0.8Cash at beginning of period0.1 0.8 —Cash at end of period$5.2 $0.1 $0.8 Supplemental disclosure of cash flow information Cash paid during the period for interest$64.9 $27.9 $20.3Cash paid during the period for income taxes$2.5 $— $— Supplemental schedule of non-cash investing and financing activities Net change to property, plant and equipment through accounts payable and accrued expenses$(38.0) $(1.7) $3.8 Acquisitions, net of cash acquired: Current assets$409.6 $— $4.0Property, plant and equipment2,487.2 178.0 204.6Intangible assets660.9 384.0 130.2Goodwill2,195.4 4.1 93.6Other assets32.1 — 0.2Current liabilities(420.6) (0.7) (12.5)Debt(1,079.3) — —Invested capital of Crestwood Equity Partners LP, net of debt (Note 4)(3,579.4) — —Other liabilities(150.3) (1.4) (6.0)Total acquisitions, net of cash acquired$555.6 $564.0 $414.1The accompanying notes are an integral part of these consolidated financial statements.111Table of ContentsCRESTWOOD EQUITY PARTNERS LP (FORMERLY INERGY, L.P.)NOTES TO CONSOLIDATED FINANCIAL STATEMENTSNote 1 – Organization and Description of BusinessOrganizationCrestwood Equity Partners LP (formerly known as Inergy, L.P., the “Company” or “CEQP”), a Delaware limited partnership formed in March 2001, is anenergy midstream company. Its common units are listed on NYSE under the symbol “CEQP.” We are managed by our general partner, Crestwood Equity GPLLC (formerly known as Inergy GP, LLC), which is indirectly owned by Crestwood Holdings LLC (“Crestwood Holdings”). Crestwood Holdings issubstantially owned and controlled by First Reserve Management, L.P., an energy-focused private equity fund (“First Reserve”).Between June 19, 2013 and October 7, 2013, we conducted a significant part of our consolidated operations through two publicly-traded master limitedpartnerships, Inergy Midstream, L.P. (“Inergy Midstream” or “NRGM”) and Crestwood Midstream Partners LP (“Legacy Crestwood” or “Legacy CMLP”).These master limited partnerships were managed by their general partners, and we owned the general partners of Inergy Midstream and Legacy Crestwood. Wetherefore managed and controlled Inergy Midstream and Legacy Crestwood.On October 7, 2013, (i) Legacy Crestwood merged with and into a wholly-owned subsidiary of Inergy Midstream (the "Crestwood Merger"), with LegacyCrestwood continuing as the surviving entity; (ii) Legacy Crestwood merged with and into Inergy Midstream, with Inergy Midstream continuing as thesurviving entity; and (iii) Inergy Midstream changed its name to Crestwood Midstream Partners LP ("Crestwood Midstream") and changed its NYSE listingsymbol from “NRGM” to “CMLP.” Concurrently with these transactions, on October 7, 2013, we changed our name from Inergy, L.P. to Crestwood EquityPartners LP and changed our NYSE listing symbol from “NRGY” to “CEQP.” We also changed our principal executive offices to 700 Louisiana Street, Suite2060, Houston, Texas 77002.We own the non-economic general partnership interest of Crestwood Midstream and, consequently, manage and control Crestwood Midstream. As of December31, 2013, we also own approximately 4% of Crestwood Midstream’s limited partnership interests and 100% of its incentive distribution rights (“IDRs”),which entitle us to receive 50% of all distributions paid by Crestwood Midstream in excess of its initial quarterly distribution of $0.37 per common unit.Unless otherwise indicated, references in this report to “we,” “us,” “our,” “ours,” “our company,” the “partnership,” the “Company,” “CEQP,” and similarterms refer to either Crestwood Equity Partners LP itself or Crestwood Equity Partners LP and its consolidated subsidiaries, as the context requires. Unlessotherwise indicated, references to (i) Legacy Inergy refers to either Inergy, L.P. itself or Inergy, L.P. and its consolidated subsidiaries prior to the CrestwoodMerger, (ii) Inergy Midstream and NRGM refer to either Inergy Midstream, L.P. itself or Inergy Midstream, L.P. and its consolidated subsidiaries prior to theCrestwood Merger, (iii) Legacy Crestwood and Legacy CMLP refer to either Crestwood Midstream Partners LP itself or Crestwood Midstream Partners LP andits consolidated subsidiaries prior to the Crestwood Merger, and (iv) Crestwood Midstream refers to Crestwood Midstream Partners LP and its consolidatedsubsidiaries following the Crestwood Merger.Business CombinationOn May 5, 2013, we and certain of our affiliates entered into a series of definitive agreements with Crestwood Holdings and certain of its affiliates underwhich, among other things, (i) we agreed to distribute to our common unitholders all of the NRGM common units owned by us; (ii) Crestwood Holdingsagreed to acquire the owner of our general partner; (iii) Crestwood Holdings agreed to contribute ownership of Legacy CMLP's general partner and IDRs to usin exchange for common and subordinated units; and (iv) Legacy Crestwood agreed to merge with and into a subsidiary of Inergy Midstream in a merger inwhich Legacy CMLP unitholders received 1.07 NRGM common units for each Legacy CMLP common unit they owned and, Legacy CMLP unitholders(other than Crestwood Holdings), received a one-time $34.9 million cash payment at the closing of the Crestwood Merger, or $1.03 per unit, $24.9 million ofwhich was paid by NRGM and $10 million of which was paid by Crestwood Holdings.On June 5, 2013, Legacy Crestwood's general partner distributed to a wholly-owned subsidiary of Crestwood Holdings approximately 137,105 common unitsand approximately 21,588 Class D units of Legacy CMLP, representing all of the Legacy CMLP common and Class D units held by Legacy Crestwood'sgeneral partner.On June 18, 2013, we distributed to our unitholders approximately 56.4 million NRGM common units, representing all of the NRGM common units held byus.112Table of ContentsCRESTWOOD EQUITY PARTNERS LP (FORMERLY INERGY, L.P.)NOTES TO CONSOLIDATED FINANCIAL STATEMENTSOn June 19, 2013, Crestwood Holdings acquired the owner of our general partner and contributed to us ownership of Crestwood Gas Services GP, LLC("Legacy Crestwood GP"), which owned 100% of the general partnership interests and IDRs of Legacy Crestwood. Crestwood Holdings and its ultimate parentcompany, First Reserve, acquired control of us as a result of these transactions.Following the closing of the Crestwood Merger on October 7, 2013, Crestwood Holdings exchanged 7,100,000 common units of Crestwood Midstream for14,300,000 of our common units pursuant to an option granted to Crestwood Holdings when it acquired our general partner.Description of BusinessWe provide gathering, processing, storage and transportation solutions to customers in the crude oil, NGL and natural gas sectors of the energy industry. Ourfinancial statements reflect three operating and reporting segments: (i) gathering and processing; (ii) NGL and crude services; and (iii) storage andtransportation.Our gathering and processing (G&P) operations provide natural gas gathering, processing, treating, compression and transportation services to producers inunconventional shale plays in West Virginia, Wyoming, Texas, Arkansas, New Mexico and Louisiana. The consolidated and unconsolidated assets reflectedin this segment include rich gas gathering systems and processing plants in the Marcellus, Powder River Basin (“PRB”) Niobrara, Barnett, Granite Wash,and Avalon Shale plays, and dry gas gathering systems in the Barnett, Fayetteville, and Haynesville Shale plays.Our NGL and crude services operations provide gathering, storage, transportation, marketing, supply and logistics services to producers, refiners, marketers,and other customers. The consolidated assets reflected in this segment primarily include (i) the COLT Hub, a crude oil rail loading and storage terminallocated in North Dakota, (ii) the Arrow crude oil, natural gas and water gathering systems located on the Fort Berthold Indian Reservation in North Dakota,(iii) our West Coast operations, (iv) a fleet of terminals and over-the-road truck and rail transports, (v) the Bath and Seymour NGL storage facilities in NewYork and Indiana, respectively, and (vi) US Salt, a solution-mining and salt production company in New York.Our storage and transportation operations provide natural gas storage and transportation services to third parties. The consolidated assets reflected in thissegment primarily include natural gas storage facilities in New York and Texas (the Stagecoach, Thomas Corners, Steuben, Seneca Lake and Tres Palaciosstorage facilities), and natural gas transmission facilities in New York and Pennsylvania (the North-South Facilities, the MARC I Pipeline, and the EastPipeline).We own and operate the Tres Palacios natural gas storage facility, an NGL processing and fractionation facility on the West Coast, and an NGL supply andlogistics business (including, without limitation, terminals and fleet). All of our other consolidated assets are owned by or through Crestwood Midstream.Note 2 – Basis of Presentation and Summary of Significant Accounting PoliciesBasis of PresentationOur consolidated financial statements were originally the financial statements of Legacy Crestwood GP, prior to being acquired by us on June 19, 2013 asdiscussed above. The acquisition of Legacy Crestwood GP was accounted for as a reverse acquisition under the purchase method of accounting in accordancewith accounting standards for business combinations. The accounting for a reverse acquisition results in the legal acquiree (Legacy Crestwood GP) being theacquirer for accounting purposes. Although Legacy Crestwood GP was the acquiring entity for accounting purposes, we were the acquiring entity for legalpurposes; consequently, the name on these financial statements was changed from Crestwood Gas Services GP, LLC to Crestwood Equity Partners LP.On June 19, 2013, we changed our fiscal year-end from September 30 to December 31 to adopt the fiscal year of Legacy Crestwood GP.113Table of ContentsCRESTWOOD EQUITY PARTNERS LP (FORMERLY INERGY, L.P.)NOTES TO CONSOLIDATED FINANCIAL STATEMENTSOur consolidated financial statements are prepared in accordance with GAAP and include the accounts of all consolidated subsidiaries after the elimination ofall intercompany accounts and transactions. In management’s opinion, all necessary adjustments to fairly present our results of operation, financial positionand cash flows for the periods presented have been made and all such adjustments are of a normal and recurring nature.Financial Instruments and Price Risk ManagementWe utilize certain derivative financial instruments to (i) manage our exposure to commodity price risk, specifically, the related change in the fair value ofinventory, as well as the variability of cash flows related to forecasted transactions; (ii) ensure adequate physical supply of commodity will be available; and(iii) manage our exposure to the interest rate risk associated with fixed and variable rate borrowings. We record all derivative instruments on the balance sheetas either assets or liabilities measured at fair value. Changes in the fair value of these derivative financial instruments are recorded through current earnings.We did not have any derivatives identified as fair value hedges for accounting purposes or any derivatives designated as cash flow hedges for the years endedDecember 31, 2013, 2012 or 2011.Principles of ConsolidationWe consolidate entities when we have the ability to control or direct the operating and financial decisions of the entity or when we have a significant interest inthe entity that gives us the ability to direct the activities that are significant to that entity. The determination of our ability to control, direct or exert significantinfluence over an entity involves the use of judgment. We apply the equity method of accounting where we can exert significant influence over, but do notcontrol or direct the policies, decisions or activities of an entity. We use the cost method of accounting where we are unable to exert significant influence over theentity.Revenue RecognitionWe gather, treat, compress, store, transport and sell various commodities (including crude oil, natural gas, NGLs and water) pursuant to fixed-fee andpercent-of-proceeds contracts. We recognize revenues for these services and products when all of the following criteria are met:• services have been rendered or products delivered or sold;• persuasive evidence of an exchange arrangement exists;• the price for services is fixed or determinable; and• collectability is reasonably assured.For fixed-fee contracts, we recognize revenues based on the volume of crude oil, natural gas or produced water gathered, processed and treated or compressed,as applicable. For percent-of-proceeds contracts, we recognize revenues based on the value of products sold to third parties.Sales of crude oil, NGLs and salt are recognized at the time product is shipped or delivered to the customer depending on the sales terms. NGL processing andfractionation fees are recognized upon delivery of the product. Revenues from the COLT Hub are recognized when the contractual services are provided, suchas loading of customer rail cars. Revenues from storage and transportation contracts are recognized during the period in which the storage and transportationservices are provided, such as providing storage and transportation services during the period a firm service contract is in place. We record deferred revenuewhen we receive amounts from our customers but have not met the criteria listed above. At December 31, 2013 and 2012, we had deferred revenue ofapproximately $2.1 million and $2.6 million, which is reflected in accrued expenses and other liabilities on our consolidated balance sheets.Credit Risk and ConcentrationsInherent in our contractual portfolio are certain credit risks. Credit risk is the risk of loss from nonperformance by suppliers, customers or financialcounterparties to a contract. We take an active role in managing credit risk and have established control procedures, which are reviewed on an ongoing basis.We attempt to minimize credit risk exposure through credit policies and periodic monitoring procedures as well as through customer deposits, letters of creditand entering into netting agreements that allow for offsetting counterparty receivable and payable balances for certain financial transactions, as deemedappropriate.114Table of ContentsCRESTWOOD EQUITY PARTNERS LP (FORMERLY INERGY, L.P.)NOTES TO CONSOLIDATED FINANCIAL STATEMENTSTwo suppliers, Williams Ohio Valley and PBF Holding Corp., accounted for 14% and 11% of natural gas liquid purchases during 2013. No customer accounted for 10% or more of our total consolidated revenues for the year ended December 31, 2013. For the years ended December 31, 2012 and2011, Quicksilver Resources Inc. ("Quicksilver") accounted for approximately 47% and 64% of our total consolidated revenues. For the year endedDecember 31, 2012, Antero Resources Appalachian Corporation ("Antero") accounted for approximately 11% of our total consolidated revenues. Revenuesfrom Quicksilver and Antero are reflected in our gathering and processing segment.No customer accounted for 10% or more of our consolidated accounts receivable at December 31, 2013. At December 31, 2012, Quicksilver and Anteroaccounted for approximately 48% and 14% of our consolidated accounts receivable.Use of EstimatesThe preparation of consolidated financial statements in conformity with accounting principles generally accepted in the United States requires management tomake estimates and assumptions that affect the reported amount of assets and liabilities and disclosure of contingent assets and liabilities at the date of theconsolidated financial statements and the reported amounts of revenues and expenses during the periods presented. Actual results could differ from thoseestimates.InventoryInventory for our NGL and crude services operations and our storage and transportation operations are stated at the lower of cost or market and are computedpredominantly using the average cost method. Legacy Crestwood GP had no inventory at December 31, 2012.Shipping and Handling CostsShipping and handling costs are recorded as part of cost of product/services sold at the time product is shipped or delivered to the customer.Property, Plant and EquipmentProperty, plant and equipment is recorded at is original cost of construction or, upon acquisition, at the fair value of the assets acquired. For assets weconstruct, we capitalize direct costs, such as labor and materials, and indirect costs, such as overhead and interest. We capitalize major units of propertyreplacements or improvement and expense minor items. Depreciation is computed by the straight-line method over the estimated useful lives of the assets, asfollows: YearsGathering systems and pipelines20Facilities and equipment20 – 25Buildings, rights-of-way and easements20 – 40Office furniture and fixtures5 – 10Vehicles5We deplete salt deposits included in our property, plant and equipment utilizing the unit of production method.When we retire property, plant and equipment, we charge accumulated depreciation for the original costs of the assets in addition to the cost to remove, sell ordispose of the assets, less their salvage value.We evaluate our long-lived assets for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not berecoverable. If such events or changes in circumstances are present, a loss is recognized if the carrying value of the asset is in excess of the sum of theundiscounted cash flows expected to result from the use of the asset and its eventual disposition. An impairment loss is measured as the amount by which thecarrying amount of the asset exceeds the fair value of the asset. We have not identified any indicators that suggest the carrying amount of an asset may not berecoverable as of December 31, 2013.115Table of ContentsCRESTWOOD EQUITY PARTNERS LP (FORMERLY INERGY, L.P.)NOTES TO CONSOLIDATED FINANCIAL STATEMENTSIdentifiable Intangible AssetsWe have recorded certain identifiable intangible assets, including customer accounts, covenants not to compete, trademarks, certain revenue contracts anddeferred financing costs. Customer accounts, covenants not to compete, trademarks and certain of our revenue contracts have arisen from acquisitions. Weamortize certain of our revenue contracts based on the projected cash flows associated with these contracts. Deferred financing costs represent financing costsincurred in obtaining financing and are being amortized over the term of the related debt using the effective interest method. We recognize acquired intangibleassets separately if the benefit of the intangible asset is obtained through contractual or other legal rights, or if the intangible asset can be sold, transferred,licensed, rented or exchanged, regardless of the acquirer's intent to do so.Certain intangible assets are amortized on a straight-line basis over their estimated economic lives, as follows: Weighted-AverageLife(years)Customer accounts12Covenants not to compete4Trademarks6Deferred financing costs6GoodwillOur goodwill represents consideration paid in excess of the fair value of the identifiable assets acquired in a business combination. We evaluate goodwill forimpairment, at a minimum, annually on December 31, or whenever events or changes indicate that it is more likely than not that the fair value of a reportingunit could be less than its carrying amount. This evaluation requires us to compare the fair value of each of our reporting units to its carrying value (includinggoodwill). If the fair value exceeds the book value of a reporting unit, goodwill of the reporting unit is not considered impaired.We estimate the fair value of our reporting units based on a number of factors, including the potential value we would receive if we sold the reporting unit,discount rates and projected cash flows. Estimating projected cash flows requires us to make certain assumptions as it relates to future operating performance.When considering operating performance, various factors are considered such as current and changing economic conditions and the commodity priceenvironment, among others. Due to the imprecise nature of these projections and assumptions, actual results can and often do, differ from our estimates. If thegrowth assumptions embodied in the current year impairment testing prove inaccurate, we could incur an impairment charge. For the year ended December 31, 2013, we recorded an impairment of goodwill of approximately $4.1 million on our Haynesville/Bossier Shale system as aresult of a decrease in anticipated revenues to be generated from those operations due primarily to our inability to renew and extend a significant revenuecontract that expired in mid-2013.Investment in Unconsolidated AffiliatesThe FASB's accounting standards related to equity method investments and joint ventures requires entities to periodically review their equity methodinvestments to determine whether current events or circumstances indicate that the carrying value of the equity method investment may be impaired. Weevaluate our equity method investments for impairment when there are indicators of impairment. If indicators suggest impairment, we will perform animpairment test to assess whether an adjustment is necessary. The impairment test considers whether the fair value of our equity method investments declinedand if any such decline is other than temporary. If a decline in fair value is determined to be other than temporary, the investment's carrying value is writtendown to fair value. No impairment adjustments were recorded in the year ended December 31, 2013.116Table of ContentsCRESTWOOD EQUITY PARTNERS LP (FORMERLY INERGY, L.P.)NOTES TO CONSOLIDATED FINANCIAL STATEMENTSIncome TaxesWe are a master limited partnership. Partnerships are generally not subject to federal income tax, although publicly-traded partnerships are treated ascorporations for federal income tax purposes and therefore are subject to federal income tax, unless the partnership generates at least 90% of its gross incomefrom qualifying sources. If the qualifying income requirement is satisfied, the publicly-traded partnership will be treated as a partnership for federal incometax purposes. We satisfy the qualifying income requirement and are treated as a partnership for federal and state income tax purposes. Our consolidatedearnings are included in the federal and state income tax returns of our partners. However, legislation in certain states allows for taxation of partnerships, andas such, certain state taxes have been included in our accompanying financial statements as income taxes due to the nature of the tax in those particular statesas discussed below. In addition, federal and state income taxes are provided on the earnings of the subsidiaries incorporated as taxable entities. We are requiredto recognize deferred tax assets and liabilities for the expected future tax consequences of events that have been included in the financial statements or taxreturns. Under this method, deferred tax assets and liabilities are determined based on the differences between the financial reporting and tax basis of assetsand liabilities using expected rates in effect for the year in which the differences are expected to reverse.We are responsible for the Texas Margin tax computed on the Texas franchise tax return. The margin tax qualifies as an income tax under GAAP, whichrequires us to recognize the impact of this tax on the temporary differences between the financial statement assets and liabilities and their tax basis attributableto such tax. For the years ended December 31, 2013, 2012 and 2011, there were no temporary differences recognized in our consolidated statements ofoperations.Net earnings for financial statement purposes may differ significantly from taxable income reportable to unitholders as a result of differences between the taxbasis and the financial reporting basis of assets and liabilities and the taxable income allocation requirements under the partnership agreement.Sales TaxWe account for the collection and remittance of sales tax on a net tax basis. As a result, these amounts are not reflected in the consolidated statements ofoperations.Cash and Cash EquivalentsWe define cash equivalents as all highly liquid investments with maturities of three months or less when purchased.Asset Retirement ObligationsAn asset retirement obligation ("ARO") is an estimated liability for the cost to retire a tangible asset. We record a liability for legal or contractual obligations toretire our long-lived assets associated with right-of-way contracts we hold and our facilities whether owned or leased. We record a liability in the period theobligation is incurred and estimable. An ARO is initially recorded at its estimated fair value with a corresponding increase to property, plant and equipment.This increase in property, plant and equipment is then depreciated over the useful life of the asset to which that liability relates. An ongoing expense isrecognized for changes in the fair value of the liability as a result of the passage of time, which we record as depreciation, amortization and accretion expenseon our consolidated statements of operations. The fair value of certain AROs could not be determined as the settlement dates (or range of dates) associated withthese assets were not estimable. At December 31, 2013 and 2012, our AROs were reflected in other long-term liabilities on our consolidated balance sheets. SeeNote 14 for a discussion of our AROs.Environmental Costs and Other ContingenciesWe recognize liabilities for environmental and other contingencies when it has an exposure that indicates it is both probable that a liability has been incurredand the amount of loss can be reasonably estimated. Where the most likely outcome of a contingency can be reasonably estimated, we accrue a liability for thatamount. Where the most likely outcome cannot be estimated, a range of potential losses is established and if no one amount in that range is more likely thanany other, the low end of range is accrued.117Table of ContentsCRESTWOOD EQUITY PARTNERS LP (FORMERLY INERGY, L.P.)NOTES TO CONSOLIDATED FINANCIAL STATEMENTSWe record liabilities for environmental contingencies at their undiscounted amounts on our consolidated balance sheets as accrued expenses and other liabilitieswhen environmental assessments indicate that remediation efforts are probable and costs can be reasonably estimated. Estimates of our liabilities are based oncurrently available facts and presently enacted laws and regulations, taking into consideration the likely effects of other societal and economic factors. Theseestimates are subject to revision in future periods based on actual costs or new circumstances. We capitalize costs that benefit future periods and recognize acurrent period charge in operating and administrative expenses when clean-up efforts do not benefit future periods.We evaluate potential recoveries of amounts from third parties, including insurance coverage, separately from our liability. Recovery is evaluated based on thesolvency of the third party, among other factors. When recovery is assured, we record and report an asset separately from the associated liability on ourconsolidated balance sheet.Unit-Based CompensationUnit-based compensation awards are valued at the closing market price of our common units on the date of grant, which reflects the fair value of such awards.For those awards that are settled in cash, the associated liability is remeasured at every balance sheet date through settlement, such that the vested portion of theliability is adjusted to reflect its revised fair value through compensation expense. We generally recognize the expense associated with the award over the vestingperiod. Prior to the Crestwood Merger, Legacy Crestwood issued phantom units under its Fourth Amended and Restated 2007 Equity Plan ("2007 EquityPlan"). At the time of issuance of these phantom units, management of the general partner of Legacy Crestwood determined whether they were settled in cash orsettled in common units. The 2007 Equity Plan was terminated in conjunction with the Crestwood Merger. Unit-based compensation awards at CrestwoodMidstream are fully reflected in these financial statements and are accounted for in the manner described above. See Note 12 for a further discussion of ourequity plans including the Legacy Inergy and Inergy Midstream plans.Segment InformationThere are certain accounting requirements that establish standards for reporting information about operating segments, as well as related disclosures aboutproducts and services, geographic areas and major customers. Further, they define operating segments as components of an enterprise for which separatefinancial information is available that is evaluated regularly by the chief operating decision maker in deciding how to allocate resources and assessperformance. In determining our operating segments, we examine the way we organize our business internally for making operating decisions and assessingbusiness performance. See Note 17 for disclosures related to our three operating and reporting segments.Note 3 – Certain Balance Sheet InformationInventoryInventory consisted of the following at December 31, 2013 (in millions). Legacy Crestwood GP did not have inventory at December 31, 2012. December 31, 2013NGLs$66.9Parts, supplies and other6.7Total inventory$73.6118Table of ContentsCRESTWOOD EQUITY PARTNERS LP (FORMERLY INERGY, L.P.)NOTES TO CONSOLIDATED FINANCIAL STATEMENTSProperty, Plant and EquipmentProperty, plant and equipment consisted of the following at December 31, 2013 and 2012 (in millions): December 31, 2013 2012Gathering systems and pipelines$1,473.4 $582.3Facilities and equipment1,186.5 485.8Buildings, rights-of-way and easements86.3 66.4Land and storage rights728.4 4.1Vehicles35.8 0.3Construction in process365.8 56.0Base gas102.0 —Salt deposits120.5 —Office furniture and fixtures10.0 2.5 4,108.7 1,197.4Less: accumulated depreciation and depletion203.4 95.0Total property, plant and equipment, net$3,905.3 $1,102.4Depreciation. Depreciation expense totaled $109.9 million, $49.1 million and $39.1 million for the years ended December 31, 2013, 2012 and 2011.Depletion expense totaled $0.4 million for the year ended December 31, 2013. Legacy Crestwood GP did not have any depletion expense.Capitalized Interest. At December 31, 2013 and 2012, we capitalized interest of $3.4 million and $0.2 million related to certain expansion projects.Capital Leases. We have a compressor station, treating facility and certain auto leases which are accounted for as capital leases. Our compressor station andtreating facility leases are reflected in facilities and equipment in the above table. We had capital lease assets of $5.0 million and $7.1 million included inproperty, plant and equipment at December 31, 2013 and 2012.Impairment. During the year ended December 31, 2012, we recorded an impairment of $1.6 million of our property, plant and equipment to write certain ofour assets down to their fair value of zero (which is a Level 3 fair value measurement as discussed in Note 7) as a result of a compressor building fire thatoccurred on September 6, 2012 at our Corvette processing plant. This impairment, in addition to $1.3 million of other operating and administrative costsincurred related to the incident, is recoverable under our insurance policies and is recorded in prepaid expenses and other current assets on our December 31,2012 balance sheet. During the year ended December 31, 2013, we received the insurance proceeds and we recorded a gain of approximately $1.0 millionrelated to the proceeds received in excess of the book value of our assets at the facility. At December 31, 2012, our insurance receivable related to this matterwas $2.9 million.Gain on Long-Lived Assets. During the year ended December 31, 2013, we recorded a gain of approximately $4.4 million on the sale of a cryogenic plant andassociated equipment.During the year ended December 31, 2011, we recorded a gain of $1.1 million on the exchange of property, plant and equipment under an agreement with athird party to exchange the delivery of certain processing plants that were under contract. We received proceeds of $6.0 million on the exchange.119Table of ContentsCRESTWOOD EQUITY PARTNERS LP (FORMERLY INERGY, L.P.)NOTES TO CONSOLIDATED FINANCIAL STATEMENTSIntangible AssetsIntangible assets consisted of the following at December 31, 2013 and 2012 (in millions): December 31, 2013 2012Customer accounts$576.9 $—(accumulated amortization—customer accounts)(18.7) —Covenants not to compete7.0 —(accumulated amortization—covenants not to compete)(1.0) —Gas gathering, compression and processing contracts750.2 813.0(accumulated amortization - gas gathering, compression and processing contracts)(67.3) (40.2)Acquired storage contracts43.5 —(accumulated amortization - acquired storage contracts)(8.6) —Trademarks33.5 —(accumulated amortization - trademarks)(2.3) —Deferred financing and other costs55.3 32.2(accumulated amortization—deferred financing costs)(8.1) (9.7)Total intangible assets, net$1,360.4 $795.3Amortization and interest expense associated with our intangible assets described above for the years ended December 31, 2013, 2012 and 2011, wasapproximately $66.7 million, $28.9 million and $17.8 million.Estimated amortization on our intangibles for the next five years is as follows (in millions):Year EndingDecember 31, 2014$107.82015108.0201696.6201786.3201875.8 Accrued Expenses and Other LiabilitiesAccrued expenses and other liabilities consisted of the following at December 31, 2013 and 2012 (in millions): December 31, 2013 2012Accrued expenses$40.3 $9.6Accrued property taxes9.4 5.6Accrued product purchases payable1.6 2.5Tax payable14.8 2.2Interest payable16.7 7.5Accrued additions to property, plant and equipment58.2 9.2Commitments and contingent liabilities (Note 15)31.4 —Capital leases2.6 3.9Deferred revenue2.1 2.6Total accrued expenses and other liabilities$177.1 $43.1120Table of ContentsCRESTWOOD EQUITY PARTNERS LP (FORMERLY INERGY, L.P.)NOTES TO CONSOLIDATED FINANCIAL STATEMENTSNote 4 – Acquisitions2013 AcquisitionsCrestwood MergerAs described in Note 1, the acquisition of Legacy Crestwood GP was accounted for as a reverse merger under the purchase method of accounting inaccordance with the accounting standards for business combinations. This accounting treatment requires the accounting acquiree (CEQP) to have its assetsand liabilities stated at fair value as well as any other purchase accounting adjustments as of June 19, 2013, the date of the acquisition. The fair value ofCEQP was calculated based on the consolidated enterprise fair value of CEQP as of June 19, 2013. This consolidated enterprise fair value considered thediscounted future cash flows of the Legacy Inergy and Inergy Midstream operations and the stock prices of CEQP and NRGM, the value of their outstandingsenior notes based on quoted market prices for same or similar issuances and the value of their outstanding floating rate debt.The following table summarizes the preliminary fair values of the assets acquired and liabilities assumed at the merger date (in millions):Current assets$224.5Property, plant and equipment2,088.2Intangible assets337.5Other assets12.7Total identifiable assets acquired2,662.9 Current liabilities207.5Long-term debt1,079.3Other long-term liabilities146.6Total liabilities assumed1,433.4 Net identifiable assets acquired1,229.5Goodwill2,149.9Net assets acquired$3,379.4Of the $2,149.9 million of goodwill, $1,213.4 million is reflected in our NGL and crude services segment and $936.5 million is reflected in our storage andtransportation segment. Goodwill recognized relates primarily to synergies and new expansion opportunities expected to result from the combination of LegacyCrestwood and Inergy Midstream. The purchase price allocation has been prepared on a preliminary basis pending receipt of a final valuation report and issubject to material change.Included in other long-term liabilities is a market adjustment of approximately $100 million for the value of the Tres Palacios lease of the surface andsubsurface rights (see Note 15).During the year ended December 31, 2013, we recognized $916.7 million of operating revenues and $23.9 million of operating income related to thisacquisition.Arrow AcquisitionOn November 8, 2013, Crestwood Midstream acquired Arrow Midstream Holdings, LLC ("Arrow"), a privately-held midstream company, forapproximately $750 million, subject to customary capital expenditure and working capital adjustments of approximately $12.8 million. The acquisition wasconsummated by merging a wholly-owned subsidiary of Crestwood Midstream with and into Arrow (the “Arrow Acquisition”), with Arrow continuing as thesurviving entity and a wholly-owned subsidiary of Crestwood Midstream. The base merger consideration consisted of $550 million in cash and 8,826,125common units of Crestwood Midstream issued to the sellers, subject to adjustment for standard working capital provisions.121Table of ContentsCRESTWOOD EQUITY PARTNERS LP (FORMERLY INERGY, L.P.)NOTES TO CONSOLIDATED FINANCIAL STATEMENTSArrow, through its wholly-owned subsidiaries, owns and operates substantial crude oil, natural gas and water gathering systems located on the Fort BertholdIndian Reservation in the core of the Bakken Shale in McKenzie and Dunn Counties, North Dakota. Arrow also owns salt water disposal wells and a 23-acrecentral delivery point with multiple pipeline take-away outlets and a fully-automated truck loading facility.The following table summarizes the preliminary fair values of the assets acquired and liabilities assumed at the acquisition date (in millions):Current assets$192.3Property, plant and equipment399.0Intangible assets323.4Other assets19.4Total identifiable assets acquired934.1 Current liabilities213.1Other long-term liabilities3.7Total liabilities assumed216.8 Net identifiable assets acquired717.3Goodwill45.5Net assets acquired$762.8The $45.5 million of goodwill is reflected in our NGL and crude services segment. Goodwill recognized relates primarily to anticipated operating synergiesbetween the assets acquired and our existing assets. The purchase price allocation has been prepared on a preliminary basis pending receipt of a finalvaluation report and is subject to material change.During the year ended December 31, 2013, we recognized $218.8 million of operating revenues and $1.7 million of operating income related to thisacquisition.2012 AcquisitionsAntero AcquisitionOn March 26, 2012, Crestwood Marcellus Midstream LLC ("CMM") acquired from Antero gathering assets located in Harrison and Doddridge Counties,West Virginia (the "Antero Acquisition") for approximately $376.8 million. The acquired assets consisted of a 33-mile low-pressure gathering system thatdelivers Antero’s Marcellus Shale production to various regional pipeline systems and MarkWest Energy Partners’ Sherwood Gas Processing Plant.In connection with the Antero Acquisition, Legacy Crestwood agreed to pay Antero conditional consideration in the form of potential additional cash paymentsof up to $40 million, depending on the achievement of certain defined average annual production levels achieved during 2012, 2013 and 2014. During 2012and 2013, Antero did not meet the annual production level to earn additional payments. Based on our estimates of Antero’s 2014 production, we believe theirproduction levels will likely exceed the annual production threshold in the earn-out provision and accordingly, we have recognized a $31.4 million liability asof December 31, 2013 that represents the fair value of the potential payments that may be made under this earn-out provision. We estimated the liability basedon the probability-weighted discounted cash flows using a 5.9% discount rate and our estimate of Antero’s production in 2014 (a Level 3 fair valuemeasurement).Upon the closing of the Antero Acquisition, CMM entered into a 20-year fixed-fee, Gas Gathering and Compression Agreement ("GGA") with Antero. TheGGA provided for an area of dedication of approximately 127,000 gross acres, or 104,000 net acres, largely located in the rich gas corridor of the southwesterncore of the Marcellus Shale play. Under the GGA, Antero committed to deliver minimum annual throughput volumes to us for a seven year period fromJanuary 1, 2012 to January 1, 2019, ranging from an average of 300 MMcf/d in 2012 to an average of 450 MMcf/d in 2018. During the period endedDecember 31, 2012, Antero delivered less than the minimum annual throughput volumes and at December 31, 2012, we recorded a receivable and122Table of ContentsCRESTWOOD EQUITY PARTNERS LP (FORMERLY INERGY, L.P.)NOTES TO CONSOLIDATED FINANCIAL STATEMENTSdeferred revenue of approximately $2.6 million due to Antero’s potential ability to recover this amount if Antero’s 2013 throughput volumes exceeded theminimum annual throughput volumes included in the GGA for 2013. In the first quarter of 2013, Antero paid us approximately $2.4 million to satisfy theirminimum volume commitment. For the year ended December 31, 2013, Antero's throughput volumes exceeded the 2013 minimum thresholds and wassufficient to recover their 2012 minimum volume shortfall that was previously paid. As a result of Antero's recovery of their 2012 shortfall, we reclassifiedapproximately $2.4 million from deferred revenue to other accounts payable at December 31, 2013 to reflect the amount we owe to Antero. We reflect deferredrevenue and other accounts payable as accrued expenses and other liabilities on our consolidated balance sheets. See Note 15 for additional information relatedto our Antero Acquisition.Devon AcquisitionOn August 24, 2012, we acquired certain gathering and processing assets in the NGL rich gas region of the Barnett Shale (the "Devon Acquisition") fromDevon Energy Corporation ("Devon"). We paid approximately $87.3 million for these assets. During the year ended December 31, 2013, we finalized thepurchase price allocation of the assets acquired and liabilities assumed, and as a result, we reduced our depreciation, amortization and accretion expense byapproximately $2.2 million.The final purchase price allocation is as follows (in millions):Cash$87.9Total purchase price$87.9Purchase price allocation: Property, plant and equipment$88.6Total assets88.6Asset retirement obligation0.5Environmental liability0.2Total liabilities0.7Total$87.9We believe that it is impracticable to present financial information for the acquired assets prior to the acquisition date due to the lack of availability ofhistorical financial information related to the acquired assets, and because the 20-year fixed-fee gathering, processing and compression agreement with Devonhas significantly different terms than the historical intercompany relationships between the acquired assets and Devon.EMAC AcquisitionOn December 28, 2012, CMM acquired all of the membership interest of E. Marcellus Asset Company, LLC ("EMAC") from Enerven Compression, LLC("Enerven") for approximately $95.0 million. We financed this acquisition through CMM's credit facility. At the time of acquisition, EMAC’s assetsconsisted of four compression and dehydration stations located on our gathering systems in Harrison County, West Virginia. These assets providecompression and dehydration services to Antero under a compression services agreement through 2018. Antero has the option to renew the agreement for anadditional five years upon expiration of the original agreement.During the year ended December 31, 2013, we finalized the purchase price allocation of the assets acquired and liabilities assumed, and as a result, wereduced our depreciation, amortization and accretion expense by approximately $0.7 million. In addition, we recognized goodwill of approximately $8.6million, primarily related to anticipated operating synergies between the assets acquired and our existing assets. 123Table of ContentsCRESTWOOD EQUITY PARTNERS LP (FORMERLY INERGY, L.P.)NOTES TO CONSOLIDATED FINANCIAL STATEMENTSThe final purchase price allocation is as follows (in millions):Cash$95.0Total purchase price$95.0Purchase price allocation: Property, plant and equipment$53.4Intangible assets33.9Goodwill8.6Total assets95.9Asset retirement obligation0.8Environmental liability0.1Total liabilities0.9Total$95.0Our intangible assets recorded as a result of the EMAC acquisition relate to the compression services agreements with Antero. These intangibles will beamortized over the life of the contracts. The financial results of EMAC prior to the date of acquisition were not material to our results of operations, therefore,pro forma information has not been provided.2011 AcquisitionsLas Animas AcquisitionOn February 16, 2011, we acquired certain midstream assets in the Avalon Shale trend from a group of independent producers for approximately $5.1million (the "Las Animas Acquisition"). The acquired assets included approximately 46 miles of natural gas gathering pipeline located in the Morrow/Atokatrend and the Avalon Shale trend in southeastern New Mexico. The pipelines are supported by long-term fixed-fee contracts which include existingMorrow/Atoka production and dedications of approximately 55,000 acres.During the year ended December 31, 2011, we recognized approximately $4.8 million of operating revenues and $0.1 million of operating income related to thisacquisition.Frontier Gas AcquisitionOn April 1, 2011, we acquired certain midstream assets in the Fayetteville Shale and the Granite Wash from Frontier Gas Services, LLC for approximately$344.6 million (the "Frontier Gas Acquisition"). We financed $338.1 million of the purchase price through a combination of equity and debt as described inNote 9 and Note 11.The acquired Fayetteville assets included approximately 130 miles of high pressure and low pressure gathering pipelines in northwestern Arkansas withcapacity of approximately 510 MMcf/d, treating capacity of approximately 165 MMcf/d and approximately 35,000 hp compression (the "FayettevilleSystem"). The Fayetteville System interconnects with multiple interstate pipelines and is supported by long-term fixed-fee contracts with producers whodedicated to us approximately 100,000 acres in the core of the Fayetteville Shale. These contracts have initial terms that extend through 2020 and include anoption, by either party to the contract, to extend the contract through 2025. The acquired Granite Wash assets included a 28-mile pipeline system and a 36MMcf/d cryogenic processing plant in the Texas Panhandle (the "Granite Wash System"). The Granite Wash System is supported by more than 13,000dedicated acres and long-term contracts with initial terms extending through 2022.During the year ended December 31, 2011, we recognized approximately $59.0 million in operating revenues and $5.4 million in operating income related tothis acquisition.124Table of ContentsCRESTWOOD EQUITY PARTNERS LP (FORMERLY INERGY, L.P.)NOTES TO CONSOLIDATED FINANCIAL STATEMENTSTristate AcquisitionOn November 1, 2011, we acquired Tristate Sabine, LLC ("Tristate") from affiliates of Energy Spectrum Capital, Zwolle Pipeline, LLC and Tristate’smanagement for approximately $72.4 million. We paid $64.4 million in cash at the closing, and we made a deferred payment of approximately $8.0 million inthe fourth quarter of 2012.At the time of acquisition, the Tristate assets located in Haynesville/Bossier Shale consisted of approximately 60 miles of high pressure and low pressuregathering pipelines with capacity of approximately 100 MMcf/d and treating capacity of approximately 80 MMcf/d (collectively, the "Sabine System"). TheSabine System is supported by long-term, fixed-fee contracts with producers who dedicated approximately 20,000 acres to us. These contracts have variousinitial terms that extend through 2019 and 2021.During the year ended December 31, 2011, we recognized approximately $1.9 million in operating revenues and $0.9 million in operating income related tothis acquisition.Unaudited Pro Forma InformationThe following table represents the pro forma consolidated statements of operations as if the Legacy Inergy reverse acquisition and Arrow acquisition had beenincluded in our consolidated results for the years ended December 31, 2012 and 2011 and for the entire year ended December 31, 2013, and if the results ofoperations for the 2011 acquisitions had been included for the entire year ended December 31, 2011 (in millions, except per unit information). All otheracquisitions were immaterial in consolidation. Pro Forma Consolidated Statement of Operations (Unaudited) Year Ended December 31, 2013 2012 (a) 2011 (a)Revenues$3,449.3 $2,267.2 $1,713.7Net income (loss)$3.9 $49.8 $(35.0) Net income (loss) per limited partner unit(b): Basic$0.04 $0.31 $(0.25)Diluted$0.04 $0.29 $(0.25)(a)The years ended December 31, 2012 and 2011 have also been adjusted to reflect the contribution of Inergy, L.P.'s retail operations to Suburban Propane Partners on August1, 2012 and the subsequent distribution on September 14, 2012 of 99% of the Suburban Propane Partners LP units acquired in the contribution as if that contribution andsubsequent distribution had been removed from the consolidated results of operations at the beginning of each period presented.(b) Basic and diluted net income per limited partner unit for the years ended December 31, 2012 and 2011 were computed based on the presumption that the common andsubordinated units issued to acquire Legacy Crestwood GP (the accounting predecessor) were outstanding for the entire period prior to the June 19, 2013 acquisition.These amounts have been calculated after applying our accounting policies and adjusting the results of the acquisitions to reflect the depreciation andamortization that would have been charged assuming the preliminary fair value adjustments to property, plant and equipment and intangible assets had beenmade at the beginning of the respective reporting period. The purchase price allocation for the reverse acquisition of Legacy Inergy and Arrow acquisition hasbeen prepared on a preliminary basis pending final asset valuation and asset rationalization, and changes are expected when additional information becomesavailable. Accordingly, the purchase accounting adjustments made in connection with the development of the unaudited pro forma are preliminary and subjectto change.125Table of ContentsCRESTWOOD EQUITY PARTNERS LP (FORMERLY INERGY, L.P.)NOTES TO CONSOLIDATED FINANCIAL STATEMENTSNote 5 - Investments in Unconsolidated AffiliatesJackalope Gas Gathering Services, L.L.C.On July 19, 2013, Crestwood Niobrara LLC ("Crestwood Niobrara"), our consolidated subsidiary, acquired from RKI Exploration and Production, LLC’s("RKI") a 50% ownership interest in Jackalope Gas Gathering Services, L.L.C. (“Jackalope”) for approximately $107.5 million. RKI is a privately-owned,independent exploration and production company in which an affiliate of Crestwood Holdings owns a significant minority ownership interest, and therefore isconsidered our related party. Access Midstream Partners, L.P. ("Access") operates and owns the remaining 50% interest in Jackalope. Crestwood Niobraramanages the commercial operations of the Jackalope system, and we account for our investment in Jackalope under the equity method of accounting.Jackalope is developing a gathering and processing system to serve producers in and around Converse County, Wyoming. The Jackalope system and plannedfuture development are supported by a 20-year gathering and processing agreement with Chesapeake Energy Corporation and RKI under an area of dedicationof approximately 311,000 gross acres located in the core of the PRB Niobrara. During the year ended December 31, 2013, Crestwood Niobrara contributed anadditional $19.6 million to Jackalope to fund its construction projects.We have reflected the earnings from our investment in Jackalope in our consolidated statements of income, which includes our share of net earnings based onour ownership interest and other adjustments recorded by us as discussed below. During the year ended December 31, 2013, our share of Jackalope’s netearnings was approximately $1.5 million. As of December 31, 2013, our investment balance in Jackalope exceeded our equity in the underlying net assets ofJackalope by approximately $56.8 million. We amortize and generally assess the recoverability of this amount based on the life of Jackalope’s gatheringagreement with Chesapeake and RKI. The amortization is reflected as reduction of our earnings from unconsolidated affiliates, and during the year endedDecember 31, 2013, we recorded amortization expense of approximately $1.4 million.Jackalope is required to make quarterly distributions of its available cash to its members based on their respective ownership percentage. During the yearended December 31, 2013, Jackalope did not make any distributions to its members.Our Jackalope investment is in included in our gathering and processing segment.Powder River Basin Industrial Complex, LLCOn September 4, 2013, Crestwood Crude Logistics LLC ("Crude Logistics") and Enserco Midstream, LLC formed Powder River Basin Industrial Complex,LLC (“PRBIC”) to construct, own and operate an early-stage crude oil rail terminal located in Douglas County, Wyoming (the “Douglas Facility”). TheDouglas Facility, which is located in the emerging PRB Niobrara Shale play, is anchored by a long-term agreement with a major producer for the throughputof crude oil volumes through the terminal. The Douglas Facility was placed into manifest service in August 2013, and unit train service is expected to beginduring the first quarter of 2014. Crude Logistics paid approximately $22.5 million to acquire a 50.01% interest in PRBIC and invested approximately $1.9million in PRBIC in 2013 since acquiring its equity interest. We account for our investment in PRBIC under the equity method of accounting.Our investment in PRBIC was $24.2 million at December 31, 2013. During the year ended December 31, 2013, our share of PRBIC’s earnings wereapproximately $(0.2) million. As of December 31, 2013, our investment balance in PRBIC approximated our equity in the underlying net assets of PRBIC.PRBIC is required to make quarterly distributions of its available cash to its members based on their respective ownership percentage. During the year endedDecember 31, 2013, PRBIC did not make any distributions to its members.Our PRBIC investment is in included in our NGL and crude services segment.126Table of ContentsCRESTWOOD EQUITY PARTNERS LP (FORMERLY INERGY, L.P.)NOTES TO CONSOLIDATED FINANCIAL STATEMENTSNote 6 – Risk ManagementWe are exposed to certain market risks related to our ongoing business operations. These risks include exposure to changing commodity prices as well asfluctuations in interest rates. We utilize derivative instruments to manage our exposure to fluctuations in commodity prices, which is discussed below. We alsoperiodically utilize derivative instruments to manage our exposure to fluctuations in interest rates, which is discussed in Note 9. Additional information relatedto our derivatives is discussed in Note 2 and Note 7.Commodity Derivative Instruments and Price Risk ManagementRisk Management ActivitiesWe sell NGLs to energy related businesses and may use a variety of financial and other instruments including forward contracts involving physical deliveryof NGLs. We will periodically enter into offsetting positions to economically hedge against the exposure our customer contracts create, however we do notdesignate these instruments as hedging instruments for accounting purposes. These instruments are marked to market with the changes in the market valuereflected in costs of product/services sold. At December 31, 2013, the amount of these derivatives in costs of product/services sold was $10.7 million. Weattempt to balance our contractual portfolio in terms of notional amounts and timing of performance and delivery obligations. This balance in the contractualportfolio significantly reduces the volatility in costs of product/services sold related to these instruments.Commodity Price and Credit RiskNotional Amounts and TermsThe notional amounts and terms of our derivative financial instruments include the following at December 31, 2013 (in millions): December 31, 2013 Fixed PricePayor Fixed PriceReceiverPropane, crude and heating oil (barrels)5.6 6.8Notional amounts reflect the volume of transactions, but do not represent the amounts exchanged by the parties to the financial instruments. Accordingly,notional amounts do not reflect our monetary exposure to market or credit risks.All contracts subject to price risk had a maturity of thirty-six months or less; however, 97.4% of the contracts expire within twelve months.Credit RiskInherent in our contractual portfolio are certain credit risks. Credit risk is the risk of loss from nonperformance by suppliers, customers or financialcounterparties to a contract. We take an active role in managing credit risk and have established control procedures, which are reviewed on an ongoing basis.We attempt to minimize credit risk exposure through credit policies and periodic monitoring procedures as well as through customer deposits, letters of creditand entering into netting agreements that allow for offsetting counterparty receivable and payable balances for certain financial transactions, as deemedappropriate. The counterparties associated with assets from price risk management activities as of December 31, 2013 were energy marketers and propaneretailers, resellers and dealers. There were no activities associated with assets from price risk management at December 31, 2012.127Table of ContentsCRESTWOOD EQUITY PARTNERS LP (FORMERLY INERGY, L.P.)NOTES TO CONSOLIDATED FINANCIAL STATEMENTSCertain of our derivative instruments have credit limits that require us to post collateral. The amount of collateral required to be posted is a function of the netliability position of the derivative as well as our established credit limit with the respective counterparty. If our credit rating were to change, the counterpartiescould require us to post additional collateral. The amount of additional collateral that would be required to be posted would vary depending on the extent ofchange in our credit rating as well as the requirements of the individual counterparty. The aggregate fair value of all commodity derivative instruments withcredit-risk-related contingent features that are in a liability position on December 31, 2013, is $16.6 million for which we have posted $2.6 million ofcollateral in the normal course of business. We have posted $3.6 million of NYMEX margin deposits in the normal course of business. We have receivedcollateral of $5.9 million in the normal course of business. All collateral amounts have been netted against the asset or liability with the respectivecounterparty.Note 7 – Fair Value MeasurementsThe accounting standard for fair value measurement establishes a three-tier fair value hierarchy, which prioritizes the inputs used in measuring fair value. Thehierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (level 1 measurement) and the lowest priorityto unobservable inputs (level 3 measurement). The three levels of the fair value hierarchy are as follows:•Level 1—Quoted prices are available in active markets for identical assets or liabilities as of the reporting date. Active markets are those in whichtransactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Level 1 primarilyconsists of financial instruments such as exchange-traded derivatives, listed equities and US government treasury securities.•Level 2—Pricing inputs are other than quoted prices in active markets included in level 1, which are either directly or indirectly observable as of thereporting date. Level 2 includes those financial instruments that are valued using models or other valuation methodologies. These models are primarilyindustry-standard models that consider various assumptions, including quoted forward prices for commodities, time value, volatility factors, andcurrent market and contractual prices for the underlying instruments, as well as other relevant economic measures. Substantially all of theseassumptions are observable in the marketplace throughout the full term of the instrument, can be derived from observable data or are supported byobservable levels at which transactions are executed in the marketplace. Instruments in this category include non-exchange-traded derivatives such asover the counter (“OTC”) forwards, options and physical exchanges.•Level 3—Pricing inputs include significant inputs that are generally less observable from objective sources. These inputs may be used with internallydeveloped methodologies that result in management’s best estimate of fair value.Cash and Cash Equivalents, Accounts Receivable and Accounts PayableAs of December 31, 2013 and December 31, 2012, the carrying amounts of cash and cash equivalents, accounts receivable (net of allowance for doubtfulaccounts) and accounts payable represent fair value based on their short-term nature.Notes Payable and Other ObligationsAs of December 31, 2013, the carrying value and fair value of our notes payable and other obligations are approximately the same due to the imputed interestrate being reset as a result of the reverse merger. Legacy Crestwood GP did not have a balance in notes payable and other obligations at December 31, 2012.Credit FacilitiesThe fair value of our credit facilities approximates their carrying amounts as of December 31, 2013 and December 31, 2012, due primarily to the variablenature of the interest rates of the instruments.128Table of ContentsCRESTWOOD EQUITY PARTNERS LP (FORMERLY INERGY, L.P.)NOTES TO CONSOLIDATED FINANCIAL STATEMENTSSenior NotesWe estimate the fair value of our senior notes primarily based on quoted market prices for the same or similar issuances. This valuation methodology isconsidered level 2 in the fair value hierarchy. The following table reflects the carrying value and fair value of the senior notes (in millions): December 31, 2013 December 31, 2012 Carrying Amount FairValue Carrying Amount Fair ValueCEQP senior unsecured notes$11.4 $11.6 $— $—Crestwood Midstream 2022 senior unsecured notes$600.0 $617.3—$— $—Crestwood Midstream 2019 senior unsecured notes$351.2 $379.3 $351.5 $365.9Crestwood Midstream 2020 senior unsecured notes$504.7 $513.8 $— $—Assets and LiabilitiesAs of December 31, 2013, we held certain assets and liabilities that are required to be measured at fair value on a recurring basis, which include our derivativeinstruments related to heating oil, crude oil, NGLs and interest rates. Our derivative instruments consist of forwards, swaps, futures, physical exchanges andoptions.Certain of our derivative instruments are traded on the NYMEX. These instruments have been categorized as level 1.Our derivative instruments also include OTC contracts, which are not traded on a public exchange. The fair values of these derivative instruments aredetermined based on inputs that are readily available in public markets or can be derived from information available in publicly quoted markets. Theseinstruments have been categorized as level 2.Our OTC options are valued based on the Black Scholes option pricing model that considers time value and volatility of the underlying commodity. Theinputs utilized in the model are based on publicly available information as well as broker quotes. These options have been categorized as level 2.The assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. The assessment ofthe significance of a particular input to the fair value measurement requires judgment, and may affect the valuation of fair value assets and liabilities and theirplacement within the fair value hierarchy levels.129Table of ContentsCRESTWOOD EQUITY PARTNERS LP (FORMERLY INERGY, L.P.)NOTES TO CONSOLIDATED FINANCIAL STATEMENTSThe following tables set forth by level within the fair value hierarchy, our assets and liabilities that were accounted for at fair value on a recurring basis atDecember 31, 2013 (in millions): December 31, 2013 Fair Value of Derivatives Level 1 Level 2 Level 3 Total NettingAgreements(a) TotalAssets Assets from price risk management$0.3 $27.7 $— $28.0 $(13.5) $14.5SPH units6.7 — — 6.7 — 6.7Total assets at fair value$7.0 $27.7 $— $34.7 $(13.5) $21.2 Liabilities Liabilities from price risk management$0.1 $39.5 $— $39.6 $(4.7) $34.9Interest rate swaps— 4.3 — 4.3 — 4.3Total liabilities at fair value$0.1 $43.8 $— $43.9 $(4.7) $39.2(a) Amounts represent the impact of legally enforceable master netting agreements that allow us to settle positive and negative positions as well as cash collateral held or placed with thesame counterparties.Legacy Crestwood GP had no assets or liabilities recorded at fair value at December 31, 2012.Note 8 - Earnings Per Limited Partner UnitWe own a non-economic general partnership interest and 100% of the IDRs in Crestwood Midstream. The general partner of Legacy Crestwood held generalpartner units and owned 100% of the IDRs of Legacy Crestwood and therefore, was allocated a portion of Legacy Crestwood’s net income based on itsownership interest after giving effect to the IDRs earned. Subsequent to the Crestwood Merger, net income attributable to the limited partners is determined byfirst allocating to us the IDRs earned from Crestwood Midstream (or, prior to the Crestwood Merger, the general partner and IDR interests of Inergy Midstreamand Legacy Crestwood) with the remaining earnings allocated to the subordinated and limited partner unitholders based on their ownership percentage.We calculate basic net income per limited partner unit by utilizing the two class method. Diluted net income per limited partner unit is computed by dividingnet income attributable to the limited partners by the weighted-average number of units outstanding and the effect of dilutive units granted in the acquisition ofLegacy Crestwood GP. The weighted average number of units outstanding is calculated based on the presumption that the common and subordinated unitsissued to acquire Legacy Crestwood GP (the accounting predecessor) were outstanding for the entire period prior to the June 19, 2013 acquisition. On the dateof the acquisition, all of our limited partner units were considered outstanding.130Table of ContentsCRESTWOOD EQUITY PARTNERS LP (FORMERLY INERGY, L.P.)NOTES TO CONSOLIDATED FINANCIAL STATEMENTSNote 9 – DebtLong-term debt consisted of the following at December 31, 2013 and December 31, 2012, (in millions): December 31, 2013 December 31, 2012 CEQP credit facility$381.0 $—CEQP senior notes11.4 —CEQP obligations under noncompetition agreements and notes to former owners of businesses acquired2.8 —Crestwood Midstream Revolver414.9 —Legacy Crestwood credit facility— 206.7Crestwood Midstream 2019 senior notes350.0 350.0Premium on Crestwood Midstream 2019 senior notes1.2 1.5CMM credit facility— 127.0Crestwood Midstream 2020 senior notes500.0 —Fair value adjustment of Crestwood Midstream 2020 senior notes4.7 —Crestwood Midstream 2022 senior notes600.0 —Total debt2,266.0 685.2Less: current portion5.1 —Total long-term debt$2,260.9 $685.2We and our subsidiaries do not provide credit support or guarantee any amounts outstanding under the credit facilities or notes of Crestwood Midstream.Crestwood Midstream and its subsidiaries do not provide credit support or guarantee any amounts outstanding under our credit facility or senior notes.CEQP Credit FacilityWe utilize a secured credit facility (the "CEQP Credit Facility") with an aggregate revolving loan facility of $550 million due in July 2016, to fund workingcapital requirements, as a source of capital to fund capital expenditures and acquisitions and for general partnership purposes. All borrowings under theCEQP Credit Facility are generally secured by substantially all of our assets and the equity interests in all of our wholly owned subsidiaries, and loansthereunder bear interest, at our option, subject to certain limitations, at a rate equal to the following:•the Alternate Base Rate, which is defined as the higher of (i) the federal funds rate plus 0.50%; (ii) JP Morgan's prime rate; or (iii) AdjustedLIBOR plus 1%; plus a margin varying from 0.75% to 2.00%; or•Adjusted LIBOR, which is defined as the LIBOR plus a margin varying from 1.75% to 3.00%.We are required to use 50% of the net cash proceeds (that are not applied to purchase replacement assets) from asset dispositions (other than the sale ofinventory and motor vehicles in the ordinary course of business, sales of assets among us and our domestic subsidiaries and the sale or disposition of obsoleteor worn-out equipment) to reduce borrowings under the CEQP Credit Facility during any fiscal year in which unapplied net cash proceeds are in excess of$50 million.On August 28, 2013, we amended the CEQP Credit Facility to, among other things, (i) amend the definition of “Consolidated EBITDA” and (ii) change ourfiscal year from September 30 to December 31.On December 20, 2013, we further amended the CEQP Credit Facility. This amendment, among other things, (i) modifies our ratio of total funded debt (asdefined in the credit agreement) to consolidated EBITDA financial covenant levels for the fiscal quarter ending December 31, 2013 (from 4.75 to 1.00 to 5.75to 1.00) and for the quarter ending March 31, 2014 (from 4.75 to 1.00 to 5.50 to 1.00) and reverts to 4.75 for the quarter ended June 30, 2014 and allsubsequent quarters, and (ii) incorporates131Table of ContentsCRESTWOOD EQUITY PARTNERS LP (FORMERLY INERGY, L.P.)NOTES TO CONSOLIDATED FINANCIAL STATEMENTScustomary equity cure rights subject to certain limitations and, with respect to the proceeds of such equity cures, restricted payment rights.At December 31, 2013, the balance outstanding under the CEQP Credit Facility was $381.0 million. The interest rates of the CEQP Credit Facility are basedon prime rate and LIBOR plus the applicable spreads, resulting in interest rates which were between 2.67% and 4.75% at December 31, 2013. Availabilityunder the CEQP Credit Facility was approximately $116.3 million at December 31, 2013, subject to compliance with any applicable covenants under suchfacility. Outstanding standby letters of credit under the credit facility was approximately $52.7 million at December 31, 2013.The credit agreement governing the CEQP Credit Facility contains various covenants and restrictive provisions that limit its ability to, among other things:incur additional debt; make distributions on or redeem or repurchase units; make certain investments and acquisitions; incur or permit certain liens to exist;enter into certain types of transactions with affiliates; merge, consolidate or amalgamate with another company; and transfer or otherwise dispose of assets.The CEQP Credit Facility contains the following financial covenants: •the ratio of our total funded debt (as defined in the credit agreement) to consolidated EBITDA (as defined in the credit agreement) for the four fiscalquarters most recently ended must be no greater than 5.75 to 1.0 (subject to adjustments in future quarters as discussed above); and•the ratio of our consolidated EBITDA to consolidated interest expense (as defined in the credit agreement), for the four fiscal quarters then mostrecently ended, must not be less than 2.50 to 1.0.At December 31, 2013, the total funded debt to consolidated EBITDA was approximately 4.22 to 1.0 and consolidated EBITDA to consolidated interestexpense was approximately 8.93 to 1.0.At December 31, 2013, we were in compliance with the debt covenants in the CEQP Credit Facility.If we fail to perform our obligations under these and other covenants, the CEQP Credit Facility could be terminated and any outstanding borrowings, togetherwith accrued interest, under the credit agreement could be declared immediately due and payable. The credit agreement also has cross default provisions thatapply to any other material indebtedness of ours, excluding debt of Crestwood Midstream.Events of default under the credit agreement governing the CEQP Credit Facility include, among other things: default in payment of principal when due;default in payment of interest, fees or other amounts within three days of their due date; and violation of specified affirmative and negative covenants.We have entered into six interest rate swaps that mature in 2016 to reduce our exposure to variable interest payments due under the CEQP Credit Facility.These swap agreements require us to pay the counterparty an amount based on fixed rates from 0.84% to 2.52% due quarterly on an aggregate notional amountof $225 million. In exchange, the counterparty is required to make quarterly floating interest rate payments on the same date to us based on the three-monthLIBOR applied to the same aggregate notional amount of $225 million. Included in net interest and debt expense on our consolidated statements of operationsfor the year ended December 31, 2013 was $0.1 million of interest income associated with these interest rate swaps. These interest rate swaps are not designatedas hedges for accounting purposes.CEQP Senior NotesAt December 31, 2013, we had $11.4 million in outstanding senior notes, the majority of which mature on October 1, 2018 and have a coupon rate of 7%.The outstanding senior notes do not contain any financial covenants.132Table of ContentsCRESTWOOD EQUITY PARTNERS LP (FORMERLY INERGY, L.P.)NOTES TO CONSOLIDATED FINANCIAL STATEMENTSCrestwood Midstream RevolverContemporaneously with the closing of the Crestwood Merger on October 7, 2013, Crestwood Midstream entered into a new five-year $1 billion senior securedrevolving credit facility (the "Crestwood Midstream Revolver"). The Crestwood Midstream Revolver is available to fund acquisitions, working capital andinternal growth projects and for general partnership purposes. The Crestwood Midstream Revolver includes a sub-limit up to $25 million for same-day swingline advances and a sub-limit up to $250 million for letters of credit. Subject to limited exception, the new credit facility is secured by substantially all of theequity interests and assets of Crestwood Midstream’s restricted domestic subsidiaries, and is joint and severally guaranteed by substantially all of itsrestricted domestic subsidiaries.Crestwood Midstream borrowed $623.6 million under the Crestwood Midstream Revolver to repay in full and retire the credit facilities of Inergy Midstream,Legacy Crestwood and CMM. At December 31, 2013, the balance outstanding on the Crestwood Midstream Revolver was $414.9 million. Outstandingstandby letters of credit under the Crestwood Midstream Revolver amounted to $30.7 million at December 31, 2013. As a result, Crestwood Midstream had$554.4 million of remaining capacity at December 31, 2013, subject to compliance with any applicable covenants under such facility. The weighted-averageinterest rate as of December 31, 2013 was 2.745%.The Crestwood Midstream Revolver contains various covenants and restrictive provisions that limit Crestwood Midstream's ability to, among other things:•incur additional debt;•make distributions on or redeem or repurchase units;•make certain investments and acquisitions;•incur or permit certain liens to exist;•enter into certain types of transactions with affiliates;•merge, consolidate or amalgamate with another company; and•transfer or otherwise dispose of assets.If Crestwood Midstream fails to perform its obligations under these and other covenants, the lenders' credit commitment could be terminated and anyoutstanding borrowings, together with accrued interest, under the Crestwood Midstream Revolver could be declared immediately due and payable. TheCrestwood Midstream Revolver also has cross default provisions that apply to any other material indebtedness of Crestwood Midstream.Borrowings under the Crestwood Midstream Revolver (other than swing line loans) bear interest at its option at either:•the Alternate Base Rate, which is defined as the highest of (i) the federal funds rate plus 0.50%; (ii) JP Morgan's prime rate; or (iii) Adjusted LIBORplus 1%; plus a margin varying from 0.75% to 1.75% depending on Crestwood Midstream's most recent total leverage ratio; or•Adjusted LIBOR, which is defined as LIBOR plus a margin varying from 1.75% to 2.75% depending on Crestwood Midstream's most recent totalleverage ratio.Swingline loans bear interest at the Alternate Base Rate plus a margin varying from 0.75% to 1.75%. The unused portion of the Crestwood MidstreamRevolver is subject to a commitment fee ranging from 0.30% to 0.50% per annum according to Crestwood Midstream's most recent total leverage ratio. Intereston Alternative Base Rate loans is payable quarterly or, if Adjusted LIBOR applies, it may be paid at more frequent intervals.133Table of ContentsCRESTWOOD EQUITY PARTNERS LP (FORMERLY INERGY, L.P.)NOTES TO CONSOLIDATED FINANCIAL STATEMENTSThe Crestwood Midstream Revolver requires maintenance of a consolidated leverage ratio (as defined in its credit agreement) of not more than 5.00 (subject to,at its election, a consolidated net leverage ratio of not more than 5.50 to 1.0 during certain periods following certain material acquisitions as further describedin its credit agreement) to 1.0 and an interest coverage ratio (as defined in its credit agreement) of not less than 2.50 to 1.0.At December 31, 2013, the total funded debt to consolidated EBITDA was approximately 4.90 to 1.0 and consolidated EBITDA to consolidated interestexpense was approximately 3.56 to 1.0.Crestwood Midstream 2019 Senior NotesIn April 2011, Legacy Crestwood and Crestwood Midstream Finance Corporation (“Legacy Crestwood Finance” and together with Legacy Crestwood, the“Legacy Crestwood Issuers”) issued $200 million in a private offering in aggregate principal amount of their 7.75% Senior Notes due 2019 (the “Initial 2019Senior Notes”). On November 14, 2012, the Legacy Crestwood Issuers issued and sold an additional $150 million in a private offering in aggregate principalamount of their 7.75% Senior Notes due 2019 the “Additional 2019 Senior Notes,” and together with the Initial 2019 Senior Notes, the “2019 Senior Notes”).The 2019 Senior Notes will mature on April 1, 2019, and interest is payable semi-annually in arrears on April 1 and October 1 of each year. Interestpayments commenced on October 1, 2011 and April 1, 2013 for the Initial 2019 Senior Notes and the Additional 2019 Senior Notes, respectively, noting thatinterest payable on the Additional 2019 Senior Notes' April 1, 2013 payment date commenced accruing on October 1, 2012.Following the close of the Crestwood Merger on October 7, 2013, (i) Crestwood Midstream and Crestwood Midstream Finance Corp. (formerly known asNRGM Finance Corp., “Finance Corp”) assumed the obligations of Legacy Crestwood and Legacy Crestwood Finance under their 2019 Senior Notes; (ii)certain Legacy Crestwood subsidiary guarantors of the 2019 Senior Notes guaranteed the obligations of Crestwood Midstream and Finance Corp. under the2020 Senior Notes described below; (iii) Crestwood Midstream’s subsidiary guarantors of the 2020 Senior Notes guaranteed the obligations of the LegacyCrestwood Issuers under the 2019 Senior Notes; and (iv) Legacy Crestwood Finance merged with and into NRGM Finance Corp., with NRGM Finance Corp.continuing as the surviving entity and immediately thereafter changing its name to Crestwood Midstream Finance Corp.In general, the 2019 Senior Notes are fully and unconditionally guaranteed, joint and severally, on a senior unsecured basis by Crestwood Midstream’sdomestic restricted subsidiaries (other than Finance Corp). The indenture contains customary release provisions, such as (i) disposition of all or substantiallyall the assets of, or the capital stock of, a guarantor subsidiary to a third person if the disposition complies with the indenture; (ii) designation of a guarantorsubsidiary as an unrestricted subsidiary in accordance with its indentures; (iii) legal or covenant defeasance of a series of senior notes, or satisfaction anddischarge of the related indenture; and (iv) guarantor subsidiary ceases to guarantee any other indebtedness of Crestwood Midstream or any other guarantorsubsidiary, provided it no longer guarantees indebtedness under the Crestwood Midstream Revolver.The indenture restricts the ability of Crestwood Midstream and its restricted subsidiaries to, among other things, sell assets; pay distributions on, redeem orrepurchase Crestwood Midstream units, redeem or repurchase subordinated debt; make investments; incur or guarantee additional indebtedness or issuepreferred units; create or incur certain liens; enter into agreements that restrict distributions or other payments to Crestwood Midstream from its restrictedsubsidiaries; consolidate, merge or transfer all or substantially all of their assets; and, engage in affiliate transactions; create unrestricted subsidiaries. Theserestrictions are subject to a number of important exceptions and qualifications, and many of these restrictions will terminate when the senior notes are ratedinvestment grade and no default under the indenture has occurred and is continuing.Crestwood Midstream 2020 Senior NotesAt December 31, 2013, the balance outstanding on Crestwood Midstream's 6.0% Senior Notes due 2020 (the “2020 Senior Notes”) was $500 million. Werecorded a $4.7 million adjustment in conjunction with the Legacy Crestwood GP's reverse acquisition of us to adjust the debt to fair value. The senior noteswill mature on December 15, 2020, and interest is payable semi-annually in arrears on June 15 and December 15 of each year.In general, the 2020 Senior Notes are fully and unconditionally guaranteed, joint and severally, on a senior unsecured basis by Crestwood Midstream’sdomestic restricted subsidiaries (other than Finance Corp.). The indenture contains customary release provisions, such as (i) disposition of all or substantiallyall of the assets of, or the capital stock of, a guarantor subsidiary to a third person if the disposition complies with the indenture; (ii) designation of aguarantor subsidiary as an unrestricted134Table of ContentsCRESTWOOD EQUITY PARTNERS LP (FORMERLY INERGY, L.P.)NOTES TO CONSOLIDATED FINANCIAL STATEMENTSsubsidiary in accordance with Crestwood Midstream’s indentures; and (iii) legal or covenant defeasance of a series of senior notes, or satisfaction anddischarge of the related indenture.The indenture restricts the ability of Crestwood Midstream and its domestic restricted subsidiaries to, among other things: sell assets; pay distributions on,redeem or repurchase Crestwood Midstream units or redeem or repurchase subordinated debt; make investments; incur or guarantee additional indebtedness orissue preferred units; create or incur certain liens; enter into agreements that restrict distributions or other payments to Crestwood Midstream from its restrictedsubsidiaries; consolidate, merge or transfer all or substantially all of their assets; engage in affiliate transactions; create unrestricted subsidiaries and enter intosale and leaseback transactions. These covenants are subject to a number of important exceptions and qualifications. At any time when the 2020 Senior Notesare rated investment grade by either of Moody’s Investors Service, Inc. or Standard & Poor’s Ratings Services and no default or event of default (each asdefined in the indenture) has occurred and is continuing, many of these covenants will terminate.Crestwood Midstream 2022 Senior NotesOn November 8, 2013, Crestwood Midstream and Finance Corp. completed an offering of $600 million in aggregate principal amount of 6.125% senior notesdue 2022 (the "2022 Senior Notes") in a private offering exempt from the registration requirements of the Securities Act of 1933. At December 31, 2013, thebalance outstanding on the 2022 Senior Notes was $600 million. The notes are guaranteed on a senior unsecured basis by substantially all of CrestwoodMidstream’s domestic restricted subsidiaries (other than Finance Corp.), subject to certain exceptions. Crestwood Midstream used the net offering proceeds tofund a portion of the consideration paid in the Arrow Acquisition and to pay related fees and expenses, and to repay borrowings under the CrestwoodMidstream Revolver.In general, the 2022 Senior Notes are fully and unconditionally guaranteed, joint and severally, on a senior unsecured basis by Crestwood Midstream'sdomestic restricted subsidiaries (other than Finance Corp.). The indenture contains customary release provisions, such as (i) disposition of all or substantiallyall of the assets of, or the capital stock of, a guarantor subsidiary to a third person if the disposition complies with the indenture; (ii) designation of aguarantor subsidiary as an unrestricted subsidiary in accordance with Crestwood Midstream's indentures; and (iii) legal or covenant defeasance of a series ofsenior notes, or satisfaction and discharge of the related indenture.The indenture restricts the ability of Crestwood Midstream and its domestic restricted subsidiaries to, among other things, sell assets; redeem or repurchasesubordinated debt; make investments; incur or guarantee additional indebtedness or issue preferred units; create or incur certain liens; enter into agreementsthat restrict distributions or other payments to Crestwood Midstream from its restricted subsidiaries; consolidate, merge or transfer all of substantially all oftheir assets; create unrestricted subsidiaries; and engage in affiliate transactions. These restrictions are subject to a number of important exceptions andqualifications, and many of these restrictions will terminate when the senior notes are rated investment grade and no default under the indenture has occurredand is continuing.At December 31, 2013, Crestwood Midstream was in compliance with all of its debt covenants.Notes Payable and Other ObligationsNon-interest bearing obligations due under noncompetition agreements and other note payable agreements consisted of agreements between Legacy Inergy andthe sellers of certain companies acquired from 2003 through 2013 with payments due through 2022 and imputed interest ranging from 6.75% to 8.00%. Non-interest bearing obligations consisted of $3.7 million in total payments due under agreements, less unamortized discount based on imputed interest of $0.9million at December 31, 2013. 135Table of ContentsCRESTWOOD EQUITY PARTNERS LP (FORMERLY INERGY, L.P.)NOTES TO CONSOLIDATED FINANCIAL STATEMENTSMaturitiesThe aggregate amounts of principal to be paid on the outstanding long-term debt and notes payable during the next five years ending December 31 and in totalthereafter are as follows (in millions):2014$5.120151.02016379.220170.22018422.3Thereafter1,452.3Total debt$2,260.1Residual Value GuaranteeIn conjunction with the contribution of Legacy Inergy's retail operations to Suburban Propane Partners ("SPH") on August 1, 2012, Legacy Inergy entered intoa support agreement with SPH pursuant to which it was obligated to provide contingent, residual support of approximately $497 million of aggregate principalamount of the 7.5% senior unsecured notes due 2018 of SPH and Suburban Energy Finance Corp. (collectively, the “SPH Issuers”) or any permittedrefinancing thereof. Under the support agreement, in the event the SPH Issuers fail to pay any principal amount of the supported debt when due, we will paydirectly to, or to the SPH Issuers for the benefit of, the holders of the supported debt an amount up to the principal amount of the supported debt that the SPHIssuers have failed to pay. We have no obligation to make a payment under the support agreement with respect to any accrued and unpaid interest or anyredemption premium or other costs, fees, expenses, penalties, charges or other amounts of any kind whatsoever that shall be due to noteholders by the SPHIssuers, whether on or related to the supported debt or otherwise. The support agreement terminates on the earlier of the date the supported debt is extinguishedor on the maturity date of supported debt or any permitted refinancing thereof. We believe the probability of any future payment on this residual valueguarantee is remote.Note 10 - Income TaxesThe provision for income taxes for the years ended December 31, 2013, 2012, and 2011 consisted of the following (in millions): Year Ended December 31, 2013 2012 2011Current: Federal$2.5 $— $—State1.3 1.2 1.3Total current3.8 1.2 1.3Deferred: Federal(2.5) — —State(0.3) — —Total deferred(2.8) — —Provision for income taxes$1.0 $1.2 $1.3The effective rate differs from the statutory rate because the income tax provision for the year ended December 31, 2013 relates to taxable income of thecorporations as discussed in Note 2. 136Table of ContentsCRESTWOOD EQUITY PARTNERS LP (FORMERLY INERGY, L.P.)NOTES TO CONSOLIDATED FINANCIAL STATEMENTSDeferred income taxes related to our wholly owned subsidiary, IPCH Acquisition Corp. ("IPCHA"), reflect the net tax effects of temporary differences betweenthe carrying amounts of assets and liabilities for financial reporting purposes and the amounts used for income tax purposes. Components of the deferredincome taxes at December 31, 2013 are as follows (in millions). Legacy Crestwood GP did not have deferred income taxes at December 31, 2012. December 31, 2013Deferred tax liabilities: Basis difference in stock of acquired company$(17.2)Total deferred tax liability$(17.2)We are responsible for the Texas Margin tax computed on the Texas franchise tax return. The margin tax qualifies as an income tax under GAAP, whichrequires us to recognize the impact of this tax on the temporary differences between the financial statement assets and liabilities and their tax basis attributableto such tax. For the years ended December 31, 2013, 2012 and 2011, there were no temporary differences recognized in our consolidated statements ofoperations.Uncertain Tax Positions. We evaluate the uncertainty in tax positions taken or expected to be taken in the course of preparing our consolidated financialstatements to determine whether the tax positions are more likely than not of being sustained by the applicable tax authority. Tax positions with respect to tax atthe partnership level deemed not to meet the more likely than not threshold would be recorded as a tax benefit or expense in the current year. We believe thatthere are no uncertain tax positions that would impact our operations for the years ended December 31, 2013, 2012 and 2011 and that no provision for incometax is required for these consolidated financial statements. However, our conclusions regarding the evaluation are subject to review and may change based onfactors including, but not limited to, ongoing analyses of tax laws, regulations and interpretations thereof.Note 11 – Partners’ CapitalUnit IssuancesWe periodically sell common units in public offerings to generate funds to reduce our indebtedness under our credit facilities and to fund acquisitions. Thetable below presents limited partner unit issuances by Legacy Crestwood, Inergy Midstream and Crestwood Midstream.Issuer Issuance Date Units Per UnitGross Price Per UnitNet Price (1) NetProceeds Legacy Crestwood April 1, 2011 6,243,000(2) $24.50 $— $152.7Legacy Crestwood May 4, 2011 1,800,000 30.65 29.75 53.6Legacy Crestwood January 13, 2012 3,500,000 30.73 29.50 103.1Legacy Crestwood July 25, 2012 4,600,000(3) 26.00 24.97 114.4Legacy Crestwood March 22, 2013 5,175,000(4) 23.90 23.00 118.5Inergy Midstream September 13, 2013 11,773,191(5) 22.50 21.69 255.2Crestwood Midstream October 23, 2013 16,100,000(6) N/A 21.19 340.3 (1) Price is net of underwriting discounts.(2) Represents Class C units.(3) Includes 600,000 units that were issued in August 2012.(4) Includes 675,000 units that were issued in April 2013.(5) Includes 773,191 units that were issued on October 7, 2013.(6) Includes 2,100,000 units that were issued on October 30, 2013.137Table of ContentsCRESTWOOD EQUITY PARTNERS LP (FORMERLY INERGY, L.P.)NOTES TO CONSOLIDATED FINANCIAL STATEMENTSDuring 2011 and 2013, Legacy Crestwood issued Class C and Class D units, respectively, representing limited partner units. Legacy Crestwood had theoption to pay distributions to its Class C and Class D unitholders with cash or by issuing additional paid-in-kind units based upon the volume common unitweighted-average price for 10 trading days immediately preceding the date the distribution was declared. On April 1, 2013, the outstanding Legacy CrestwoodClass C units converted to common units on a one-for-one basis. In conjunction with the Crestwood Merger, Legacy Crestwood unitholders received 1.07 unitsof Legacy Inergy units for each unit of Legacy Crestwood they owned and as a result, there were no common or Class D units outstanding immediatelyfollowing the Crestwood Merger. During 2013, Legacy Crestwood issued 183,995 and 292,660 additional Class C and Class D units in lieu of paying aquarterly cash distribution. For the years ended December 31, 2012 and 2011, Legacy Crestwood issued 633,084 and 473,731 additional Class C units inlieu of paying quarterly cash distributions.ContributionsDuring 2012, Legacy Crestwood's general partner made additional capital contributions of approximately $5.9 million in exchange for the issuance of anadditional 215,722 general partner units. During 2011, the Legacy Crestwood general partner made an additional capital contribution of approximately $8.7million in exchange for the issuance of an additional 293,948 general partner units.DistributionsWe make quarterly distributions to the partners within approximately 45 days after the end of each quarter in an aggregate amount equal to our available cashfor such quarter. Available cash generally means, with respect to each quarter, all cash on hand at the end of the quarter less the amount of cash that thegeneral partner determines in its reasonable discretion is necessary or appropriate to:•provide for the proper conduct of our business;•comply with applicable law, any of our debt instruments, or other agreements; or•provide funds for distributions to unitholders for any one or more of the next four quarters;plus all cash on hand on the date of determination of available cash for the quarter resulting from working capital borrowings made after the end of the quarter.Working capital borrowings are generally borrowings that are made under our working capital facility and in all cases are used solely for working capitalpurposes or to pay distributions to partners.Distributions to PartnersDuring the years ended December 31, 2013, 2012 and 2011, Legacy Crestwood GP paid cash distributions to its member of $9.3 million, $13.8 million and$5.9 million.A summary of our limited partner quarterly distributions for the year ended December 31, 2013 (subsequent to the June 19, 2013 reverse acquisition) ispresented below:Year Ended December 31, 2013Record Date Payment Date Per Unit Rate Cash Distributions (in millions)August 7, 2013 August 14, 2013 $0.13 $22.3November 7, 2013 November 14, 2013 $0.135 25.0 $47.3On February 14, 2014, we paid a distribution of $0.1375 per limited partner unit to unitholders of record on February 7, 2014 with respect to the fourthquarter of 2013.138Table of ContentsCRESTWOOD EQUITY PARTNERS LP (FORMERLY INERGY, L.P.)NOTES TO CONSOLIDATED FINANCIAL STATEMENTSDistributions to Non-Controlling PartnersCrestwood Midstream and Legacy Crestwood paid cash distributions to its common unitholders of $179.6 million for the year ended December 31, 2013.Legacy Crestwood paid cash distributions to its common unitholders of $77.7 million and $58.1 million for the year ended December 31, 2012 and 2011.Other Partners' Capital TransactionsCrestwood MergerIn conjunction with Crestwood Holdings’ acquisition of our general partner, we issued 4,387,889 subordinated units, which are considered limitedpartnership interests, and have the same rights and obligations as our common units, except that the subordinated units are entitled to receive distributions ofavailable cash for a particular quarter only after each of our common units has received a distribution of at least $0.13 for that quarter. Our subordinatedunits convert to common units after our common units have received a cumulative distribution in excess of $0.52 during a consecutive four quarter period.As discussed in Note 1, in conjunction with the Crestwood Merger, Legacy Crestwood unitholders received 1.07 units of Inergy Midstream units for eachLegacy Crestwood unit they owned and as a result, there were no Legacy Crestwood common or Class D units outstanding immediately following the merger.In addition, Legacy Crestwood unitholders also received a $34.9 million distribution, $10 million of which was funded as a non-cash contribution fromCrestwood Holdings and is reflected on our consolidated statements of partners’ capital as contribution from Crestwood Holding LLC for the year endedDecember 31, 2013. We reflected the distribution of $34.9 million as distributions to non-controlling partners on our consolidated statements of partners’capital for the year ended December 31, 2013.In conjunction with the Crestwood Merger, the restricted units outstanding under the Legacy Inergy long-term incentive plan were modified to accelerate thevesting of certain outstanding awards on December 31, 2013. We reflected the cash paid of approximately $11.8 million related to these vesting units asdistributions to partners on our consolidated statements of cash flows for the year ended December 31, 2013. Following the closing of the Crestwood Merger, Crestwood Holdings exchanged 7,100,000 common units of CMLP for 14,300,000 common units of CEQPpursuant to an option obtained on June 19, 2013 when it acquired our general partner. This exchange resulted in a $182.3 million decrease to the interest ofnon-controlling partners and a $182.3 million increase to partners' capital on our consolidated statements of partners' capital.Acquisitions and OtherCMM. In February 2012, Legacy Crestwood and Crestwood Holdings formed the CMM joint venture. Legacy Crestwood contributed approximately $131.3million for a 35% membership interest and Crestwood Holdings contributed approximately $243.8 million for a 65% membership interest. On January 8,2013, Legacy Crestwood acquired Crestwood Holdings’ 65% membership interest in CMM for approximately $258.0 million, which was funded through$129.0 million of borrowings under the Legacy Crestwood credit facility, the issuance of 6,190,469 Class D units and the issuance of 133,060 generalpartner units to the Legacy Crestwood general partner. As a result of the acquisition of the additional membership interest, Legacy Crestwood had the ability tocontrol CMM’s operating and financial decisions and policies. The transaction was accounted for as a reorganization of entities under common control andaccordingly, the historical results of Legacy Crestwood were retrospectively adjusted to reflect the change in reporting entity as of and for the year endedDecember 31, 2012. We reflected the $243.8 million contribution by Crestwood Holdings as contributions from non-controlling partners in our consolidatedstatements of cash flows and statements of partners’ capital for the year ended December 31, 2012. The issuances of the Class D and general partner units inconjunction with the acquisition of the additional interest in CMM were reflected as distributions for additional interest in Crestwood Marcellus MidstreamLLC in our consolidated statements of cash flows and statements of partners’ capital for the year ended December 31, 2013.Arrow. On November 7, 2013, Crestwood Midstream issued 8,826,125 common units as partial consideration of the Arrow Acquisition. See Note 4 foradditional information regarding the Arrow Acquisition.139Table of ContentsCRESTWOOD EQUITY PARTNERS LP (FORMERLY INERGY, L.P.)NOTES TO CONSOLIDATED FINANCIAL STATEMENTSOther. In connection with the Crestwood Holdings’ acquisition of Legacy Crestwood, Legacy Crestwood GP agreed to pay Quicksilver conditionalconsideration in the form of potential additional cash payments of up to $72 million depending on the achievement of certain defined average volume targetsabove an agreed threshold for 2011 and 2012. At December 31, 2011, the fair value of the conditional consideration was determined to be approximately $47.9million. We recognized a gain of approximately $17.2 million for the year ended December 31, 2011 as a result of the reduction in the fair value of thecontingent consideration.In February 2012, Crestwood Holdings paid Quicksilver approximately $41.1 million on behalf of Legacy Crestwood GP associated with the average volumesachieved for 2011. We reflected this payment as a non-cash contribution from non-controlling partners on our consolidated statements of partners’ capital forthe year ended December 31, 2012. As of December 31, 2012, Quicksilver did not achieve their 2012 average volume target. As such, we determined that theestimated fair value of our remaining conditional consideration to Quicksilver was zero, and we recognized a gain of approximately $6.8 million for the yearended December 31, 2012 related to the elimination of the contingent liability.Preferred Equity of SubsidiaryIn conjunction with the Jackalope Acquisition discussed in Note 5, Crestwood Niobrara issued a preferred interest of approximately $80.6 million to asubsidiary of General Electric Capital Corporation and GE Structured Finance, Inc. (collectively, “GE”). The preferred interest is reflected as non-controllinginterest in our consolidated financial statements. During the year ended December 31, 2013, we allocated approximately $4.9 million of net income to the non-controlling interest, which was based on the overall return attributable to the preferred security.Crestwood Niobrara will fund 75% of future capital contributions to Jackalope through additional preferred interest issuances to GE (up to a maximum of anadditional $53.9 million), with the remainder to be funded through our capital contributions to Crestwood Niobrara. During the year ended December 31,2013, GE contributed $96.1 million (which consisted of the initial contribution of $80.6 million and additional capital contributions of $15.5 million) toCrestwood Niobrara in exchange for an equivalent number of preferred units. The proceeds from GE’s initial contribution were used to fund a portion of theJackalope acquisition price, and the proceeds from the subsequent contributions were used to fund capital contributions to the Jackalope investment.Crestwood Niobrara has the option to pay distributions to GE with cash or by issuing additional preferred units through the January 2015 distribution. OnOctober 30, 2013, Crestwood Niobrara issued GE approximately 2,161,657 units in lieu of paying a cash distribution. Crestwood Midstream serves as themanaging member of Crestwood Niobrara and, subject to certain restrictions, it has the ability to redeem GE’s preferred interest in either cash or CrestwoodMidstream common units. On January 31, 2014, Crestwood Niobrara issued 2,210,294 preferred units to GE in lieu of paying a cash distribution.Note 12 - Equity PlanCEQPUnit Purchase PlanLegacy Inergy's general partner sponsored a unit purchase plan for its employees and the employees of its affiliates. The unit purchase plan permitsparticipants to purchase common units in market transactions from Legacy Inergy, the general partners or any other person. All purchases made have been inmarket transactions, although the plan allows Legacy Inergy to issue additional units. Legacy Inergy has reserved 100,000 units for purchase under the unitpurchase plan. As determined by the compensation committee, the general partner may match each participant's cash base pay or salary deferrals by anamount up to 10% of such deferrals and have such amount applied toward the purchase of additional units. The general partner has also agreed to pay thebrokerage commissions, transfer taxes and other transaction fees associated with a participant's purchase of common units. The maximum amount that aparticipant may elect to have withheld from his or her salary or cash base pay with respect to unit purchases in any calendar year may not exceed 10% of hisor her base salary or wages for the year. Units purchased on behalf of a participant under the unit purchase plan generally are to be held by the participant forat least one year. To the extent a participant desires to sell or dispose of such units prior to the end of this one year holding period, the participant will beineligible to participate in the unit purchase plan again until the one year anniversary of the date of such sale. The unit purchase plan is intended to serve as ameans for encouraging participants to invest in common units. There were 10,968 units140Table of ContentsCRESTWOOD EQUITY PARTNERS LP (FORMERLY INERGY, L.P.)NOTES TO CONSOLIDATED FINANCIAL STATEMENTSpurchased through the unit purchase plan by Legacy Inergy and its employees for the year ended December 31, 2013. We continue to maintain and sponsorthis plan.Long-Term Incentive PlanLegacy Inergy’s general partner sponsored a long-term incentive plan for its employees, consultants and directors and the employees of its affiliates thatperformed services for Legacy Inergy. Restricted units were the only type of unvested award outstanding at the time of the Crestwood Merger on June 19, 2013.In conjunction with the Crestwood Merger, the restricted units outstanding under the long-term incentive plan were modified to accelerate the vesting of all theoutstanding awards on either the earlier of their original vesting date, or December 31, 2013 or June 19, 2014, depending on the respective employee. Wecontinue to maintain and sponsor this plan. During the period June 19, 2013 to December 31, 2013, 670,658 restricted units vested at a per unit price of $13.96. Total compensation expense associatedwith vested and unvested awards amounted to $5.9 million for the year ended December 31, 2013. At December 31, 2013, there were 446,581 unvestedrestricted units outstanding at a per unit price of $13.96 and total unrecognized compensation expense associated with these restricted units amounted to $1.6million. That cost is expected to be recognized over the period January 1, 2014 to June 19, 2014.CMLPLong-Term Incentive PlanInergy Midstream's general partner sponsored a long-term incentive plan for its employees, consultants and directors and the employees of its affiliates thatperformed services for Inergy Midstream. Restricted units were the only type of unvested award outstanding at the time of the Crestwood Merger on June 19,2013. In conjunction with the Crestwood Merger, the restricted units outstanding under the long-term incentive plan were modified to accelerate the vesting ofall the outstanding awards on the earlier of their original vesting date, or either December 31, 2013 or June 19, 2014, depending on the respective employee.Crestwood Midstream continues to maintain and sponsor this plan. During the period June 19, 2013 to December 31, 2013, 230,384 restricted units vested at a per unit price of $22.16. Total compensation expense associatedwith vested and unvested awards amounted to $4.9 million for the year ended December 31, 2013. At December 31, 2013, there were 195,250 unvestedrestricted units outstanding at a per unit price of $22.16 and total unrecognized compensation expense associated with these restricted units amounted to $1.8million. That cost is expected to be recognized over the period January 1, 2014 to June 19, 2014.141Table of ContentsCRESTWOOD EQUITY PARTNERS LP (FORMERLY INERGY, L.P.)NOTES TO CONSOLIDATED FINANCIAL STATEMENTSLegacy CrestwoodLong-Term Incentive PlanPrior to the Crestwood Merger, awards of phantom and restricted units were granted under the Legacy Crestwood Fourth Amended and Restated 2007 EquityPlan (the "2007 Equity Plan"). The 2007 Equity Plan was terminated in conjunction with the Crestwood Merger. All of the unvested phantom and restrictedunits became vested upon consummation of the Crestwood Merger and all unamortized compensation expense related to those units was recognized on thatdate. The following table summarizes information regarding phantom and restricted unit activity: Payable In Cash Payable In Units Units Weighted-Average GrantDate FairValue Units Weighted-Average GrantDate FairValue Unvested - December 31, 201113,346 $26.40 128,795 $27.22Vested - phantom units(4,267) $26.46 (40,929) $27.21Vested - restricted units— $— (4,682) $27.53Granted - phantom units— $— 126,246 $29.90Granted - restricted units— $— 37,500 $25.67Canceled - phantom units(767) $25.63 (24,938) $28.30Unvested - December 31, 20128,312 $26.45 221,992 $28.35Vested - phantom units(7,958) $26.48 (329,825) $26.69Vested - restricted units— $— (74,760) $25.60Granted - phantom units— $— 161,807 $24.33Granted - restricted units— $— 27,900 $24.86Canceled - phantom units(354) $25.81 (7,114) $27.96Unvested - December 31, 2013— $— — $—As discussed above, the vesting period of our phantom and restricted units were accelerated upon consummation of the Crestwood Merger. CrestwoodMidstream recognized compensation expense under the 2007 Equity Plan of approximately $6.5 million, $1.9 million and $0.9 million for the years endedDecember 31, 2013, 2012 and 2011, included in operating expenses on our consolidated statements of income. Crestwood Midstream granted phantom andrestricted units under the 2007 Equity Plan with a grant date fair value of approximately $4.6 million, $4.7 million and $0.8 million for the years endedDecember 31, 2013, 2012 and 2011. Under the 2007 Equity Plan, participants who were granted restricted units could elect to have Crestwood Midstream withhold common units to satisfyminimum statutory tax withholding obligations arising in connection with the vesting of non-vested common units. Any such common units withheld werereturned to the 2007 Equity Plan on the applicable vesting dates, which corresponded to the times at which income was recognized by the employee. WhenCrestwood Midstream withheld these common units, they were required to remit to the appropriate taxing authorities the fair value of the units withheld as ofthe vesting date. The number of units withheld was determined based on the closing price per common unit as reported on the NYSE on such dates. For theyears ended December 31, 2013 and 2012, Crestwood Midstream withheld 21,014 and 1,405 common units to satisfy employee tax withholding obligations.There were no common units withheld to satisfy employee tax withholding obligations for the year ended December 31, 2011.142Table of ContentsCRESTWOOD EQUITY PARTNERS LP (FORMERLY INERGY, L.P.)NOTES TO CONSOLIDATED FINANCIAL STATEMENTSNote 13 - Employee Benefit PlansA 401(k) plan is available to all of our employees after meeting certain requirements. The plan permits employees to make contributions up to 75% of theirsalary, up to statutory limits, which was $17,500 in 2013. The plan provides for matching contributions by us for employees completing one year of serviceof at least 1,000 hours. Aggregate matching contributions made by us were $0.5 million in 2013. Neither Legacy Crestwood GP nor Legacy Crestwood hadany employees. Employees of Crestwood Holdings provided services to Legacy Crestwood GP and Legacy Crestwood pursuant to an omnibus agreement.Note 14 - Asset Retirement ObligationsWe have legal obligations associated with right-of-way contracts we hold and at our facilities whether owned or leased. Where we can reasonably estimate theasset retirement obligation, we accrue a liability based on an estimate of the timing and amount of settlement. We record changes in these estimates based onchanges in the expected amount and timing of payments to settle our obligations.The following table presents the changes in the net asset retirement obligations for the years ended December 31, 2013 and 2012 (in millions): December 31, 2013 2012Net asset retirement obligation at January 1$14.0 $11.5Liabilities incurred— 0.4Acquisitions— 1.4Accretion expense0.8 0.7Changes in estimate0.3 —Net asset retirement obligation at December 31$15.1 $14.0We did not have any material assets that were legally restricted for use in settling asset retirement obligations as of December 31, 2013 and 2012.Note 15 – Commitments and ContingenciesLegal ProceedingsClass Action Lawsuits. Five putative class action lawsuits challenging the Crestwood Merger have been filed, four in federal court in the United StatesDistrict Court for the Southern District of Texas: (i) Abraham Knoll v. Robert G. Phillips, et al. (Case No. 4:13-cv-01528); (ii) Greg Podell v. CrestwoodMidstream Partners, LP, et al. (Case No. 4:13-cv-01599); (iii) Johnny Cooper v. Crestwood Midstream Partners LP, et al. (Case No. 4:13-cv-01660);and (iv) Steven Elliot LLC v. Robert G. Phillips, et al. (Case No. 4:13-cv-01763), and one in Delaware Chancery Court, Hawley v. Crestwood MidstreamPartners LP, et al. (Case No. 8689-VCL). All of the cases name Legacy Crestwood (since merged into the Company), Crestwood Gas Services GP LLC,Crestwood Holdings LLC, the current and former directors of Crestwood Gas Services GP LLC, the Company, Inergy Midstream, Crestwood Midstream GPLLC (formerly NRGM GP, LLC), and Intrepid Merger Sub, LLC as defendants. All of the suits are brought by a purported holder of common units ofInergy Midstream, both individually and on behalf of a putative class consisting of holders of common units of Inergy Midstream. The lawsuits generallyallege, among other things, that the directors of Crestwood Gas Services GP LLC breached their fiduciary duties to holders of common units of InergyMidstream by agreeing to a transaction with inadequate consideration and unfair terms and pursuant to an inadequate process. The lawsuits further allege thatthe Company, Inergy Midstream, Crestwood Midstream GP LLC, and Intrepid Merger Sub, LLC aided and abetted the Legacy Crestwood directors in thealleged breach of their fiduciary duties. The lawsuits seek, in general, (i) injunctive relief enjoining the merger, (ii) in the event the merger is consummated,rescission or an award of rescissory damages, (iii) an award of plaintiffs' costs, including reasonable attorneys' and experts' fees, (iv) the accounting by thedefendants to plaintiffs for all damages caused by the defendants, and (v) such further equitable relief as the court deems just and proper. Certain of theactions also assert claims of inadequate disclosure under Sections 14(a) and 20(a) of the Securities143Table of ContentsCRESTWOOD EQUITY PARTNERS LP (FORMERLY INERGY, L.P.)NOTES TO CONSOLIDATED FINANCIAL STATEMENTSExchange Act of 1934, and the Elliot case also names Citigroup Global Markets Inc. as an alleged aider and abettor. The plaintiff in the Hawley action inDelaware filed a motion for expedited proceedings but subsequently withdrew that motion and then filed a stipulation voluntarily dismissing the action withoutprejudice (which has not yet been approved by the Court). The plaintiffs in the Knoll, Podell, Cooper, and Elliot actions filed an unopposed motion toconsolidate these four cases, which the Court granted and captioned the consolidated matter as In re Crestwood Midstream Partners Unitholder Litigation,Lead Case No. 4:13-cv-01528 (the “Consolidated Action”). The plaintiffs entered into a Memorandum of Understanding (MOU) on September 24, 2013 tosettle the Consolidated Action whereby the defendants denied liability. The settlement contemplated by the MOU is subject to a number of conditions,including notice to the class and final court approval following completion of a settlement hearing, which is scheduled for May 16, 2014. The defendantsexpect the Court to approve the final settlement. The anticipated settlement of the MOU will not have a material impact to our consolidated financial statements.Letter of Intent. In June 2010, Inergy Midstream and Central New York Oil And Gas Company, L.L.C. (“CNYOG”) entered into a letter of intent withAnadarko Petroleum Corporation (“Anadarko”) which contemplated that, subject to certain conditions, Anadarko may exercise an option to acquire up to a25% ownership interest in the MARC I pipeline. On September 23, 2011, Anadarko filed a complaint against Inergy Midstream and CNYOG in the Court ofCommon Pleas in Lycoming County, Pennsylvania (Cause No. 11-01697) alleging that (i) Anadarko had an option to acquire, and timely exercised its optionto acquire, a 25% ownership interest in the MARC I pipeline, (ii) Inergy Midstream refused to enter into definitive agreements under which Anadarko wouldacquire a 25% interest in the pipeline and, by doing so, Inergy Midstream breached the letter of intent, and (iii) by refusing to enter into definitive agreements,Inergy Midstream breached a duty of good faith and fair dealing in connection with the letter of intent. Based on these allegations, Anadarko sought variousremedies, including specific performance of the letter of intent and monetary damages. On September 9, 2013, Inergy Midstream and Anadarko entered into a confidential settlement agreement to resolve any and all claims relating to the litigation.We have reimbursed Inergy Midstream for the amount paid to Anadarko under the settlement agreement pursuant to the omnibus agreement that governs InergyMidstream's relationship with us.Declaratory Action. In January 2014, the entity from whom we lease our Tres Palacios caverns, Underground Services Markham, LLC (“USM”), filed apetition in the 269th Judicial District Court, Harris County, Texas (Case No. 2014-00823) requesting declaratory judgment on numerous fronts, includingwhether or not TPGS has breached its lease obligations by filing an application with the FERC to reduce the certificated working gas storage capacity of ourTres Palacios natural gas storage facility. We filed our response to USM’s petition on January 31, 2014, and requested that the court dismiss the petition basedon several grounds. We have been advised by the district court that a hearing on USM's motion will be held in early March 2014. We believe that TPGS isentitled to request FERC authorization to reduce Tres Palacios’ certificated working gas storage capacity under our lease and that USM’s claims are withoutmerit, and we intend to vigorously defend ourselves in the lawsuit.We are periodically involved in litigation proceedings. If we determine that a negative outcome is probable and the amount of loss is reasonably estimable, thenwe accrue the estimated amount. The results of litigation proceedings cannot be predicted with certainty; however, management believes that we do not havematerial potential liability in connection with these proceedings that would have a significant financial impact on its consolidated financial condition, results ofoperations or cash flows. However, we could incur judgments, enter into settlements or revise its expectations regarding the outcome of certain matters, andsuch developments could have a material adverse effect on our results of operations or cash flows in the period in which the amounts are paid and/or accrued.As of December 31, 2013 and 2012, we had less than $0.1 million accrued for our outstanding legal matters.Any loss estimates are inherently subjective, based on currently available information, and are subject to management's judgment and various assumptions.Due to the inherently subjective nature of these estimates and the uncertainty and unpredictability surrounding the outcome of legal proceedings, actual resultsmay differ materially from any amounts that have been accrued.Regulatory ComplianceIn the ordinary course of our business, we are subject to various laws and regulations. In the opinion of our management, compliance with current laws andregulations will not have a material effect on its results of operations, cash flows or financial condition.144Table of ContentsCRESTWOOD EQUITY PARTNERS LP (FORMERLY INERGY, L.P.)NOTES TO CONSOLIDATED FINANCIAL STATEMENTSEnvironmental ComplianceOur operations are subject to stringent and complex laws and regulations pertaining to health, safety, and the environment. We are subject to laws andregulations at the federal, state and local levels that relate to air and water quality, hazardous and solid waste management and disposal and otherenvironmental matters. The cost of planning, designing, constructing and operating our facilities must incorporate compliance with environmental laws andregulations and safety standards. Failure to comply with these laws and regulations may trigger a variety of administrative, civil and potentially criminalenforcement measures. Our accruals for environmental matters were immaterial at December 31, 2013 and 2012.Self-InsuranceWe utilize third-party insurance subject to varying retention levels of self-insurance, which management considers prudent. Such self-insurance relates tolosses and liabilities primarily associated with medical claims, workers' compensation claims and general, product, vehicle and environmental liability.Losses are accrued based upon management's estimates of the aggregate liability for claims incurred using certain assumptions followed in the insuranceindustry and based on past experience. The primary assumption utilized is actuarially determined loss development factors. The loss development factors arebased primarily on historical data. Our self insurance reserves could be affected if future claim developments differ from the historical trends. We believechanges in health care costs, trends in health care claims of our employee base, accident frequency and severity and other factors could materially affect theestimate for these liabilities. We continually monitor changes in employee demographics, incident and claim type and evaluates our insurance accruals andadjusts our accruals based on our evaluation of these qualitative data points. We are liable for the development of claims for our disposed retail propaneoperations, provided they were reported prior to August 1, 2012. At December 31, 2013, our self-insurance reserves were $15.8 million. We estimate that$10.6 million of this balance will be paid subsequent to December 31, 2014. As such, $10.6 million has been classified in other long-term liabilities on ourconsolidated balance sheets. There were no self-insurance reserves at December 31, 2012.Contingent Consideration - AnteroIn connection with the Antero Acquisition, Legacy Crestwood agreed to pay Antero conditional consideration in the form of potential additional cash paymentsof up to $40 million, depending on the achievement of certain defined average annual production levels achieved during 2012, 2013 and 2014. During 2012and 2013, Antero did not meet the annual production level to earn additional payments. Based on our estimates of Antero’s 2014 production, we believe theirproduction levels will likely exceed the annual production threshold in the earn-out provision and accordingly, we have recognized a $31.4 million liability asof December 31, 2013 that represents the fair value of the potential payments that may be made under this earn-out provision. We estimated the liability basedon the probability-weighted discounted cash flows using a 5.9% discount rate and our estimate of Antero’s production in 2014 (a Level 3 fair valuemeasurement).Commitments and Purchase ObligationsOperating Leases. TPGS leases the surface and subsurface rights necessary to operate the Tres Palacios storage facility under an operating lease that expireson December 31, 2037, which is subject to automatic renewal for two 20-year extension periods unless TPGS elects not to extend the term of the lease. Thelease payments vary based on the FERC-certificated working gas capacity of the caverns which are in service as well as an incremental payment for physicalvolumes of gas injected and / or withdrawn from the caverns in service. We also maintain operating leases in the ordinary course of our business activities. These leases include those for office buildings and other operating facilitiesand equipment. The terms of the agreements vary from 2014 until 2032.145Table of ContentsCRESTWOOD EQUITY PARTNERS LP (FORMERLY INERGY, L.P.)NOTES TO CONSOLIDATED FINANCIAL STATEMENTSFuture minimum lease payments under noncancelable operating leases for the next five years ending December 31 and in total thereafter consist of the following(in millions):Year EndingDecember 31, 2014$18.2201517.4201617.1201715.8201814.3Thereafter247.5Total minimum lease payments$330.3Rent expense for operating leases for the years ended December 31, 2013, 2012 and 2011, totaled $16.4 million, $7.4 million and $7.7 million.Capital Leases. We have a compressor, treating facility and certain auto leases which are accounted for as capital leases. The terms of the agreements varyfrom 2014 until 2018. We recorded amortization of expense of $3.6 million, $3.1 million and $1.9 million for the years ended December 31, 2013, 2012 and2011.Future minimum lease payments related to our capital leases at December 31, 2013 are as follows (in millions):Year EndingDecember 31, 2014$2.620151.320160.620170.32018—Thereafter—Total payments4.8Imputed interest(0.1)Present value of future payments$4.7Our capital lease liabilities were $4.7 million and $7.0 million at December 31, 2013 and 2012, and are included in accrued expenses and other liabilities andother long-term liabilities on our consolidated balance sheets.Purchase Commitments. We periodically enter into agreements with suppliers to purchase fixed quantities of NGLs, distillates and natural gas at fixedprices. At December 31, 2013, the total of these firm purchase commitments was $234.1 million, substantially all of which will occur over the course of thenext twelve months. We also enter into non-binding agreements with suppliers to purchase quantities of NGLs, distillates and natural gas at variable prices atfuture dates at the then prevailing market prices.We have entered into certain purchase commitments in connection with the identified growth projects primarily related to the Watkins Glen NGL developmentproject, the COLT Hub expansion project, and certain upgrades to the US Salt facility. The Watkins Glen NGL development project entails the conversion ofcertain caverns created by US Salt into 2.1 million barrels of NGL storage. The COLT Hub expansion project primarily includes an expansion of receiving,storage, and take-away capacity via interconnecting pipelines, storage tanks, and rail facilities. At December 31, 2013, the total of our storage andtransportation and NGL and crude services operations' firm purchase commitments was approximately $49.6 million. The gathering and processing segmentalso has purchase commitments of approximately $47.7 million primarily related to the expansion of our compression facilities in the Marcellus Shale andother growth and maintenance contractual purchase obligations. The majority of the purchases associated with these commitments are expected to occur overthe course of the next twelve months.146Table of ContentsCRESTWOOD EQUITY PARTNERS LP (FORMERLY INERGY, L.P.)NOTES TO CONSOLIDATED FINANCIAL STATEMENTSNote 16 – Related Party TransactionsOur general partner is owned by Crestwood Holdings. Affiliates of Crestwood Holdings and its owners, such as Sabine Oil and Gas LLC and MountaineerKeystone, LLC, are considered our related parties. Concurrent with the Crestwood Merger described in Note 1, Quicksilver is no longer a related party, and asa result our transactions with Quicksilver are now considered non-affiliated transactions.We enter into transactions with its affiliates within the ordinary course of business and the services are based on the same terms as non-affiliates, includinggas gathering and processing services under long-term contracts, product purchases and various operating agreements. The following table shows revenues,cost of goods sold, operating and administrative expenses and reimbursements from our affiliates for the years December 31, 2013, 2012 and 2011 (inmillions): Year Ended December 31, 2013 2012 2011Gathering and processing revenues$74.9 $113.7 $131.2Gathering and processing costs of goods sold$32.5 $15.2 $—Operating and administrative expenses$25.3 $19.5 $17.9The following table shows accounts receivable and accounts payable from our affiliates as of December 31, 2013 and 2012 (in millions): December 31,2013 December 31,2012Accounts receivable$— $23.8Accounts payable$3.6 $3.1Following the closing of the Crestwood Merger on October 7, 2013, Crestwood Holdings exchanged 7,100,000 common units of Crestwood Midstream for14,300,000 of our common units pursuant to an option granted to Crestwood Holdings when it acquired our general partner.Note 17 – SegmentsIn conjunction with the June 19, 2013 transactions described in Note 1, we modified our segments and now our financial statements reflect three operating andreporting segments: (i) gathering and processing operations; (ii) NGL and crude services operations; and (iii) storage and transportation operations. Ourgathering and processing operations engage in the gathering, processing, treating, compression, transportation and sales of natural gas and the delivery ofNGLs. Our NGL and crude services operations provide NGLs and crude oil gathering, storage, marketing, supply and logistics services to producers,refiners, marketers, and others that effectively provide flow assurances to our customers, as well as the production and sale of salt products. Our storage andtransportation operations provide natural gas storage and transportation services to third parties. Our corporate operations include all general andadministrative expenses that are not allocated to our reportable segments. We assess the performance of our operating segments based on EBITDA, whichrepresents operating income plus depreciation, amortization and accretion expense.The following table is a reconciliation of net income to EBITDA (in millions): Year Ended December 31, 2013 2012 2011Net income (loss)$(50.6) $24.4 $42.1Add: Interest and debt expense, net77.9 35.8 27.6Provision for income taxes1.0 1.2 1.3Depreciation, amortization and accretion167.9 73.2 53.9EBITDA$196.2 $134.6 $124.9147Table of ContentsCRESTWOOD EQUITY PARTNERS LP (FORMERLY INERGY, L.P.)NOTES TO CONSOLIDATED FINANCIAL STATEMENTSThe following table summarizes the reportable segment data for the years ended December 31, 2013, 2012 and 2011 (in millions). The net asset/liability fromprice risk management, as reported in the accompanying consolidated balance sheets, is primarily related to the NGL and crude services segment. Year Ended December 31, 2013 Gathering andProcessing NGL and CrudeServices Storage andTransportation Corporate TotalOperating revenues$291.2 $1,031.3 $104.2 $— $1,426.7Costs of product/services sold56.6 930.0 15.7 — 1,002.3Operating and administrative expense54.9 37.6 12.1 93.5 198.1Goodwill impairment(4.1) — — — (4.1)Other income— — — 0.2 0.2Gain (loss) on long-lived assets5.4 (0.1) — — 5.3Loss on contingent consideration(31.4) — — — (31.4)Earnings (loss) from unconsolidated affiliates0.1 (0.2) — — (0.1)EBITDA$149.7 $63.4 $76.4 $(93.3) $196.2Goodwill$356.8 $1,258.9 $936.5 $— $2,552.2Total assets$2,507.3 $3,465.8 $2,369.1 $181.0 $8,523.2Cash expenditures for property, plant and equipment$271.2 $56.8 $18.0 $1.0 $347.0 Year Ended December 31, 2012 Gathering andProcessing NGL and CrudeServices Storage andTransportation Corporate TotalOperating revenues$239.5 $— $— $— $239.5Costs of product/services sold39.0 — — — 39.0Operating and administrative expense43.1 — — 29.6 72.7Gain on contingent consideration6.8 — — — 6.8EBITDA$164.2 $— $— $(29.6) $134.6Goodwill$352.2 $— $— $— $352.2Total assets$2,278.9 $— $— $22.7 $2,301.6Cash expenditures for property, plant and equipment$51.5 $— $— $1.1 $52.6148Table of ContentsCRESTWOOD EQUITY PARTNERS LP (FORMERLY INERGY, L.P.)NOTES TO CONSOLIDATED FINANCIAL STATEMENTS Year Ended December 31, 2011 Gathering andProcessing NGL and CrudeServices Storage andTransportation Corporate TotalOperating revenues$205.8 $— $— $— $205.8Costs of product/services sold38.8 — — — 38.8Operating and administrative expense36.3 — — 24.1 60.4Gain on long-lived assets1.1 — — — 1.1Gain on contingent consideration17.2 — — — 17.2EBITDA$149.0 $— $— $(24.1) $124.9Goodwill$348.1 $— $— $— $348.1Total assets$1,720.9 $— $— $18.3 $1,739.2Cash expenditures for property, plant and equipment$47.8 $— $— $0.6 $48.4Note 18 – Condensed Consolidating Financial InformationWe are a holding company and own no operating assets and have no significant operations independent of our subsidiaries. Obligations under our outstandingsenior notes and credit agreement are jointly and severally guaranteed by our wholly owned domestic subsidiaries. Legacy Crestwood GP and CrestwoodMidstream and its wholly owned subsidiaries do not guarantee our senior notes or credit facility. CEQP Finance Corp., the co-issuer, is our 100% ownedsubsidiary and has no material assets, operations, revenues or cash flows other than those related to its service as co-issuer of our senior notes. As discussed in Note 1, the accounting for the reverse acquisition of Legacy Inergy results in Legacy Inergy's historical operations being acquired on June 19,2013. Our senior notes are thus not included in the financial statements prior to June 19, 2013. Since Legacy Crestwood GP (the accounting predecessor) doesnot guarantee any debt, the condensed consolidated financial statements do not include 2012 or 2011 financial information.The tables below present condensed consolidating financial statements for us (parent) on a stand-alone, unconsolidated basis, and our combined guarantorand combined non-guarantor subsidiaries as of December 31, 2013 and for the year ended December 31, 2013. The financial information may not necessarilybe indicative of the results of operations, cash flows or financial position had the subsidiaries operated as independent entities.149Table of ContentsCRESTWOOD EQUITY PARTNERS LP (FORMERLY INERGY, L.P.)NOTES TO CONSOLIDATED FINANCIAL STATEMENTSCondensed Consolidating Balance SheetDecember 31, 2013(in millions) Parent GuarantorSubsidiaries Non-GuarantorSubsidiaries Eliminations ConsolidatedAssets Current assets: Cash and cash equivalents$0.1 $2.4 $2.7 $— $5.2Accounts receivable— 207.5 205.1 — 412.6Inventories— 66.6 7.0 — 73.6Other current assets— 25.8 10.2 (5.4) 30.6Total current assets0.1 302.3 225.0 (5.4) 522.0 Property, plant and equipment, net— 400.9 3,504.4 — 3,905.3Goodwill and intangible assets, net— 742.4 3,170.2 — 3,912.6Investment in subsidiary5,927.1 — — (5,927.1) —Other assets— 10.2 173.1 — 183.3Total assets$5,927.2 $1,455.8 $7,072.7 $(5,932.5) $8,523.2 Liabilities and partners' capital Current liabilities: Accounts payable$— $218.3 $160.7 $— $379.0Other current liabilities4.2 61.6 156.7 (5.4) 217.1Total current liabilities4.2 279.9 317.4 (5.4) 596.1 Long-term liabilities: Long-term debt, less current portion393.0 — 1,867.9 — 2,260.9Other long-term liabilities21.4 109.9 26.3 — 157.6Total long-term liabilities414.4 109.9 1,894.2 — 2,418.5 Partners' capital831.6 1,066.0 184.1 (1,250.1) 831.6Interest of non-controlling partners in subsidiaries4,677.0 — 4,677.0 (4,677.0) 4,677.0Total partners' capital5,508.6 1,066.0 4,861.1 (5,927.1) 5,508.6Total liabilities and partners' capital$5,927.2 $1,455.8 $7,072.7 $(5,932.5) $8,523.2150Table of ContentsCRESTWOOD EQUITY PARTNERS LP (FORMERLY INERGY, L.P.)NOTES TO CONSOLIDATED FINANCIAL STATEMENTSCondensed Consolidating Statements of OperationsYear Ended December 31, 2013(in millions) Parent GuarantorSubsidiaries Non-GuarantorSubsidiaries Eliminations ConsolidatedRevenues: Gathering and processing$— $— $216.3 $— $216.3NGL and crude services— 761.2 270.1 — 1,031.3Storage and transportation— 14.1 90.1 — 104.2Related party— — 82.1 (7.2) 74.9 — 775.3 658.6 (7.2) 1,426.7 Costs of product/services sold (excluding depreciation,amortization and accretion as shown below): Gathering and processing— — 24.1 — 24.1NGL and crude services— 699.6 230.4 — 930.0Storage and transportation— 7.0 8.7 — 15.7Related party— 7.2 32.5 (7.2) 32.5 — 713.8 295.7 (7.2) 1,002.3 Expenses: Operating and administrative— 41.3 156.8 — 198.1Depreciation, amortization and accretion— 26.0 141.9 — 167.9 — 67.3 298.7 — 366.0Other operating income (expense): Loss on contingent consideration— — (31.4) — (31.4)Other— (0.1) 1.3 — 1.2Operating income (loss)— (5.9) 34.1 — 28.2 Interest and debt expense, net(6.5) — (71.4) — (77.9)Other— 0.2 (0.1) — 0.1Equity in net income of subsidiary(43.9) — — 43.9 —Income (loss) before income taxes(50.4) (5.7) (37.4) 43.9 (49.6)Provision for income taxes0.2 0.1 0.7 — 1.0Net income (loss)(50.6) (5.8) (38.1) 43.9 (50.6)Net loss attributable to non-controlling partners insubsidiaries— — 57.3 — 57.3Net income (loss) attributable to partners$(50.6) $(5.8) $19.2 $43.9 $6.7 151Table of ContentsCRESTWOOD EQUITY PARTNERS LP (FORMERLY INERGY, L.P.)NOTES TO CONSOLIDATED FINANCIAL STATEMENTSCondensed Consolidating Statements of Comprehensive IncomeYear Ended December 31, 2013(in millions) Parent GuarantorSubsidiaries Non-GuarantorSubsidiaries Eliminations ConsolidatedNet income (loss)$(50.6) $(5.8) $(38.1) $43.9 $(50.6)Change in Suburban Propane Partners LP units(0.1) — — — (0.1)Comprehensive income (loss)$(50.7) $(5.8) $(38.1) $43.9 $(50.7)152Table of ContentsCRESTWOOD EQUITY PARTNERS LP (FORMERLY INERGY, L.P.)NOTES TO CONSOLIDATED FINANCIAL STATEMENTSCondensed Consolidating Statements of Cash FlowsYear Ended December 31, 2013(in millions) Parent GuarantorSubsidiaries Non-GuarantorSubsidiaries Eliminations ConsolidatedCash flows from operating activities:$— $1.8 $186.5 $— $188.3 Cash flows from investing activities: Acquisitions, net of cash acquired— 5.9 (561.5) — (555.6)Purchases of property, plant and equipment— (12.4) (334.6) — (347.0)Investment in unconsolidated affiliates, net— — (151.5) — (151.5)Distributions received and other76.0 17.0 11.1 (92.9) 11.2Net cash provided by (used in) investing activities76.0 10.5 (1,036.5) (92.9) (1,042.9) Cash flows from financing activities: Proceeds from the issuance of long-term debt— 394.1 2,072.8 — 2,466.9Principal payments on long-term debt— (333.3) (1,634.3) — (1,967.6)Distributions paid(76.0) (59.1) (155.2) 92.9 (197.4)Distributions paid to non-controlling partners— — (204.5) — (204.5)Net proceeds from the issuance of common units— — 714.0 — 714.0Proceeds from issuance of preferred equity— — 96.1 — 96.1Other0.1 (11.6) (36.3) — (47.8)Net cash provided by (used in) financing activities(75.9) (9.9) 852.6 92.9 859.7 Net increase in cash0.1 2.4 2.6 — 5.1Cash at beginning of period— — 0.1 — 0.1Cash at end of period$0.1 $2.4 $2.7 $— $5.2153Table of ContentsCRESTWOOD EQUITY PARTNERS LP (FORMERLY INERGY, L.P.)NOTES TO CONSOLIDATED FINANCIAL STATEMENTSNote 19 - Quarterly Financial Data (Unaudited)Summarized unaudited quarterly financial data is presented below (in millions, except per unit information): Quarter Ended March 31 June 30 September 30 December 31 2013 Revenues$72.4 $118.9 $427.2 $808.2 Operating income (loss)15.7 7.8 15.8 (11.1)(b) Earnings (loss) from unconsolidated affiliates— — (0.4) 0.3 Net income (loss)3.9 (4.5) (7.9) (42.1) Net income (loss) attributable to partners5.1 1.6 (8.3) 8.3 Net income (loss) per limited partner unit:(a) Basic(c)$0.13 $0.03 $(0.05) $0.04 Diluted(c)$0.13 $0.03 $(0.05) $0.04 2012 Revenues$53.8 $55.2 $63.0 $67.5 Operating income12.4 17.5 18.3 13.2 Net income4.5 8.3 9.1 2.5 Net income attributable to partners3.3 3.4 6.0 2.2 Net income per limited partner unit:(a) Basic$0.08 $0.09 $0.15 $0.06 Diluted$0.08 $0.09 $0.15 $0.06 (a)Basic and diluted net income for the quarter ended March 31, 2013 and each of the quarters ended December 31, 2012, were calculated based on the presumption that thecommon and subordinated units issued to acquire Legacy Crestwood GP (the accounting predecessor) were outstanding for the entire period prior to the June 19, 2013acquisition.(b)Includes a $31.4 million loss on contingent consideration which reflects the fair value of an earn-out premium associated with the original acquisition of our Antero assets. SeeNotes 4 and 15 for a further discussion of this non-cash charge.(c)The accumulation of basic and diluted net income (loss) per limited partner unit does not total the amount for the year due to changes in ownership percentages throughout theyear.154Table of ContentsCRESTWOOD EQUITY PARTNERS LP (FORMERLY INERGY, L.P.)NOTES TO CONSOLIDATED FINANCIAL STATEMENTSThe following table is a summary of the purchase accounting adjustments recorded during the fourth quarter related to the Crestwood Merger (in millions): Current Estimate(a) Preliminary Estimate(b) Adjustment Basedon RevisedValuation ReportCurrent assets$224.5 $222.7 $1.8Property, plant and equipment2,088.2 2,259.7 (171.5)Intangible assets337.5 315.0 22.5Other assets12.7 12.7 —Total identifiable assets acquired2,662.9 2,810.1 (147.2) Current liabilities207.5 208.9 (1.4)Long-term debt1,079.3 1,079.3 —Other long-term liabilities146.6 213.1 (66.5)Total liabilities assumed1,433.4 1,501.3 (67.9) Net identifiable assets acquired1,229.5 1,308.8 (79.3)Goodwill2,149.9 2,564.4 (414.5)Net assets acquired$3,379.4 $3,873.2 $(493.8)(a)See Note 4 for additional information related to the December 31, 2013 estimate of the fair values of the assets acquired and liabilities assumed at June 19, 2013, the date of themerger.(b)Preliminary estimate recorded as of September 30, 2013.The changes from the preliminary estimate were based on additional valuation information obtained on the components that comprise the enterprise fair valueof Legacy Inergy as well as certain of our storage and transportation assets and obligations, primarily related to our Tres Palacios storage operations. Theimpact of these adjustments on depreciation and amortization expense was not material to any quarters. These revised estimates continue to be preliminary andare subject to material change pending the final valuation of these assets and liabilities. 155Table of ContentsSIGNATURESPursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalfby the undersigned, thereunto duly authorized. CRESTWOOD EQUITY PARTNERS LP By Crestwood Equity GP, LLC (its general partner) Dated:February 28, 2014By/s/ ROBERT G. PHILLIPS Robert G. Phillips President, Chief Executive Officer and DirectorPursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following officers and directors of CrestwoodEquity GP, LLC, as general partner of Crestwood Equity Partners LP, the registrant, in the capacities and on the dates indicated.Date Signature and TitleFebruary 28, 2014 /S/ ROBERT G. PHILLIPS Robert G. Phillips,President, Chief Executive Officer and Director(Principal Executive Officer) February 28, 2014 /S/ MICHAEL J. CAMPBELL Michael J. Campbell,Senior Vice President and Chief Financial Officer(Principal Financial Officer) February 28, 2014 /S/ STEVEN M. DOUGHERTY Steven M. Dougherty,Senior Vice President and Chief Accounting Officer(Principal Accounting Officer) February 28, 2014 /S/ ALVIN BLEDSOE Alvin Bledsoe, Director February 28, 2014 /S/ MICHAEL G. FRANCE Michael G. France, Director February 28, 2014 /S/ WARREN H. GFELLER Warren H. Gfeller, Director February 28, 2014 /S/ ARTHUR B. KRAUSE Arthur B. Krause, Director February 28, 2014 /S/ RANDY E. MOEDER Randy E. Moeder, Director February 28, 2014 /S/ JOHN J. SHERMAN John J. Sherman, Director February 28, 2014 /S/ JOHN W. SOMERHALDER II John W. Somerhalder II, Director February 28, 2014 /S/ DAVID M. WOOD David M. Wood, Director156Table of ContentsSchedule ICrestwood Equity Partners LP (Formerly Inergy, L.P.)Parent OnlyCondensed Balance Sheet(in millions, except unit information) December 31, 2013Assets Current assets: Cash and cash equivalents$0.1Total current assets0.1 Investment in subsidiaries5,927.1Total assets$5,927.2 Liabilities and partners’ capital Current liabilities: Accrued expenses$2.0Current portion of long-term debt2.2Total current liabilities4.2 Long-term debt, less current portion393.0Other long-term liabilities21.4 Total partners’ capital5,508.6Total liabilities and partners’ capital$5,927.2 See accompanying notes to condensed financial statements.157Table of ContentsSchedule ICrestwood Equity Partners LP (Formerly Inergy, L.P.)Parent OnlyCondensed Statement of Operations(in millions) Year EndedDecember 31, 2013 Operating income$—Interest expense, net(6.5)Equity in net income of subsidiaries(43.9)Loss before income taxes(50.4)Provision for income taxes0.2Net loss$(50.6)See accompanying notes to condensed financial statements.158Table of ContentsSchedule ICrestwood Equity Partners LP (Formerly Inergy, L.P.)Parent OnlyCondensed Statement of Comprehensive Income(in millions) Year EndedDecember 31, 2013 Net loss$(50.6)Change in unrealized fair value on cash flow hedges(0.1)Comprehensive loss$(50.7)See accompanying notes to condensed financial statements.159Table of ContentsSchedule ICrestwood Equity Partners LP (Formerly Inergy, L.P.)Parent OnlyCondensed Statement of Cash Flows(in millions) Year EndedDecember 31, 2013Cash flows from operating activities$— Cash flows from investing activities76.0 Cash flows from financing activities: Proceeds from the issuance of long-term debt—Principal payments on long-term debt—Distributions paid(76.0)Distributions received—Other0.1Net cash provided by (used in) financing activities(75.9) Net increase (decrease) in cash0.1Cash at beginning of period—Cash at end of period$0.1See accompanying notes to condensed financial statements.160Table of ContentsSchedule ICrestwood Equity Partners LP (Formerly Inergy, L.P.)Parent OnlyNotes to Condensed Financial StatementsNote 1. Basis of PresentationIn the parent-only financial statements, our investment in subsidiaries is stated at cost plus equity in undistributed earnings of subsidiaries since the date ofacquisition. Our share of net income of our unconsolidated subsidiaries is included in consolidated income using the equity method. The parent-onlyfinancial statements should be read in conjunction with our consolidated financial statements. 161Table of ContentsSchedule IICrestwood Equity Partners LP (Formerly Inergy, L.P.)Valuation and Qualifying Accounts(in millions)Year Ended December 31,Balance atbeginningof period Chargedto costs andexpenses OtherAdditions Deductions(write-offs) Balanceat endof periodAllowance for doubtful accounts 2013$— $(1.1) $1.2 $— $0.12012— — — — —2011— — — — —162Exhibit 10.4EMPLOYMENT AGREEMENTThis Employment Agreement (“Agreement”), is made and entered into as of the 1st day of January, 2014, (the “EffectiveDate”) between Crestwood Operations LLC, a Delaware limited liability company (“Employer”), and Heath Deneke (“Employee”).W I T N E S S E T H:WHEREAS, Employer desires to employ Employee, and Employee desires to be employed by Employer, pursuant to theterms and conditions set forth in this Agreement;NOW, THEREFORE, for and in consideration of the mutual promises, covenants, and obligations contained herein,Employer and Employee agree as follows:SECTION 1: EMPLOYMENT AND DUTIES.1.1 Employer agrees to employ Employee, and Employee agrees to be employed solely by Employer, beginning as of theEffective Date and, except as set forth below, continuing through December 31, 2015 (the “Initial Term”), unless earlier terminatedpursuant to Section 3 of this Agreement. Following expiration of the Initial Term, this Agreement will be automatically renewed forsuccessive 1-year terms following the Initial Term (each, a “Renewal Term” and, together with the Initial Term, the “Term”) unlesseither party gives the other party no less than 30 days’ written notice prior to the expiration of the Term of such Party’s intent not torenew the Agreement (a “Notice of Non-Renewal”). Notwithstanding the foregoing, the Term (including any Renewal Terms) andEmployee’s employment pursuant to this Agreement may be terminated at any time as set forth below, subject to the terms of thisAgreement. At the expiration of the Term following delivery of a Notice of Non-Renewal, Employee’s employment with Employer(and any affiliates or assignees of Employer) shall terminate, and this Agreement shall have no further force or effect except withrespect to Employee’s obligations pursuant to Section 3.5.1.2 Beginning as of the Effective Date, Employee shall be employed as Senior Vice President, Crestwood GP and President,Natural Gas. Employee shall also serve in such other executive capacities as may be reasonably requested from time to time byEmployer or the Board of Directors (the “Board”) of the Employer, and shall report directly to the Chief Executive Officer of theEmployer. Employee agrees to perform diligently and to the best of Employee’s abilities, and in a trustworthy, competent, businesslike,and efficient manner, the duties and services pertaining to any such position as reasonably determined by Employer, as well as suchadditional or different duties and services that Employee from time to time may be reasonably directed to perform by Employer.Employee shall, during the period of Employee’s employment by Employer, devote Employee’s full business time, energy, and bestefforts to the business and affairs of Employer.1.3 Employee shall at all times comply with and be subject to such policies and procedures that Employer may establish fromtime to time for Employer’s executives and employees, including,1HOU:0024197/00043:1712692v2Exhibit 10.4without limitation, Employer’s Code of Business Conduct as adopted by Employer and as amended from time to time (the “Code ofBusiness Conduct”).1.4 Except with the advance written permission of the Board and with respect to Employee’s existing directorships identifiedon Exhibit A hereto, Employee may not engage or participate, directly or indirectly, in any other business, investment, or activity that(a) could interfere with Employee’s performance of Employee’s duties hereunder, (b) is contrary to the best interests of Employer,Crestwood Equity Partners, LP, Crestwood Midstream Partners, LP, or any of their respective subsidiaries (each a “Related Entity”), or(c) requires any significant portion of Employee’s business time. Notwithstanding the foregoing, the parties recognize that Employeemay engage in passive personal investments and other non-competitive business activities that do not conflict with the business andaffairs of Employer or any Related Entities or materially interfere with Employee’s performance of Employee’s duties hereunder;provided, that with the exception of any civic, charitable, or educational boards or committees that do not unreasonably interfere withEmployee’s performance of Employee’s duties hereunder, Employee may not serve as a manager or on the board of directors or similarbody of any entity other than Employer or a Related Entity during the Term without prior approval therefor by the Board.1.5 Employee acknowledges and agrees that Employee has a fiduciary duty of loyalty, fidelity, and allegiance to act at all timesin the best interests of Employer and the other Related Entities and to do no act that could, directly or indirectly, injure any such entity’sbusiness, interests, or reputation. In furtherance of the foregoing, Employee shall present to the Employer all material businessopportunities or ventures known to Employee, independently or with others, that are within the purposes of Employer or any RelatedEntity, including, without limitation, opportunities that may compete with Employer or a Related Entity or could reasonably beexpected to be implemented by Employer or a Related Entity. It is agreed that any direct or indirect interest in connection with, or anybenefit from, any outside activities, particularly commercial activities, which might in any way adversely affect Employer or any of theRelated Entities involves a possible conflict of interest. In keeping with Employee’s fiduciary duties to Employer, Employee agrees thatduring the employment relationship Employee shall not knowingly become involved in a conflict of interest with Employer or any ofthe Related Entities, whether directly or indirectly through a spouse or other family member, or upon discovery thereof, allow such aconflict to continue. Moreover, Employee agrees that Employee shall disclose to the Employer any facts which might involve such aconflict of interest that has not been approved in writing by the Employer.SECTION 2: COMPENSATION AND BENEFITS.2.1 Employee’s base salary during the Term shall be Four Hundred Thirty-Five Thousand Dollars ($435,000) per annum,subject to increase at the discretion of the Board (“Base Salary”), which shall be paid in accordance with Employer’s standard payrollpractice. In addition to the Base Salary, Employee shall be eligible to be considered for a target bonus (a “Bonus”) in each calendar yearduring the Term, payable in accordance with and pursuant to Employer’s then-current2HOU:0024197/00043:1712692v2Exhibit 10.4bonus plan (“Bonus Plan”). For the 2014 bonus year, the target bonus for Employee will be equal to 90% of his Base Salary and shall besubject to such terms and conditions as are established by the Board (including, if applicable, its Compensation Committee) for awards ofequity compensation made to similarly situated executives of the Employer. Thereafter, the target bonus for Employee will becomparable to the bonus opportunity provided to similarly situated executives of the Employer. The Bonus Plan will be implementedand administered by the Board, and any Bonuses payable thereunder shall be based upon a number of factors determined and set by theBoard in its sole discretion. Such factors may include, but not be limited to, the achievement by Employer of certain performanceobjectives, and the operation of Employer within the budgets approved by the Board. Employee must be employed by Employer at thetime a Bonus is declared as a condition of receiving any such Bonus.2.2 During the Term, Employee shall be eligible to receive annual awards under the terms of the Crestwood Equity PartnersLP Long Term Incentive Plan and the Crestwood Midstream Partners LP Long Term Incentive Plan. For the 2014 grant cycle, theEmployee shall receive an award of restricted units, with a total target equity grant level for Employee equal to 175% of his BaseSalary. These restricted units will be granted equally from both plans and shall be subject to such terms and conditions as are establishedby the Board (including, if applicable, its Compensation Committee) for awards of equity compensation made to similarly situatedexecutives of the Employer. Thereafter, the target grant level for Employee will be comparable to the level of equity granted tosimilarly situated executives of the Employer, provided such grants shall be made at the discretion of the Board. Equity awards grantedto Employee under the foregoing plans shall include provisions that provide for accelerated vesting in the event of a Change in Control,upon termination of Employee’s employment by the Employer without Cause, or upon Employee’s resignation with Employee Cause(for purposes of this Section 2.2 only, each of “Change in Control,” “Cause” and “Employee Cause” to be as such terms are defined inthe respective award agreements). Notwithstanding the foregoing, the level of equity compensation to be awarded to the Employee forthe 2014 and 2015 grant cycles shall be reduced to reflect his prior award of incentive units in Crestwood Holdings Partners LLC. Forthe 2014 grant cycle, the Employee shall receive 1/3 of what would otherwise be the recommended equity awards proposed by theCompensation Committees of Crestwood Equity Partners LP and Crestwood Midstream Partners LP. For the 2015 grant cycle, theEmployee shall receive 2/3 of such recommended equity awards.2.3 During the Term, Employer shall pay or reimburse Employee for all reasonable and customary business expensesactually incurred by Employee during the Term in the course of Employee’s employment; provided that such expenses are incurredand accounted for in accordance with Employer’s applicable policies and procedures. Employer shall provide to Employeeofficer/director liability insurance coverage to cover any claims that may be made arising from Employee’s past, present, or futureactivities on behalf of Employer or any Related Entity, in the same manner and of the same kind as such insurance is provided to theother officers and directors of Employer.2.4 During the Term, Employer shall furnish Employee with such fringe benefit programs that are maintained by Employerand that are made available to Employer’s management3HOU:0024197/00043:1712692v2Exhibit 10.4generally, under the same terms as those provided to Employer’s management generally. Employee shall bear any tax effects orobligations stemming from any such policies and programs or their amounts.2.5 Employee acknowledges that Employee shall have no vested rights under or in respect of Employee’s participation in anyemployee benefit program, plan, or coverage except as expressly provided under the terms thereof. Notwithstanding anything in thisAgreement, it is specifically understood and agreed that Employer shall not be obligated to institute, maintain, or refrain from changing,amending, or discontinuing any employee benefit program, plan, or coverage applicable to Employee, so long as any such actions orinactions in this regard by Employer are similarly applicable to covered executive employees of Employer generally.2.6 Employee shall be entitled to six (6) weeks of paid vacation per calendar year, to be provided in accordance withEmployer’s standard policy and to be taken at such time as mutually agreed by Employee and Employer.SECTION 3: TERMINATION OF EMPLOYMENT AND EFFECTS OF SUCH TERMINATION.3.1 Termination Generally. Employee’s employment with Employer (a) shall be terminated prior to the end of the Term (i)upon the death of Employee, or (ii) upon Employee’s Permanent Disability (as defined below), and (b) may be terminated prior to theend of the Term (i) at any time by Employer upon notice to Employee, (ii) at any time by Employee upon thirty (30) days’ prior writtennotice to Employer, or (iii) at any time by Employee if Employee has Employee Cause and complies with the notice proceduresdescribed below. The date of termination is referred to herein as the “Termination Date.”3.2 Bad Leaver Termination. If Employee’s employment is terminated under any of the circumstances set forth in Section3.2(a), Employee shall be entitled to receive only the benefits set forth in Section 3.2(b) below:(a) Bad Leaver Conditions.(i) Termination by Employer for Employer Cause. Employer termination of Employee’s employment for“Employer Cause” shall mean termination by Employer for any of the following: if Employee (a) has been indicted or convicted of, orhas entered a plea of guilty or nolo contendere to, a felony charge or crime involving moral turpitude, or, in the course of Employee’semployment has engaged in fraudulent or criminal activity (whether or not prosecuted), (b) has failed to follow reasonable directions ofEmployer, provided that the foregoing failure shall not be “Employer Cause” if Employee in good faith believes that such direction isillegal and promptly so notifies the Board, (c) has failed to devote all of Employee’s professional time to the Employer and affiliates ofEmployer, except as permitted by the Employer, (d) has materially breached any policy or code of conduct of the Employer, (e) hasmaterially breached any4HOU:0024197/00043:1712692v2Exhibit 10.4provision of this Agreement or any other agreement between Employee and the Employer or Related Entity, (f) has received a kickbackor rebate of any fee or expense paid by Employer, (g) has engaged in the use of illegal drugs, the persistent excessive use of alcohol, orany other activity that materially impairs Employee’s ability to perform Employee’s duties hereunder or results in conduct bringingEmployer or any Related Entity into substantial public disgrace or disrepute, or (h) engages in intentional, reckless, or grossly negligentconduct that has or is reasonably likely to have a material adverse effect on Employer or any Related Entity; provided, however, thatwith respect to subsections (c), (d) and (e) of this Section 3.2(a)(i), the Board may elect, in its sole discretion, to allow Employee aperiod of time as determined by the Board to cure the act, conduct or event constituting Employer Cause under such subsections.(ii) Employee Resignation. Employee resigns for any reason other than having Employee Cause (as definedbelow in Section 3.3(a)(i)).(b) Bad Leaver Consequences.(i) Employee shall be entitled to receive, within 30 days of the Termination Date or such shorter period asmay be required by applicable state law, any Base Salary that was accrued (on a pro rata basis) but unpaid as of the Termination Date(“Accrued Salary”) and such other benefits provided to Employee pursuant to the terms of Employer’s employee benefit plans(which, for the avoidance of doubt, does not include any Bonus payments) that were accrued by Employer in its books and records, butnot forfeited, cancelled, or previously paid, as of the Termination Date (“Accrued Benefits,” or, collectively with Accrued Salary,“Accrued Compensation”); and(ii) Except for Accrued Compensation, Employee shall forfeit, from and after the Termination Date,Employee’s rights to any and all future compensation from Employer or any Related Entity to which Employee may be entitled and toall future benefits for which Employee may be eligible, in either case under this Agreement or otherwise, including without limitationany Bonus payments (including any earned but unpaid Bonus payments or portions thereof) that would have been payable had Employeeremained employed through the date such Bonus payments would have been paid. Except for Accrued Compensation, Employer’sobligations to pay or provide Employee with future compensation or benefits shall fully and forever cease and terminate as of theTermination Date.3.3 Good Leaver Termination. Subject to Section 3.8, if Employee’s employment is terminated under any of thecircumstances set forth in Section 3.3(a), and Employee complies with the requirements of Section 3.7, Employee shall be entitled toreceive Accrued Compensation as well as the benefits set forth in Section 3.3(b) below (“Severance Benefits”):(a) Good Leaver Conditions.5HOU:0024197/00043:1712692v2Exhibit 10.4(iii) Employee Resignation with Employee Cause. “Employee Cause” will exist if one of the followingoccurs: (A) a substantial and continuing diminution in the nature of Employee’s responsibilities (provided, however, that neither achange in Employee’s reporting relationship, nor a diminution in responsibilities as a result of Employer exercising its rights underSection 3.7 will trigger this provision); (B) a material breach by Employer of any material provision of this Agreement; (C) a materialand continuing reduction in the aggregated total of Employee’s Base Salary, target Bonus percentage and target equity percentage; or (D)reassignment by the Company of the Employee’s principal place of employment to a location more than fifty (50) miles from hisprincipal place of employment on the Effective Date, but excluding normal business travel consistent with Employee’s duties,responsibilities and position. For Employee to terminate for Employee Cause: (i) Employer must be notified by Employee in writingwithin 30 days of the date Employee becomes aware of the event that would allow Employee to terminate employment for EmployeeCause, with such notice setting forth such event in reasonable detail; (ii) the event must remain uncorrected by Employer for 30 daysfollowing Employer’s receipt of such notice (the “Notice Period”); and (iii) such termination must occur within 30 days after theexpiration of the Notice Period.(iv) Employer Termination without Cause. Employer Termination without Cause shall mean termination byEmployer for any reason other than for Employer Cause.(v) Death. Death shall mean Employee’s death.(vi) Permanent Disability. Termination due to Employee’s “Permanent Disability” shall mean the inabilityof Employee, with or without reasonable accommodation, by reason of illness, incapacity, or other disability, to perform Employee’sduties or fulfill Employee’s employment obligations to Employer, as determined by the Board and as certified in writing by a competentmedical physician chosen by the Board, for a cumulative total of 180 days in any 12 month period; provided, however, that such periodof absence may be extended if required by applicable law.(b) Good Leaver Consequences.(i) A severance payment equal to two (2) times the sum of (A) the Base Salary calculated as of theTermination Date or, if greater, before any reduction not consented to by the Employee and (B) the average of the annual Bonus paid toEmployee for the prior two (2) year period. In the event Employee has not worked one full bonus year as of the Termination Date, theamount for purposes of Section 3.3(b)(i)(B) shall be Employee’s target Bonus amount for 2014 pursuant to Section 2.1; and in the eventEmployee has only worked one full bonus year as of the Termination Date, the amount for purposes of Section 3.3(b)(i)(B) shall beshall be the average of the annual Bonus paid to Employee for the prior year and Employee’s target Bonus amount for 2014 pursuant toSection 2.1. The severance payment shall be paid in equal installments in accordance with the Employer’s normal payroll proceduresover the period commencing on the Termination Date and ending on the date that is twelve (12) months following the TerminationDate; provided,6HOU:0024197/00043:1712692v2Exhibit 10.4however that in the event that (1) Employee serves a Severance Waiver Notice in accordance with Section 4.1, or (2) Employeeviolates any of the covenants set forth in this Agreement or in any separation agreement, general release, or similar agreement withEmployer, Employee shall thereafter forfeit the right to receive any further severance payment installments payable hereunder.During the period that Employee is entitled to receive severance payments pursuant to this Section 3.3(b), the Employer shall alsoprovide medical benefits to Employee under terms and conditions that are not less favorable than provided to executive officers of theEmployer; provided, however, that (X) Employee must elect to receive continuation of health insurance coverage pursuant to theConsolidated Omnibus Budget Reconciliation Act (COBRA); (Y) Employee will be required to pay the amount that an active employeeof the Employer would pay to receive such coverage and the Employer will be responsible for the employer portion of the insurancepremium payments (which amount will be treated as imputed income to the Employee); and (Z) the Employer’s obligation to pay aportion of the Employee’s COBRA premiums shall cease on the first day of the month after Employee obtains reasonably comparablehealth care coverage from a subsequent employer or other source.(ii) Except as set forth in this Section 3.3(b) and as provided in Section 2.2, from and after the TerminationDate, (A) Employee forfeits Employee’s rights to any and all compensation from Employer or any Related Entity to which Employeemay be entitled and to all future benefits for which Employee may be eligible, in either case under this Agreement or otherwise,including without limitation any Bonus payments (excluding Employee’s Bonus payment for the calendar year of termination, pro-ratedfor the portion of the calendar year of termination during which Employee was employed by Employer, such pro-rated Bonus to bepayable on the date that such bonuses are otherwise paid by the Employer to its employees), and (B) Employer’s obligations to pay orprovide Employee with any such future compensation or future benefits shall fully and forever cease and terminate.(iii) If Employee’s employment is terminated by reason of Employee’s death, Employee’s estate will beentitled to payment of all amounts due under Section 3.3(b). If Employee’s employment is terminated because of Employee’sPermanent Disability, Employee’s legal guardian will be entitled to payment of the amounts due under Section 3.3(b) in accordancewith the terms and conditions set forth therein.3.4 Expiration. If the Agreement expires and Employee’s employment terminates as a result of the delivery of a Notice ofNon-Renewal by Employer to Employee, Employee shall be entitled to receive the Severance Benefits provided pursuant to the termsand conditions of Section 3.3(b); provided, however, that if Employer terminates the Agreement and Employee’s employment forEmployer Cause following Employee’s delivery of a Notice of Non-Renewal but prior to the expiration of the Term, or Employeerefuses to remain employed through the expiration of the Term, Employee shall forfeit and not be entitled to the Severance Benefits. Ifthe Agreement expires and Employee’s employment terminates as a result of the delivery of a Notice of Non-Renewal by7HOU:0024197/00043:1712692v2Exhibit 10.4Employee to Employer, Employee shall only be entitled to receive the Accrued Compensation pursuant to the terms and conditions ofSection 3.2(b).3.5 Continuing Obligations. Termination or expiration of this Agreement and the employment relationship does not terminatethose obligations of Employee imposed by this Agreement that are continuing obligations, including, without limitation, Employee’sobligations under Section 4.3.6 Post-Termination Assistance. During any period during which any Severance Benefits or other monies are being paid toEmployee under this Agreement after the Termination Date, Employee shall provide to Employer reasonable levels of assistance toEmployer in answering questions or otherwise cooperating concerning the business of Employer, transition of responsibility, orlitigation; provided that Employee shall be fully and promptly reimbursed for all out of pocket expenses of Employee reasonablyincurred in connection with such assistance and any such assistance after the period during which any Severance Benefits or othermonies are being paid shall not interfere or conflict with the obligations that Employee may owe to any other employer.3.7 Reduction or Alteration in Duties. When either the Employer or Employee serves a notice of termination or a Notice ofNon-Renewal, the Employer will have the right in its absolute discretion to (i) assign reduced, alternative, or no duties to the Employee,and require the Employee to act as directed by the Employer, including excluding the Employee from the premises of the Employer orother Related Entity, and (ii) prohibit the Employee from discussing the Employee’s termination with employees, agents, or any thirdparty except with respect to Employee’s communication with federal, state or local governmental agencies as may be legally required orotherwise protected by law; provided, however, that in the event of a reduction or alteration of duties in accordance with Section 3.7(i),Employer will still be required to make the Base Salary payments pursuant to Section 2.1 through the date of termination ofEmployee’s employment.3.8 Release. As a condition to the payment of any severance benefit hereunder, including the Severance Benefits, Employer,in its sole discretion, may require Employee (or Employee’s executor, legal guardian, or other legal representative in the case of theEmployee’s death or Permanent Disability) to first execute and not revoke a waiver and release of all claims against Employer and theRelated Entities in a form reasonably acceptable to Employer within 21 days following the Termination Date.3.9 Forfeiture of Benefits. Except as otherwise provided in Section 4.1 hereof, in the event Employee breaches any ofEmployee’s obligations under Section 4 of this Agreement, and if Employee is otherwise entitled to receive Severance Benefits underSection 3.3, Employee shall fully, completely, and permanently forfeit any and all rights to such Severance Benefits, and Employerand each Related Entity shall have the right to fully, completely, and permanently terminate payment of any amounts to whichEmployee would otherwise be entitled pursuant to these provisions and recover the amount equal to the Severance Benefits previouslypaid to Employee under Section 3.3. The foregoing forfeiture of rights to the Severance Benefits shall not in any way limit or restrict8HOU:0024197/00043:1712692v2Exhibit 10.4Employer’s rights and remedies pursuant to Section 4, including the right to seek injunctive relief to enforce compliance with suchobligations and to recover damages for any breach. Employee agrees that all disputes relating to Employee’s employment or terminationof employment shall be resolved through Employer’s Dispute Resolution Plan as provided in Section 5.6 hereof.3.10 Severance Benefits Not an Offer of Employment. The payment of any Severance Benefits or other monies toEmployee under this Agreement after the Termination Date shall not constitute an offer or a continuation of employment of Employee.In no event shall Employee represent or hold himself out to be an employee of Employer after the Termination Date. Except whereEmployer is required by law to withhold any federal, state, or local taxes, Employee shall be responsible for any and all federal, state, orlocal taxes that arise out of any payments to Employee hereunder.3.11 Recharacterization of Termination. Notwithstanding any other provision of this Agreement, if following the terminationof employment Employer discovers that grounds existed as of the Termination Date for a termination for Employer Cause, then suchtermination shall be deemed to be a termination for Employer Cause and Employee shall only be entitled to the payments and benefitsprovided in Section 3.2. In the event Employee’s termination is reclassified as a termination for Employer Cause pursuant to thisSection 3.11, Employee’s termination shall be so treated and classified for all purposes under this Agreement and any other agreementsbetween Employee and Employer, and Employee shall repay to Employer any monies or benefits received by Employee followingtermination to which Employee would not have been entitled upon being terminated for Employer Cause.SECTION 4: COVENANT NOT TO COMPETE; CONFIDENTIALITY.4.1 Non-Compete. The parties hereto recognize that Employee is retained by Employer as part of a professional, management,and executive staff of Employer whose duties include the formulation and execution of management policy. Therefore, in exchange forthe consideration specified herein and as a material incentive for Employer to enter into this Agreement, and to enforce Employee’sobligations regarding confidentiality pursuant to Section 4.5 hereof, Employee hereby agrees that during the term of Employee’semployment hereunder (including any period of employment in which Employee has reduced or altered duties pursuant to Section 3.7)and, in the event of a termination of Employee’s employment pursuant to Section 3.3 (Good Leaver Termination), for a period oftwelve (12) months following the Termination Date (the “Non-Compete Period”), Employee shall not, within North America, act orengage in material competition with the activities or plans of Employer or any Related Entity as they exist up to the time of Employee’stermination of employment. “Material Competition” by Employee shall mean (A) engaging in or conducting any business orinvestment activity in any capacity that directly competes with or has a material adverse economic effect on any of the material businessactivities or business plans of Employer or any Related Entity, or with respect to a business or asset that was being evaluated byEmployer or any Related Entity at any time during the Term and prior to the termination of9HOU:0024197/00043:1712692v2Exhibit 10.4employment, or (B) rendering advice or services to, whether as an employee, consultant, advisor, agent, shareholder, independentcontractor, investor, partner, member, owner, or otherwise, any company, business or other entity that derives a material part of itsbusiness from activities that directly compete with the business activities or business plans of Employer or any Related Entity; provided,however, that Employee shall be permitted to acquire a passive stock interest in such a business provided that the stock acquired ispublicly traded and Employee does not beneficially own more than 2% of the outstanding interest in such business. Notwithstanding theforegoing, at any time during the eighteen-month period following the Termination Date, Employee may, at Employee’s option, serveon the Employer a written notice waiving the right to any and all future installments of the Severance Benefit payments pursuant toSection 3.3(b)(i) (a “Severance Waiver Notice”), and upon delivery of the Severance Waiver Notice, Employee shall no longer bebound by the restrictions set forth in this Section 4.1 for the period on and after the date on which the Severance Waiver Notice isdelivered to the Employer; provided, however, that notwithstanding the delivery of a Severance Waiver Notice, Employee willcontinue to be bound by the remaining obligations set forth in this Agreement, including but not limited to those covenants of Employeeset forth in Section 4.2 and Section 4.5 hereof.4.2 Non-Solicit. During the term of Employee’s employment hereunder (including any period of employment in whichEmployee has reduced or altered duties pursuant to Section 3.7) and for a period of eighteen (18) months following the TerminationDate (the “Non-Solicitation Period”), Employee will not, directly or indirectly, solicit or induce (i) any person who is employed byEmployer or any of the Related Entities or was so employed within the six-month period prior to the Termination Date (A) to interferewith the activities or businesses of Employer or any Related Entity or (B) to discontinue such person’s employment with Employer orany of the Related Entities, nor shall Employee (or any business or entity with which Employee is then involved) employ any suchperson or (ii) any customer of Employer to discontinue or reduce its business with Employer (either through the transition of suchbusiness to a competitor of Employer or otherwise); provided, however, that general solicitation of the public for employment shall notconstitute a solicitation hereunder so long as such general solicitation is not designed to target any such person.4.3 Recognition of Limitations as Reasonable. Employee understands that the provisions of Sections 4.1 and 4.2 hereof maylimit Employee’s ability to earn a livelihood in a business similar to the business in which Employee is involved, but as a member of themanagement group of Employer Employee nevertheless agrees and hereby acknowledges that (i) such provisions do not impose agreater restraint than is necessary to protect the goodwill, trade secrets, or other business interests of Employer and any of the RelatedEntities; (ii) such provisions contain reasonable limitations as to time, scope of activity, and geographical area to be restrained; and (iii) theconsideration provided hereunder, including without limitation, any amounts or benefits provided under Section 3 hereof and theConfidential Information provided pursuant to Section 4.5, is sufficient to compensate Employee for the restrictions contained inSections 4.1 and 4.2 hereof. In consideration of the foregoing and in light of Employee’s education, skills, and abilities, Employee agreesthat Employee will not assert that, and it should not be considered that, any provisions of10HOU:0024197/00043:1712692v2Exhibit 10.4Section 4.1 or 4.2 otherwise are void, voidable, or unenforceable or should be voided or held unenforceable.4.4 Modifications to Section 4. If, at the time of enforcement of Section 4 of this Agreement, a court shall hold that the period,scope, or geographical area restrictions stated herein are unreasonable under circumstances then existing, the parties hereto agree thatthe maximum period, scope, or geographical area reasonable under such circumstances shall be substituted for the stated period, scope,or geographical area and that the court shall revise the restrictions contained herein to cover the maximum period, scope, andgeographical area permitted by law. If, in any proceeding, a court refuses to enforce all of the separate covenants deemed included hereinbecause, taken together, they are deemed more extensive than necessary to assure Employer of the intended benefit of this Agreement,it is expressly understood and agreed that those of such covenants or portions of such covenants that, if eliminated, would permit theremaining separate covenants or portions thereof to be enforced in such proceeding shall, for the purpose of such proceeding, be deemedeliminated from the provisions hereof. Employee acknowledges that Employee is a member of Employer’s management group withaccess to Employer’s confidential business information and Employee’s services are unique to Employer and the Related Entities.Employee therefore agrees that the remedy at law for any breach by Employee of any of the covenants and agreements set forth in thisSection 4 will be inadequate and that in the event of any such breach, Employer may, in addition to the other remedies that may beavailable to it at law, apply to any court of competent jurisdiction to obtain specific performance and/or injunctive relief prohibitingEmployee (together with all those persons associated with Employee) from the breach of such covenants and agreements and toenforce, or prevent any violations of, the provisions of this Agreement. In addition, in the event of an alleged breach or violation byEmployee of this Section 4, the applicable Non-Compete Period and Non-Solicitation Period set forth in this Section shall be tolled untilsuch breach or violation has been cured.4.5 Confidential Information. Employee acknowledges that pursuant to the employment hereunder, Employee occupies aposition of trust and confidence. Accordingly, in order to facilitate the performance of this Agreement and the activities contemplated bythis Agreement, Employee shall be provided with or given access to, or Employee may develop, certain proprietary or confidentialinformation (“Confidential Information”) of Employer or a Related Entity. Confidential Information includes, without limitation,information pertaining to Employer’s or the Related Entities’ past, current and future business plans, corporate opportunities,operations, acquisition, merger or sale strategies, production, product development, product names and marks, marketing, cost andpricing structure, margins, profitability, operation or production procedures or results, partners, partnership or other businessarrangements or agreements with third parties, customers, customer sales volumes, customer contracts, books, records and documents,technical information, equipment, services and processes. Subject to the last sentence of this Section, during the term of Employee’semployment and after the termination of Employee’s employment, Employee hereby agrees not to use or to disclose to any person,other than in the discharge of Employee’s duties under this Agreement, any Confidential Information of Employer or any RelatedEntities.11HOU:0024197/00043:1712692v2Exhibit 10.4Information shall not be deemed to be Confidential Information for purposes of this Agreement that: (i) is or hereafter becomes publiclyknown through no act or omission of Employee; (ii) is received by Employee without restriction on disclosure from a third party whodisclosed the information without violating any restriction on confidentiality or disclosure; or (iii) is independently developed after thetermination of Employee’s employment with Employer by Employee without reference to the Confidential Information and withoutviolation of any confidentiality restriction. If Employee violates this agreement of confidentiality, Employer shall, in addition to anyother remedy provided by law, be permitted to pursue an action for injunctive relief; monetary damages, or both. Employeeacknowledges that all such Confidential Information constitutes confidential and/or proprietary information of Employer and the RelatedEntities and agrees that such Confidential Information shall be kept confidential, such Confidential Information shall be used solely forthe purpose of performing the obligations hereunder or activities contemplated by this Agreement, and that Employee shall nototherwise disclose or make use of such Confidential Information except in response to a court order, provided that when responding to acourt order, Employee shall provide written notice of the court order to Employer in advance of any disclosure in response thereto.4.6 Intangible Rights. Employee agrees that all ideas, concepts, processes, discoveries, devices, machines, tools, materials,designs, improvements, inventions, computer software, and other things of value (“Intangible Rights”), if patented or subject to apatent application, and Confidential Information, which are conceived, made, invented or suggested either by Employee alone or incollaboration with others during the Term and relating to the business of Employer or a Related Entity, shall be promptly disclosed inwriting to Employer and shall be the sole and exclusive property of Employer. Employee hereby assigns to Employer all of Employee’sright, title, and interest in and to all such intangible rights that are patented or subject to a patent application by Employer and itssuccessors or assigns, and in and to Confidential Information. In the event that any of said Intangible Rights shall be deemed byEmployer to be patentable or otherwise registerable under any federal, state or foreign law, Employee further agrees that during theTerm plus 60 days, at the expense of Employer, Employee will execute all documents and do all things necessary, advisable, or properto obtain patents therefor or registration thereof; and to vest in Employer full title thereto. Employee agrees that all right, title, andinterest in any and all copyrights, copyright registrations, and copyrightable subject matter that occur as a result of Employee’semployment with Employer, shall be the sole and exclusive property of Employer, and agrees that such works comprise “works forhire.” Employee hereby assigns and agrees to assign to Employer all right, title, and interest in any such copyrights, copyrightregistrations, and copyrightable subject matter that occur because of such employment.4.7 Non-Disparagement. Employee shall refrain, both during the employment relationship and after the employmentrelationship terminates, from publishing any oral or written statements about Employer or any Related Entity, or any of their respectiveofficers, employees, shareholders, investors, directors, agents or representatives that are malicious, obscene, threatening, harassing,intimidating or discriminatory and which are designed to harm any of the foregoing. The foregoing restriction shall include, but not belimited to, statements made, whether directly or12HOU:0024197/00043:1712692v2Exhibit 10.4indirectly, to or on social media, internet websites, blogs and electronic bulletin boards, as well as statements to the media, includingwriters, researchers, reporters, magazines, newspapers, book publishers, television stations, radio stations, the motion picture industry,public interest groups, and the publishing industry generally. In the event such a communication is made to anyone, it will be considereda material breach of the terms of this Agreement, and all commitments to make any payments under Section 3.3(b) will be null andvoid. Additionally, in the event any such communication materially damages the reputation of Employer, any Related Entity, or theirrespective agents, officers, directors, or employees, the Employee will be required to reimburse the Employer for any and allSeverance Benefits made under the terms of this Agreement. This provision is not intended to limit Employee’s right to give non-malicious and truthful testimony should Employee be subpoenaed to give such testimony, and the foregoing restrictions in this Section4.7 shall not apply with respect to Employee’s communication with federal, state or local governmental agencies as may be legallyrequired or otherwise protected by law.4.8 Agreement to Covenants. Each of the covenants of this Section 4 are given by Employee as part of the consideration forthis Agreement and as an inducement to Employer to enter into this Agreement and accept the obligations hereunder. Employee has hadadequate time to consider these covenants and to consult with an attorney or other advisor concerning them. Employee acknowledgesthat Employee understands these covenants and agrees to them freely and voluntarily.SECTION 5: MISCELLANEOUS.5.1 Employee and Employer expressly understand and agree that Employer may at its sole discretion assign this Agreementand transfer Employee’s employment to another Related Entity (“Subsequent Employer”) as of, or at any time after, the EffectiveDate, and no such assignment and transfer shall be deemed to be a termination of employment for purposes of Section 3, or grounds fortermination for Employee Cause; provided, however, that, effective with such assignment and transfer, all of Employer’s obligationshereunder shall be unchanged, assumed by, and be binding upon, and all of Employer’s rights hereunder shall be assigned to, suchSubsequent Employer and the defined term “Employer” as used herein shall thereafter refer to such Subsequent Employer. Employeeexpressly consents to such assignment and transfer. Except for Employee’s title, as applicable, and as otherwise provided in this Section5.1, all of the terms and conditions of this Agreement, including without limitation, Employee’s rights and obligations, shall remain infull force and effect following any such assignment and transfer of employment.5.2 Except as otherwise required by law, any written notice hereunder shall be deemed validly given, made or served (i) onthe date on which it is delivered personally, (ii) five business days after it shall have been sent by registered or certified mail (receiptrequested and postage prepaid), (iii) one business day after it is sent by overnight courier (charges prepaid), or (iv) on the same businessday when sent before 5:00 p.m., recipient’s time, and on the next business day when sent after 5:00 p.m., recipient’s time, by facsimile.If to Employer, addressed to: Crestwood Operations LLC13HOU:0024197/00043:1712692v2Exhibit 10.4700 Louisiana, Suite 2060Houston, TX 77002Facsimile: (832) 519-2200Attention: Chief Executive OfficerCopy to: Crestwood Operations LLC700 Louisiana, Suite 2060Houston, TX 77002Facsimile: (832) 519-2200Attention: Senior Vice President and GeneralCounselIf to Employee: Heath Deneke4127 Amherst StHouston, TX 77005or to Employee’s last known personal address.5.3 This Agreement shall be construed and enforced, and this Agreement and any disputes or controversies related heretoshall be governed by, in all respects in accordance with, the law of the State of Texas, without regard to principles of conflicts of lawthat would apply the laws of any other jurisdiction, unless preempted by federal law, in which case federal law shall govern.5.4 No failure by either party hereto at any time to give notice of any breach by the other party of, or to require compliancewith, any condition or provision of this Agreement shall be deemed a waiver of similar or dissimilar provisions or conditions at the sameor at any prior or subsequent time.5.5 It is a desire and intent of the parties that the terms, provisions, covenants, and remedies contained in this Agreement shallbe enforceable to the fullest extent permitted by law. If any such term, provision, covenant, or remedy of this Agreement or theapplication thereof to any person, association, or entity or circumstances shall, to any extent, be construed to be invalid or unenforceablein whole or in part, then such term, provision, covenant, or remedy shall be construed or re-written in a manner so as to permit itsenforceability under the applicable law to the fullest extent permitted by law. In any case, the remaining provisions of this Agreement orthe application thereof to any person, association, or entity or circumstances other than those to which they have been held invalid orunenforceable, shall remain in full force and effect.5.6 It is the mutual intention of the parties to have the option to resolve any dispute concerning this Agreement out of court.Accordingly, the parties agree that either party may elect to have any such dispute submitted for resolution through Employer’s DisputeResolution Plan or, if no such plan is in place, then pursuant to binding arbitration to be held in Harris County, Texas, in accordance withthe employment arbitration rules (except as modified below) of the American Arbitration Association and with the Expedited Proceduresthereof (collectively, the “Rules”);14HOU:0024197/00043:1712692v2Exhibit 10.4provided, however, that Employer, on its own behalf and on behalf of any of the Related Entities, shall be entitled to seek a restrainingorder or injunction in any court of competent jurisdiction to prevent any breach, threatened breach, or the continuation of any breach ofthe provisions of Sections 4 and 5 and Employee hereby consents that such restraining order or injunction may be granted without thenecessity of Employer posting any bond. Each of the parties hereto agrees that arbitration pursuant to this Section 5.6 shall be conductedby a single arbitrator selected in accordance with the Rules; provided that such arbitrator shall be experienced in deciding casesconcerning the matter which is the subject of the dispute. Each of the parties agrees that in any such arbitration that the award shall bemade in writing no more than 30 days following the end of the proceeding, that the arbitration shall not be conducted as a class action,that the arbitration award shall include factual findings or conclusions of law, and that no punitive damages shall be awarded. Any awardrendered by the arbitrator shall be final and binding and judgment may be entered on it in any court of competent jurisdiction. Each of theparties hereto agrees to treat as confidential the results of any arbitration (including, without limitation, any findings of fact and/or lawmade by the arbitrator) and not to disclose such results to any unauthorized person. In any dispute related to a termination of Employee’semployment pursuant to Section 3.2(a)(i), Employee shall only be permitted to dispute or contest whether or not a determination ofEmployer Cause was made in good faith by the Board. Employer shall bear all administrative fees and expenses of the arbitration andunless the arbitrator directs otherwise, each party shall bear its own counsel fees and expenses. Either party may appeal the arbitrationaward and judgment thereon and, in actions seeking to vacate an award, the standard of review to be applied to the arbitrator’s findings offact and conclusions of law will be the same as that applied by an appellate court reviewing a decision of a trial court sitting without a jury.5.7 This Agreement shall be binding upon and inure to the benefit of Employer, its successors in interest, or any other person,association, or entity that may hereafter acquire or succeed to all or substantially all of the business assets of Employer by any means,whether indirectly or directly, and whether by purchase, merger, consolidation, or otherwise. Employee’s rights and obligations underthis Agreement are personal and such rights, benefits, and obligations of Employee shall not be voluntarily or involuntarily assigned,alienated, or transferred, whether by operation of law or otherwise, without the prior written consent of Employer, other than in thecase of death or Permanent Disability of Employee.5.8 This Agreement and the other agreements and arrangements referred to in this Agreement supersede and replace anyprevious agreements and discussions pertaining to the subject matter covered herein. This Agreement and any Exhibit hereto(collectively, the “Employment Documents”) constitute the entire agreement of the parties with regard to the terms of Employee’semployment, termination of employment and severance benefits, and contain all of the covenants, promises, representations,warranties, and agreements between the parties with respect to such matters. Each party to this Agreement acknowledges that norepresentation, inducement, promise, or agreement, oral or written, has been made by either party with respect to the foregoing mattersthat is not embodied in the Employment Documents, and that no agreement, statement, or promise relating to the employment ofEmployee by Employer that is not contained in the Employment15HOU:0024197/00043:1712692v2Exhibit 10.4Documents shall be valid or binding. Any modification or waiver of this Agreement will be effective only if it is in writing and signed byeach party whose rights hereunder are affected thereby.5.9 The parties recognize and acknowledge, and hereby expressly waive, any right any of them may have to punitive damages.5.10 Employee represents that Employee is fully competent to manage Employee’s business affairs, has read this documentcarefully, understands all of its contents, fully understands the final and binding effect of this Agreement, has had the opportunity toconsult with Employee’s attorney, and executes this Agreement freely and voluntarily. Employee represents and acknowledges that inexecuting this Agreement Employee does not rely and has not relied upon any representation or statement not set forth herein made byEmployer or the Board or by any of their respective agents, representatives, or attorneys with regard to the subject matter, basis, oreffect of this Agreement or otherwise.5.11 The parties to this Agreement hereby agree that no special relationship of trust and reliance is, has been, or will be createdby the provisions of this Agreement or Employee’s employment arrangement.5.12 This Agreement may be executed in one or more counterparts, each of which shall be deemed to be an original, but all ofwhich together will constitute one and the same Agreement.5.13 Employer may withhold from any compensation or benefits payable under this Agreement all federal, state, city or othertaxes as may be required pursuant to any law or governmental regulation or ruling, as well as any other authorized deduction orwithholding. Furthermore, should Employee owe Employer or a Related Entity any money at the time of termination of employment,Employee authorizes and consents to Employer deducting the amount owed by Employee from compensation otherwise owedEmployee.5.14 The provisions of this Section 5.14 shall apply solely to the extent that a payment under this Agreement is subject toSection 409A of the Internal Revenue Code of 1986, as amended (the “Code”).(a) General Suspension of Payments. If Employee is a “specified employee,” as such term is defined within themeaning of Section 409A of the Code, any payments or benefits payable or provided as a result of Employee’s termination ofemployment that would otherwise be paid or provided prior to the first day of the seventh month following such termination (other thandue to death) shall instead be paid or provided on the earlier of (i) the six months and one day following Employee’s termination, (ii) thedate of Employee’s death, or (iii) any date that otherwise complies with Section 409A of the Code. In the event that Employee is entitledto receive payments during the suspension period provided under this Section, Employee shall receive the accumulated benefits thatwould have been paid or provided under this Agreement within the suspension period on the first payroll date next following the earliestday that would be permitted under Section 409A of the Code. In the event of any delay in payment under this provision, the deferredamount shall16HOU:0024197/00043:1712692v2Exhibit 10.4bear interest at the prime rate (as stated in the Wall Street Journal) in effect on his termination date until paid.(b) Release Payments. In the event that Employee is required to execute a release to receive any payments from theEmployer that constitute nonqualified deferred compensation under Section 409A of the Code, payment of such amounts shall not bemade or commence until the sixtieth (60th) day following such termination of employment. Any payments that are suspended duringthe sixty (60) day period shall be paid on the date the first regular payroll is made immediately following the end of such period.(c) Reimbursement Payments. The following rules shall apply to payments of any amounts under this Agreementthat are treated as “reimbursement payments” under Section 409A of the Code: (i) the amount of expenses eligible for reimbursementin one calendar year shall not limit the available reimbursements for any other calendar year (other than an arrangement providing forthe reimbursement of medical expenses referred to in Section 105(b) of the Code); (ii) Employee shall file a claim for allreimbursement payments not later than thirty (30) days following the end of the calendar year during which the expenses wereincurred, (iii) the Employer shall make such reimbursement payments within thirty (30) days following the date Employee deliverswritten notice of the expenses to the Employer; and (iv) Employee’s right to such reimbursement payments shall not be subject toliquidation or exchange for any other payment or benefit.(d) Separation from Service. For purposes of this Agreement, any reference to “termination” of Employee’semployment shall be interpreted consistent with the meaning of the term “separation from service” in Section 409A(a)(2)(A)(i) of theCode and no portion of the Severance Payments shall be paid to Employee prior to the date such Employee incurs a separation fromservice under Section 409A(a)(2)(A)(i) of the Code.(e) Installment Payments. For purposes of Section 409A of the Code and the regulations and other guidancethereunder and any state law of similar effect (including without limitation Treasury Regulations Section 1.409A-2(b)(2)(iii)), allpayments made under this Agreement (whether severance payments or otherwise) will be treated as a right to receive a series ofseparate payments and, accordingly, each installment payment under this Agreement will at all times be considered a separate anddistinct payment.(f) PPACA. To the extent that any post-termination continuation of health or medical coverage pursuant to thisAgreement would violate either Section 105(h) of the Code or the Patient Protection and Affordable Care Act of 2010 (“PPACA”) andrelated regulations and guidance promulgated thereunder, the Employer may reform this Agreement in such manner as is reasonablynecessary to provide the Employee with the intended benefit hereunder in a manner that complies with the PPACA; provided, however,that such reformation shall not result in a violation of Code Section 409A.17HOU:0024197/00043:1712692v2Exhibit 10.4(g) General. Notwithstanding anything to the contrary in this Agreement, it is intended that the severance benefits andother payments payable under this Agreement satisfy, to the greatest extent possible, the exemptions from the application of Section409A of the Code provided under Treasury Regulations Sections 1.409A-1(b)(4), 1.409A-1(b)(5), and 1.409A-(b)(9) and thisAgreement will be construed to the greatest extent possible as consistent with those provisions. The commencement of payment orprovision of any payment or benefit under this Agreement shall be deferred to the minimum extent necessary to prevent the impositionof any excise taxes or penalties on the Employer or Employee.5.15 The paragraph headings have been inserted for purposes of convenience and shall not be used for interpretive purposes.[Signature Page Follows]18HOU:0024197/00043:1712692v2Exhibit 10.4IN WITNESS WHEREOF, Employer and Employee have duly executed this Agreement in multiple originals to beeffective on the Effective Date.EMPLOYERCRESTWOOD OPERATIONS LLCBy: Name: Title: EMPLOYEE Name: Heath Deneke HOU:0024197/00043:1712692V2Exhibit 10.5EMPLOYMENT AGREEMENTThis Employment Agreement (“Agreement”), is made and entered into as of the 21st day of January, 2014, (the “EffectiveDate”) between Crestwood Operations LLC, a Delaware limited liability company (“Employer”), and Joel Lambert (“Employee”).W I T N E S S E T H:WHEREAS, Employer desires to employ Employee, and Employee desires to be employed by Employer, pursuant to theterms and conditions set forth in this Agreement;NOW, THEREFORE, for and in consideration of the mutual promises, covenants, and obligations contained herein,Employer and Employee agree as follows:SECTION 1: EMPLOYMENT AND DUTIES.1.1 Employer agrees to employ Employee, and Employee agrees to be employed solely by Employer, beginning as of theEffective Date and, except as set forth below, continuing through December 31, 2015 (the “Initial Term”), unless earlier terminatedpursuant to Section 3 of this Agreement. Following expiration of the Initial Term, this Agreement will be automatically renewed forsuccessive 1-year terms following the Initial Term (each, a “Renewal Term” and, together with the Initial Term, the “Term”) unlesseither party gives the other party no less than 30 days’ written notice prior to the expiration of the Term of such Party’s intent not torenew the Agreement (a “Notice of Non-Renewal”). Notwithstanding the foregoing, the Term (including any Renewal Terms) andEmployee’s employment pursuant to this Agreement may be terminated at any time as set forth below, subject to the terms of thisAgreement. At the expiration of the Term following delivery of a Notice of Non-Renewal, Employee’s employment with Employer(and any affiliates or assignees of Employer) shall terminate, and this Agreement shall have no further force or effect except withrespect to Employee’s obligations pursuant to Section 3.5.1.2 Beginning as of the Effective Date, Employee shall be employed as Senior Vice President, General Counsel & CorporateSecretary. Employee shall also serve in such other executive capacities as may be reasonably requested from time to time by Employeror the Board of Directors (the “Board”) of the Employer, and shall report directly to the Chief Executive Office of the Employer.Employee agrees to perform diligently and to the best of Employee’s abilities, and in a trustworthy, competent, businesslike, andefficient manner, the duties and services pertaining to any such position as reasonably determined by Employer, as well as suchadditional or different duties and services that Employee from time to time may be reasonably directed to perform by Employer.Employee shall, during the period of Employee’s employment by Employer, devote Employee’s full business time, energy, and bestefforts to the business and affairs of Employer.1.3 Employee shall at all times comply with and be subject to such policies and procedures that Employer may establish fromtime to time for Employer’s executives and employees, including,1HOU:0024197/00043:1712670v2Exhibit 10.5without limitation, Employer’s Code of Business Conduct as adopted by Employer and as amended from time to time (the “Code ofBusiness Conduct”).1.4 Except with the advance written permission of the Board and with respect to Employee’s existing directorships identifiedon Exhibit A hereto, Employee may not engage or participate, directly or indirectly, in any other business, investment, or activity that(a) could interfere with Employee’s performance of Employee’s duties hereunder, (b) is contrary to the best interests of Employer,Crestwood Equity Partners, LP, Crestwood Midstream Partners, LP, or any of their respective subsidiaries (each a “Related Entity”), or(c) requires any significant portion of Employee’s business time. Notwithstanding the foregoing, the parties recognize that Employeemay engage in passive personal investments and other non-competitive business activities that do not conflict with the business andaffairs of Employer or any Related Entities or materially interfere with Employee’s performance of Employee’s duties hereunder;provided, that with the exception of any civic, charitable, or educational boards or committees that do not unreasonably interfere withEmployee’s performance of Employee’s duties hereunder, Employee may not serve as a manager or on the board of directors or similarbody of any entity other than Employer or a Related Entity during the Term without prior approval therefor by the Board.1.5 Employee acknowledges and agrees that Employee has a fiduciary duty of loyalty, fidelity, and allegiance to act at all timesin the best interests of Employer and the other Related Entities and to do no act that could, directly or indirectly, injure any such entity’sbusiness, interests, or reputation. In furtherance of the foregoing, Employee shall present to the Employer all material businessopportunities or ventures known to Employee, independently or with others, that are within the purposes of Employer or any RelatedEntity, including, without limitation, opportunities that may compete with Employer or a Related Entity or could reasonably beexpected to be implemented by Employer or a Related Entity. It is agreed that any direct or indirect interest in connection with, or anybenefit from, any outside activities, particularly commercial activities, which might in any way adversely affect Employer or any of theRelated Entities involves a possible conflict of interest. In keeping with Employee’s fiduciary duties to Employer, Employee agrees thatduring the employment relationship Employee shall not knowingly become involved in a conflict of interest with Employer or any ofthe Related Entities, whether directly or indirectly through a spouse or other family member, or upon discovery thereof, allow such aconflict to continue. Moreover, Employee agrees that Employee shall disclose to the Employer any facts which might involve such aconflict of interest that has not been approved in writing by the Employer.SECTION 2: COMPENSATION AND BENEFITS.2.1 Employee’s base salary during the Term shall be Three Hundred Sixty Thousand Dollars ($360,000) per annum, subjectto increase at the discretion of the Board (“Base Salary”), which shall be paid in accordance with Employer’s standard payroll practice.In addition to the Base Salary, Employee shall be eligible to be considered for a target bonus (a “Bonus”) in each calendar year duringthe Term, payable in accordance with and pursuant to Employer’s then-current2HOU:0024197/00043:1712670v2Exhibit 10.5bonus plan (“Bonus Plan”). For the 2014 bonus year, the target bonus for Employee will be equal to 75% of his Base Salary and shall besubject to such terms and conditions as are established by the Board (including, if applicable, its Compensation Committee) for awards ofequity compensation made to similarly situated executives of the Employer. Thereafter, the target bonus for Employee will becomparable to the bonus opportunity provided to similarly situated executives of the Employer. The Bonus Plan will be implementedand administered by the Board, and any Bonuses payable thereunder shall be based upon a number of factors determined and set by theBoard in its sole discretion. Such factors may include, but not be limited to, the achievement by Employer of certain performanceobjectives, and the operation of Employer within the budgets approved by the Board. Employee must be employed by Employer at thetime a Bonus is declared as a condition of receiving any such Bonus.2.2 During the Term, Employee shall be eligible to receive annual awards under the terms of the Crestwood Equity PartnersLP Long Term Incentive Plan and the Crestwood Midstream Partners LP Long Term Incentive Plan. For the 2014 grant cycle, theEmployee shall receive an award of restricted units, with a total target equity grant level for Employee equal to 150% of his Base Salary.These restricted units will be granted equally from both plans and shall be subject to such terms and conditions as are established by theBoard (including, if applicable, its Compensation Committee) for awards of equity compensation made to similarly situated executives ofthe Employer. Thereafter, the target grant level for Employee will be comparable to the level of equity granted to similarly situatedexecutives of the Employer, provided such grants shall be made at the discretion of the Board. Equity awards granted to Employeeunder the foregoing plans shall include provisions that provide for accelerated vesting in the event of a Change in Control, upontermination of Employee’s employment by the Employer without Cause, or upon Employee’s resignation with Employee Cause (forpurposes of this Section 2.2 only, each of “Change in Control,” “Cause” and “Employee Cause” to be as such terms are defined in therespective award agreements). Notwithstanding the foregoing, the level of equity compensation to be awarded to the Employee for the2014 and 2015 grant cycles shall be reduced to reflect his prior award of incentive units in Crestwood Holdings Partners LLC. For the2014 grant cycle, the Employee shall receive 1/3 of what would otherwise be the recommended equity awards proposed by theCompensation Committees of Crestwood Equity Partners LP and Crestwood Midstream Partners LP. For the 2015 grant cycle, theEmployee shall receive 2/3 of such recommended equity awards.2.3 During the Term, Employer shall pay or reimburse Employee for all reasonable and customary business expensesactually incurred by Employee during the Term in the course of Employee’s employment; provided that such expenses are incurredand accounted for in accordance with Employer’s applicable policies and procedures. Employer shall provide to Employeeofficer/director liability insurance coverage to cover any claims that may be made arising from Employee’s past, present, or futureactivities on behalf of Employer or any Related Entity, in the same manner and of the same kind as such insurance is provided to theother officers and directors of Employer.2.4 During the Term, Employer shall furnish Employee with such fringe benefit programs that are maintained by Employerand that are made available to Employer’s management3HOU:0024197/00043:1712670v2Exhibit 10.5generally, under the same terms as those provided to Employer’s management generally. Employee shall bear any tax effects orobligations stemming from any such policies and programs or their amounts.2.5 Employee acknowledges that Employee shall have no vested rights under or in respect of Employee’s participation in anyemployee benefit program, plan, or coverage except as expressly provided under the terms thereof. Notwithstanding anything in thisAgreement, it is specifically understood and agreed that Employer shall not be obligated to institute, maintain, or refrain from changing,amending, or discontinuing any employee benefit program, plan, or coverage applicable to Employee, so long as any such actions orinactions in this regard by Employer are similarly applicable to covered executive employees of Employer generally.2.6 Employee shall be entitled to four (4) weeks of paid vacation per calendar year, to be provided in accordance withEmployer’s standard policy and to be taken at such time as mutually agreed by Employee and Employer.SECTION 3: TERMINATION OF EMPLOYMENT AND EFFECTS OF SUCH TERMINATION.3.1 Termination Generally. Employee’s employment with Employer (a) shall be terminated prior to the end of the Term (i)upon the death of Employee, or (ii) upon Employee’s Permanent Disability (as defined below), and (b) may be terminated prior to theend of the Term (i) at any time by Employer upon notice to Employee, (ii) at any time by Employee upon thirty (30) days’ prior writtennotice to Employer, or (iii) at any time by Employee if Employee has Employee Cause and complies with the notice proceduresdescribed below. The date of termination is referred to herein as the “Termination Date.”3.2 Bad Leaver Termination. If Employee’s employment is terminated under any of the circumstances set forth in Section3.2(a), Employee shall be entitled to receive only the benefits set forth in Section 3.2(b) below:(a) Bad Leaver Conditions.(i) Termination by Employer for Employer Cause. Employer termination of Employee’s employment for“Employer Cause” shall mean termination by Employer for any of the following: if Employee (a) has been indicted or convicted of, orhas entered a plea of guilty or nolo contendere to, a felony charge or crime involving moral turpitude, or, in the course of Employee’semployment has engaged in fraudulent or criminal activity (whether or not prosecuted), (b) has failed to follow reasonable directions ofEmployer, provided that the foregoing failure shall not be “Employer Cause” if Employee in good faith believes that such direction isillegal and promptly so notifies the Board, (c) has failed to devote all of Employee’s professional time to the Employer and affiliates ofEmployer, except as permitted by the Employer, (d) has materially breached any policy or code of conduct of the Employer, (e) hasmaterially breached any4HOU:0024197/00043:1712670v2Exhibit 10.5provision of this Agreement or any other agreement between Employee and the Employer or Related Entity, (f) has received a kickbackor rebate of any fee or expense paid by Employer, (g) has engaged in the use of illegal drugs, the persistent excessive use of alcohol, orany other activity that materially impairs Employee’s ability to perform Employee’s duties hereunder or results in conduct bringingEmployer or any Related Entity into substantial public disgrace or disrepute, or (h) engages in intentional, reckless, or grossly negligentconduct that has or is reasonably likely to have a material adverse effect on Employer or any Related Entity; provided, however, thatwith respect to subsections (c), (d) and (e) of this Section 3.2(a)(i), the Board may elect, in its sole discretion, to allow Employee aperiod of time as determined by the Board to cure the act, conduct or event constituting Employer Cause under such subsections.(ii) Employee Resignation. Employee resigns for any reason other than having Employee Cause (as definedbelow in Section 3.3(a)(i)).(b) Bad Leaver Consequences.(i) Employee shall be entitled to receive, within 30 days of the Termination Date or such shorter period asmay be required by applicable state law, any Base Salary that was accrued (on a pro rata basis) but unpaid as of the Termination Date(“Accrued Salary”) and such other benefits provided to Employee pursuant to the terms of Employer’s employee benefit plans(which, for the avoidance of doubt, does not include any Bonus payments) that were accrued by Employer in its books and records, butnot forfeited, cancelled, or previously paid, as of the Termination Date (“Accrued Benefits,” or, collectively with Accrued Salary,“Accrued Compensation”); and(ii) Except for Accrued Compensation, Employee shall forfeit, from and after the Termination Date,Employee’s rights to any and all future compensation from Employer or any Related Entity to which Employee may be entitled and toall future benefits for which Employee may be eligible, in either case under this Agreement or otherwise, including without limitationany Bonus payments (including any earned but unpaid Bonus payments or portions thereof) that would have been payable had Employeeremained employed through the date such Bonus payments would have been paid. Except for Accrued Compensation, Employer’sobligations to pay or provide Employee with future compensation or benefits shall fully and forever cease and terminate as of theTermination Date.3.3 Good Leaver Termination. Subject to Section 3.8, if Employee’s employment is terminated under any of thecircumstances set forth in Section 3.3(a), and Employee complies with the requirements of Section 3.7, Employee shall be entitled toreceive Accrued Compensation as well as the benefits set forth in Section 3.3(b) below (“Severance Benefits”):(a) Good Leaver Conditions.5HOU:0024197/00043:1712670v2Exhibit 10.5(iii) Employee Resignation with Employee Cause. “Employee Cause” will exist if one of the followingoccurs: (A) a substantial and continuing diminution in the nature of Employee’s responsibilities (provided, however, that neither achange in Employee’s reporting relationship, nor a diminution in responsibilities as a result of Employer exercising its rights underSection 3.7 will trigger this provision); (B) a material breach by Employer of any material provision of this Agreement; (C) a materialand continuing reduction in the aggregated total of Employee’s Base Salary, target Bonus percentage and target equity percentage; or (D)reassignment by the Company of the Employee’s principal place of employment to a location more than fifty (50) miles from hisprincipal place of employment on the Effective Date, but excluding normal business travel consistent with Employee’s duties,responsibilities and position. For Employee to terminate for Employee Cause: (i) Employer must be notified by Employee in writingwithin 30 days of the date Employee becomes aware of the event that would allow Employee to terminate employment for EmployeeCause, with such notice setting forth such event in reasonable detail; (ii) the event must remain uncorrected by Employer for 30 daysfollowing Employer’s receipt of such notice (the “Notice Period”); and (iii) such termination must occur within 30 days after theexpiration of the Notice Period.(iv) Employer Termination without Cause. Employer Termination without Cause shall mean termination byEmployer for any reason other than for Employer Cause.(v) Death. Death shall mean Employee’s death.(vi) Permanent Disability. Termination due to Employee’s “Permanent Disability” shall mean the inabilityof Employee, with or without reasonable accommodation, by reason of illness, incapacity, or other disability, to perform Employee’sduties or fulfill Employee’s employment obligations to Employer, as determined by the Board and as certified in writing by a competentmedical physician chosen by the Board, for a cumulative total of 180 days in any 12 month period; provided, however, that such periodof absence may be extended if required by applicable law.(b) Good Leaver Consequences.(i) A severance payment equal to two (2) times the sum of (A) the Base Salary calculated as of theTermination Date or, if greater, before any reduction not consented to by the Employee and (B) the average of the annual Bonus paid toEmployee for the prior two (2) year period. In the event Employee has not worked one full bonus year as of the Termination Date, theamount for purposes of Section 3.3(b)(i)(B) shall be Employee’s target Bonus amount for 2014 pursuant to Section 2.1; and in the eventEmployee has only worked one full bonus year as of the Termination Date, the amount for purposes of Section 3.3(b)(i)(B) shall beshall be the average of the annual Bonus paid to Employee for the prior year and Employee’s target Bonus amount for 2014 pursuant toSection 2.1. The severance payment shall be paid in equal installments in accordance with the Employer’s normal payroll proceduresover the period commencing on the Termination Date and ending on the date that is eighteen (18) months following the TerminationDate; provided,6HOU:0024197/00043:1712670v2Exhibit 10.5however that in the event that (1) Employee serves a Severance Waiver Notice in accordance with Section 4.1, or (2) Employeeviolates any of the covenants set forth in this Agreement or in any separation agreement, general release, or similar agreement withEmployer, Employee shall thereafter forfeit the right to receive any further severance payment installments payable hereunder.During the period that Employee is entitled to receive severance payments pursuant to this Section 3.3(b), the Employer shall alsoprovide medical benefits to Employee under terms and conditions that are not less favorable than provided to executive officers of theEmployer; provided, however, that (X) Employee must elect to receive continuation of health insurance coverage pursuant to theConsolidated Omnibus Budget Reconciliation Act (COBRA); (Y) Employee will be required to pay the amount that an active employeeof the Employer would pay to receive such coverage and the Employer will be responsible for the employer portion of the insurancepremium payments (which amount will be treated as imputed income to the Employee); and (Z) the Employer’s obligation to pay aportion of the Employee’s COBRA premiums shall cease on the first day of the month after Employee obtains reasonably comparablehealth care coverage from a subsequent employer or other source.(ii) Except as set forth in this Section 3.3(b) and as provided in Section 2.2, from and after the TerminationDate, (A) Employee forfeits Employee’s rights to any and all compensation from Employer or any Related Entity to which Employeemay be entitled and to all future benefits for which Employee may be eligible, in either case under this Agreement or otherwise,including without limitation any Bonus payments (excluding Employee’s Bonus payment for the calendar year of termination, pro-ratedfor the portion of the calendar year of termination during which Employee was employed by Employer, such pro-rated Bonus to bepayable on the date that such bonuses are otherwise paid by the Employer to its employees), and (B) Employer’s obligations to pay orprovide Employee with any such future compensation or future benefits shall fully and forever cease and terminate.(iii) If Employee’s employment is terminated by reason of Employee’s death, Employee’s estate will beentitled to payment of all amounts due under Section 3.3(b). If Employee’s employment is terminated because of Employee’sPermanent Disability, Employee’s legal guardian will be entitled to payment of the amounts due under Section 3.3(b) in accordancewith the terms and conditions set forth therein.3.4 Expiration. If the Agreement expires and Employee’s employment terminates as a result of the delivery of a Notice ofNon-Renewal by Employer to Employee, Employee shall be entitled to receive the Severance Benefits provided pursuant to the termsand conditions of Section 3.3(b); provided, however, that if Employer terminates the Agreement and Employee’s employment forEmployer Cause following Employee’s delivery of a Notice of Non-Renewal but prior to the expiration of the Term, or Employeerefuses to remain employed through the expiration of the Term, Employee shall forfeit and not be entitled to the Severance Benefits. Ifthe Agreement expires and Employee’s employment terminates as a result of the delivery of a Notice of Non-Renewal by7HOU:0024197/00043:1712670v2Exhibit 10.5Employee to Employer, Employee shall only be entitled to receive the Accrued Compensation pursuant to the terms and conditions ofSection 3.2(b).3.5 Continuing Obligations. Termination or expiration of this Agreement and the employment relationship does not terminatethose obligations of Employee imposed by this Agreement that are continuing obligations, including, without limitation, Employee’sobligations under Section 4.3.6 Post-Termination Assistance. During any period during which any Severance Benefits or other monies are being paid toEmployee under this Agreement after the Termination Date, Employee shall provide to Employer reasonable levels of assistance toEmployer in answering questions or otherwise cooperating concerning the business of Employer, transition of responsibility, orlitigation; provided that Employee shall be fully and promptly reimbursed for all out of pocket expenses of Employee reasonablyincurred in connection with such assistance and any such assistance after the period during which any Severance Benefits or othermonies are being paid shall not interfere or conflict with the obligations that Employee may owe to any other employer.3.7 Reduction or Alteration in Duties. When either the Employer or Employee serves a notice of termination or a Notice ofNon-Renewal, the Employer will have the right in its absolute discretion to (i) assign reduced, alternative, or no duties to the Employee,and require the Employee to act as directed by the Employer, including excluding the Employee from the premises of the Employer orother Related Entity, and (ii) prohibit the Employee from discussing the Employee’s termination with employees, agents, or any thirdparty except with respect to Employee’s communication with federal, state or local governmental agencies as may be legally required orotherwise protected by law; provided, however, that in the event of a reduction or alteration of duties in accordance with Section 3.7(i),Employer will still be required to make the Base Salary payments pursuant to Section 2.1 through the date of termination ofEmployee’s employment.3.8 Release. As a condition to the payment of any severance benefit hereunder, including the Severance Benefits, Employer,in its sole discretion, may require Employee (or Employee’s executor, legal guardian, or other legal representative in the case of theEmployee’s death or Permanent Disability) to first execute and not revoke a waiver and release of all claims against Employer and theRelated Entities in a form reasonably acceptable to Employer within 21 days following the Termination Date.3.9 Forfeiture of Benefits. Except as otherwise provided in Section 4.1 hereof, in the event Employee breaches any ofEmployee’s obligations under Section 4 of this Agreement, and if Employee is otherwise entitled to receive Severance Benefits underSection 3.3, Employee shall fully, completely, and permanently forfeit any and all rights to such Severance Benefits, and Employerand each Related Entity shall have the right to fully, completely, and permanently terminate payment of any amounts to whichEmployee would otherwise be entitled pursuant to these provisions and recover the amount equal to the Severance Benefits previouslypaid to Employee under Section 3.3. The foregoing forfeiture of rights to the Severance Benefits shall not in any way limit or restrict8HOU:0024197/00043:1712670v2Exhibit 10.5Employer’s rights and remedies pursuant to Section 4, including the right to seek injunctive relief to enforce compliance with suchobligations and to recover damages for any breach. Employee agrees that all disputes relating to Employee’s employment or terminationof employment shall be resolved through Employer’s Dispute Resolution Plan as provided in Section 5.6 hereof.3.10 Severance Benefits Not an Offer of Employment. The payment of any Severance Benefits or other monies toEmployee under this Agreement after the Termination Date shall not constitute an offer or a continuation of employment of Employee.In no event shall Employee represent or hold himself out to be an employee of Employer after the Termination Date. Except whereEmployer is required by law to withhold any federal, state, or local taxes, Employee shall be responsible for any and all federal, state, orlocal taxes that arise out of any payments to Employee hereunder.3.11 Recharacterization of Termination. Notwithstanding any other provision of this Agreement, if following the terminationof employment Employer discovers that grounds existed as of the Termination Date for a termination for Employer Cause, then suchtermination shall be deemed to be a termination for Employer Cause and Employee shall only be entitled to the payments and benefitsprovided in Section 3.2. In the event Employee’s termination is reclassified as a termination for Employer Cause pursuant to thisSection 3.11, Employee’s termination shall be so treated and classified for all purposes under this Agreement and any other agreementsbetween Employee and Employer, and Employee shall repay to Employer any monies or benefits received by Employee followingtermination to which Employee would not have been entitled upon being terminated for Employer Cause.SECTION 4: COVENANT NOT TO COMPETE; CONFIDENTIALITY.4.1 Non-Compete. The parties hereto recognize that Employee is retained by Employer as part of a professional, management,and executive staff of Employer whose duties include the formulation and execution of management policy. Therefore, in exchange forthe consideration specified herein and as a material incentive for Employer to enter into this Agreement, and to enforce Employee’sobligations regarding confidentiality pursuant to Section 4.5 hereof, Employee hereby agrees that during the term of Employee’semployment hereunder (including any period of employment in which Employee has reduced or altered duties pursuant to Section 3.7)and, in the event of a termination of Employee’s employment pursuant to Section 3.3 (Good Leaver Termination), for a period ofeighteen (18) months following the Termination Date (the “Non-Compete Period”), Employee shall not, within North America, actor engage in material competition with the activities or plans of Employer or any Related Entity as they exist up to the time ofEmployee’s termination of employment. “Material Competition” by Employee shall mean (A) engaging in or conducting anybusiness or investment activity in any capacity that directly competes with or has a material adverse economic effect on any of thematerial business activities or business plans of Employer or any Related Entity, or with respect to a business or asset that was beingevaluated by Employer or any Related Entity at any time during the Term and prior to the termination9HOU:0024197/00043:1712670v2Exhibit 10.5of employment, or (B) rendering advice or services to, whether as an employee, consultant, advisor, agent, shareholder, independentcontractor, investor, partner, member, owner, or otherwise, any company, business or other entity that derives a material part of itsbusiness from activities that directly compete with the business activities or business plans of Employer or any Related Entity; provided,however, that Employee shall be permitted to acquire a passive stock interest in such a business provided that the stock acquired ispublicly traded and Employee does not beneficially own more than 2% of the outstanding interest in such business. Notwithstanding theforegoing, at any time during the eighteen-month period following the Termination Date, Employee may, at Employee’s option, serveon the Employer a written notice waiving the right to any and all future installments of the Severance Benefit payments pursuant toSection 3.3(b)(i) (a “Severance Waiver Notice”), and upon delivery of the Severance Waiver Notice, Employee shall no longer bebound by the restrictions set forth in this Section 4.1 for the period on and after the date on which the Severance Waiver Notice isdelivered to the Employer; provided, however, that notwithstanding the delivery of a Severance Waiver Notice, Employee willcontinue to be bound by the remaining obligations set forth in this Agreement, including but not limited to those covenants of Employeeset forth in Section 4.2 and Section 4.5 hereof.4.2 Non-Solicit. During the term of Employee’s employment hereunder (including any period of employment in whichEmployee has reduced or altered duties pursuant to Section 3.7) and for a period of eighteen (18) months following the TerminationDate (the “Non-Solicitation Period”), Employee will not, directly or indirectly, solicit or induce (i) any person who is employed byEmployer or any of the Related Entities or was so employed within the six-month period prior to the Termination Date (A) to interferewith the activities or businesses of Employer or any Related Entity or (B) to discontinue such person’s employment with Employer orany of the Related Entities, nor shall Employee (or any business or entity with which Employee is then involved) employ any suchperson or (ii) any customer of Employer to discontinue or reduce its business with Employer (either through the transition of suchbusiness to a competitor of Employer or otherwise); provided, however, that general solicitation of the public for employment shall notconstitute a solicitation hereunder so long as such general solicitation is not designed to target any such person.4.3 Recognition of Limitations as Reasonable. Employee understands that the provisions of Sections 4.1 and 4.2 hereof maylimit Employee’s ability to earn a livelihood in a business similar to the business in which Employee is involved, but as a member of themanagement group of Employer Employee nevertheless agrees and hereby acknowledges that (i) such provisions do not impose agreater restraint than is necessary to protect the goodwill, trade secrets, or other business interests of Employer and any of the RelatedEntities; (ii) such provisions contain reasonable limitations as to time, scope of activity, and geographical area to be restrained; and (iii) theconsideration provided hereunder, including without limitation, any amounts or benefits provided under Section 3 hereof and theConfidential Information provided pursuant to Section 4.5, is sufficient to compensate Employee for the restrictions contained inSections 4.1 and 4.2 hereof. In consideration of the foregoing and in light of Employee’s education, skills, and abilities, Employee agreesthat Employee will not assert that, and it should not be considered that, any provisions of10HOU:0024197/00043:1712670v2Exhibit 10.5Section 4.1 or 4.2 otherwise are void, voidable, or unenforceable or should be voided or held unenforceable.4.4 Modifications to Section 4. If, at the time of enforcement of Section 4 of this Agreement, a court shall hold that the period,scope, or geographical area restrictions stated herein are unreasonable under circumstances then existing, the parties hereto agree thatthe maximum period, scope, or geographical area reasonable under such circumstances shall be substituted for the stated period, scope,or geographical area and that the court shall revise the restrictions contained herein to cover the maximum period, scope, andgeographical area permitted by law. If, in any proceeding, a court refuses to enforce all of the separate covenants deemed included hereinbecause, taken together, they are deemed more extensive than necessary to assure Employer of the intended benefit of this Agreement,it is expressly understood and agreed that those of such covenants or portions of such covenants that, if eliminated, would permit theremaining separate covenants or portions thereof to be enforced in such proceeding shall, for the purpose of such proceeding, be deemedeliminated from the provisions hereof. Employee acknowledges that Employee is a member of Employer’s management group withaccess to Employer’s confidential business information and Employee’s services are unique to Employer and the Related Entities.Employee therefore agrees that the remedy at law for any breach by Employee of any of the covenants and agreements set forth in thisSection 4 will be inadequate and that in the event of any such breach, Employer may, in addition to the other remedies that may beavailable to it at law, apply to any court of competent jurisdiction to obtain specific performance and/or injunctive relief prohibitingEmployee (together with all those persons associated with Employee) from the breach of such covenants and agreements and toenforce, or prevent any violations of, the provisions of this Agreement. In addition, in the event of an alleged breach or violation byEmployee of this Section 4, the applicable Non-Compete Period and Non-Solicitation Period set forth in this Section shall be tolled untilsuch breach or violation has been cured.4.5 Confidential Information. Employee acknowledges that pursuant to the employment hereunder, Employee occupies aposition of trust and confidence. Accordingly, in order to facilitate the performance of this Agreement and the activities contemplated bythis Agreement, Employee shall be provided with or given access to, or Employee may develop, certain proprietary or confidentialinformation (“Confidential Information”) of Employer or a Related Entity. Confidential Information includes, without limitation,information pertaining to Employer’s or the Related Entities’ past, current and future business plans, corporate opportunities,operations, acquisition, merger or sale strategies, production, product development, product names and marks, marketing, cost andpricing structure, margins, profitability, operation or production procedures or results, partners, partnership or other businessarrangements or agreements with third parties, customers, customer sales volumes, customer contracts, books, records and documents,technical information, equipment, services and processes. Subject to the last sentence of this Section, during the term of Employee’semployment and after the termination of Employee’s employment, Employee hereby agrees not to use or to disclose to any person,other than in the discharge of Employee’s duties under this Agreement, any Confidential Information of Employer or any RelatedEntities.11HOU:0024197/00043:1712670v2Exhibit 10.5Information shall not be deemed to be Confidential Information for purposes of this Agreement that: (i) is or hereafter becomes publiclyknown through no act or omission of Employee; (ii) is received by Employee without restriction on disclosure from a third party whodisclosed the information without violating any restriction on confidentiality or disclosure; or (iii) is independently developed after thetermination of Employee’s employment with Employer by Employee without reference to the Confidential Information and withoutviolation of any confidentiality restriction. If Employee violates this agreement of confidentiality, Employer shall, in addition to anyother remedy provided by law, be permitted to pursue an action for injunctive relief; monetary damages, or both. Employeeacknowledges that all such Confidential Information constitutes confidential and/or proprietary information of Employer and the RelatedEntities and agrees that such Confidential Information shall be kept confidential, such Confidential Information shall be used solely forthe purpose of performing the obligations hereunder or activities contemplated by this Agreement, and that Employee shall nototherwise disclose or make use of such Confidential Information except in response to a court order, provided that when responding to acourt order, Employee shall provide written notice of the court order to Employer in advance of any disclosure in response thereto.4.6 Intangible Rights. Employee agrees that all ideas, concepts, processes, discoveries, devices, machines, tools, materials,designs, improvements, inventions, computer software, and other things of value (“Intangible Rights”), if patented or subject to apatent application, and Confidential Information, which are conceived, made, invented or suggested either by Employee alone or incollaboration with others during the Term and relating to the business of Employer or a Related Entity, shall be promptly disclosed inwriting to Employer and shall be the sole and exclusive property of Employer. Employee hereby assigns to Employer all of Employee’sright, title, and interest in and to all such intangible rights that are patented or subject to a patent application by Employer and itssuccessors or assigns, and in and to Confidential Information. In the event that any of said Intangible Rights shall be deemed byEmployer to be patentable or otherwise registerable under any federal, state or foreign law, Employee further agrees that during theTerm plus 60 days, at the expense of Employer, Employee will execute all documents and do all things necessary, advisable, or properto obtain patents therefor or registration thereof; and to vest in Employer full title thereto. Employee agrees that all right, title, andinterest in any and all copyrights, copyright registrations, and copyrightable subject matter that occur as a result of Employee’semployment with Employer, shall be the sole and exclusive property of Employer, and agrees that such works comprise “works forhire.” Employee hereby assigns and agrees to assign to Employer all right, title, and interest in any such copyrights, copyrightregistrations, and copyrightable subject matter that occur because of such employment.4.7 Non-Disparagement. Employee shall refrain, both during the employment relationship and after the employmentrelationship terminates, from publishing any oral or written statements about Employer or any Related Entity, or any of their respectiveofficers, employees, shareholders, investors, directors, agents or representatives that are malicious, obscene, threatening, harassing,intimidating or discriminatory and which are designed to harm any of the foregoing. The foregoing restriction shall include, but not belimited to, statements made, whether directly or12HOU:0024197/00043:1712670v2Exhibit 10.5indirectly, to or on social media, internet websites, blogs and electronic bulletin boards, as well as statements to the media, includingwriters, researchers, reporters, magazines, newspapers, book publishers, television stations, radio stations, the motion picture industry,public interest groups, and the publishing industry generally. In the event such a communication is made to anyone, it will be considereda material breach of the terms of this Agreement, and all commitments to make any payments under Section 3.3(b) will be null andvoid. Additionally, in the event any such communication materially damages the reputation of Employer, any Related Entity, or theirrespective agents, officers, directors, or employees, the Employee will be required to reimburse the Employer for any and allSeverance Benefits made under the terms of this Agreement. This provision is not intended to limit Employee’s right to give non-malicious and truthful testimony should Employee be subpoenaed to give such testimony, and the foregoing restrictions in this Section4.7 shall not apply with respect to Employee’s communication with federal, state or local governmental agencies as may be legallyrequired or otherwise protected by law.4.8 Agreement to Covenants. Each of the covenants of this Section 4 are given by Employee as part of the consideration forthis Agreement and as an inducement to Employer to enter into this Agreement and accept the obligations hereunder. Employee has hadadequate time to consider these covenants and to consult with an attorney or other advisor concerning them. Employee acknowledgesthat Employee understands these covenants and agrees to them freely and voluntarily.SECTION 5: MISCELLANEOUS.5.1 Employee and Employer expressly understand and agree that Employer may at its sole discretion assign this Agreementand transfer Employee’s employment to another Related Entity (“Subsequent Employer”) as of, or at any time after, the EffectiveDate, and no such assignment and transfer shall be deemed to be a termination of employment for purposes of Section 3, or grounds fortermination for Employee Cause; provided, however, that, effective with such assignment and transfer, all of Employer’s obligationshereunder shall be unchanged, assumed by, and be binding upon, and all of Employer’s rights hereunder shall be assigned to, suchSubsequent Employer and the defined term “Employer” as used herein shall thereafter refer to such Subsequent Employer. Employeeexpressly consents to such assignment and transfer. Except for Employee’s title, as applicable, and as otherwise provided in this Section5.1, all of the terms and conditions of this Agreement, including without limitation, Employee’s rights and obligations, shall remain infull force and effect following any such assignment and transfer of employment.5.2 Except as otherwise required by law, any written notice hereunder shall be deemed validly given, made or served (i) onthe date on which it is delivered personally, (ii) five business days after it shall have been sent by registered or certified mail (receiptrequested and postage prepaid), (iii) one business day after it is sent by overnight courier (charges prepaid), or (iv) on the same businessday when sent before 5:00 p.m., recipient’s time, and on the next business day when sent after 5:00 p.m., recipient’s time, by facsimile.If to Employer, addressed to: Crestwood Operations LLC13HOU:0024197/00043:1712670v2Exhibit 10.5700 Louisiana, Suite 2060Houston, TX 77002Facsimile: (832) 519-2200Attention: Chief Executive OfficerIf to Employee: Joel Lambert11214 Montebello Ct.Houston, TX 77024or to Employee’s last known personal address.5.3 This Agreement shall be construed and enforced, and this Agreement and any disputes or controversies related heretoshall be governed by, in all respects in accordance with, the law of the State of Texas, without regard to principles of conflicts of lawthat would apply the laws of any other jurisdiction, unless preempted by federal law, in which case federal law shall govern.5.4 No failure by either party hereto at any time to give notice of any breach by the other party of, or to require compliancewith, any condition or provision of this Agreement shall be deemed a waiver of similar or dissimilar provisions or conditions at the sameor at any prior or subsequent time.5.5 It is a desire and intent of the parties that the terms, provisions, covenants, and remedies contained in this Agreement shallbe enforceable to the fullest extent permitted by law. If any such term, provision, covenant, or remedy of this Agreement or theapplication thereof to any person, association, or entity or circumstances shall, to any extent, be construed to be invalid or unenforceablein whole or in part, then such term, provision, covenant, or remedy shall be construed or re-written in a manner so as to permit itsenforceability under the applicable law to the fullest extent permitted by law. In any case, the remaining provisions of this Agreement orthe application thereof to any person, association, or entity or circumstances other than those to which they have been held invalid orunenforceable, shall remain in full force and effect.5.6 It is the mutual intention of the parties to have the option to resolve any dispute concerning this Agreement out of court.Accordingly, the parties agree that either party may elect to have any such dispute submitted for resolution through Employer’s DisputeResolution Plan or, if no such plan is in place, then pursuant to binding arbitration to be held in Harris County, Texas, in accordance withthe employment arbitration rules (except as modified below) of the American Arbitration Association and with the Expedited Proceduresthereof (collectively, the “Rules”); provided, however, that Employer, on its own behalf and on behalf of any of the Related Entities,shall be entitled to seek a restraining order or injunction in any court of competent jurisdiction to prevent any breach, threatened breach,or the continuation of any breach of the provisions of Sections 4 and 5 and Employee hereby consents that such restraining order orinjunction may be granted without the necessity of Employer posting any bond. Each of the parties hereto agrees that arbitrationpursuant to this Section 5.6 shall be conducted by a single arbitrator selected in accordance with the Rules; provided that such arbitratorshall be experienced in deciding cases concerning the matter14HOU:0024197/00043:1712670v2Exhibit 10.5which is the subject of the dispute. Each of the parties agrees that in any such arbitration that the award shall be made in writing no morethan 30 days following the end of the proceeding, that the arbitration shall not be conducted as a class action, that the arbitration awardshall include factual findings or conclusions of law, and that no punitive damages shall be awarded. Any award rendered by the arbitratorshall be final and binding and judgment may be entered on it in any court of competent jurisdiction. Each of the parties hereto agrees totreat as confidential the results of any arbitration (including, without limitation, any findings of fact and/or law made by the arbitrator)and not to disclose such results to any unauthorized person. In any dispute related to a termination of Employee’s employment pursuantto Section 3.2(a)(i), Employee shall only be permitted to dispute or contest whether or not a determination of Employer Cause wasmade in good faith by the Board. Employer shall bear all administrative fees and expenses of the arbitration and unless the arbitratordirects otherwise, each party shall bear its own counsel fees and expenses. Either party may appeal the arbitration award and judgmentthereon and, in actions seeking to vacate an award, the standard of review to be applied to the arbitrator’s findings of fact and conclusionsof law will be the same as that applied by an appellate court reviewing a decision of a trial court sitting without a jury.5.7 This Agreement shall be binding upon and inure to the benefit of Employer, its successors in interest, or any other person,association, or entity that may hereafter acquire or succeed to all or substantially all of the business assets of Employer by any means,whether indirectly or directly, and whether by purchase, merger, consolidation, or otherwise. Employee’s rights and obligations underthis Agreement are personal and such rights, benefits, and obligations of Employee shall not be voluntarily or involuntarily assigned,alienated, or transferred, whether by operation of law or otherwise, without the prior written consent of Employer, other than in thecase of death or Permanent Disability of Employee.5.8 This Agreement and the other agreements and arrangements referred to in this Agreement supersede and replace anyprevious agreements and discussions pertaining to the subject matter covered herein. This Agreement and any Exhibit hereto(collectively, the “Employment Documents”) constitute the entire agreement of the parties with regard to the terms of Employee’semployment, termination of employment and severance benefits, and contain all of the covenants, promises, representations,warranties, and agreements between the parties with respect to such matters. Each party to this Agreement acknowledges that norepresentation, inducement, promise, or agreement, oral or written, has been made by either party with respect to the foregoing mattersthat is not embodied in the Employment Documents, and that no agreement, statement, or promise relating to the employment ofEmployee by Employer that is not contained in the Employment Documents shall be valid or binding. Any modification or waiver ofthis Agreement will be effective only if it is in writing and signed by each party whose rights hereunder are affected thereby.5.9 The parties recognize and acknowledge, and hereby expressly waive, any right any of them may have to punitive damages.5.10 Employee represents that Employee is fully competent to manage Employee’s business affairs, has read this documentcarefully, understands all of its contents, fully understands15HOU:0024197/00043:1712670v2Exhibit 10.5the final and binding effect of this Agreement, has had the opportunity to consult with Employee’s attorney, and executes thisAgreement freely and voluntarily. Employee represents and acknowledges that in executing this Agreement Employee does not relyand has not relied upon any representation or statement not set forth herein made by Employer or the Board or by any of their respectiveagents, representatives, or attorneys with regard to the subject matter, basis, or effect of this Agreement or otherwise.5.11 The parties to this Agreement hereby agree that no special relationship of trust and reliance is, has been, or will be createdby the provisions of this Agreement or Employee’s employment arrangement.5.12 This Agreement may be executed in one or more counterparts, each of which shall be deemed to be an original, but all ofwhich together will constitute one and the same Agreement.5.13 Employer may withhold from any compensation or benefits payable under this Agreement all federal, state, city or othertaxes as may be required pursuant to any law or governmental regulation or ruling, as well as any other authorized deduction orwithholding. Furthermore, should Employee owe Employer or a Related Entity any money at the time of termination of employment,Employee authorizes and consents to Employer deducting the amount owed by Employee from compensation otherwise owedEmployee.5.14 The provisions of this Section 5.14 shall apply solely to the extent that a payment under this Agreement is subject toSection 409A of the Internal Revenue Code of 1986, as amended (the “Code”).(a) General Suspension of Payments. If Employee is a “specified employee,” as such term is defined within themeaning of Section 409A of the Code, any payments or benefits payable or provided as a result of Employee’s termination ofemployment that would otherwise be paid or provided prior to the first day of the seventh month following such termination (other thandue to death) shall instead be paid or provided on the earlier of (i) the six months and one day following Employee’s termination, (ii) thedate of Employee’s death, or (iii) any date that otherwise complies with Section 409A of the Code. In the event that Employee is entitledto receive payments during the suspension period provided under this Section, Employee shall receive the accumulated benefits thatwould have been paid or provided under this Agreement within the suspension period on the first payroll date next following the earliestday that would be permitted under Section 409A of the Code. In the event of any delay in payment under this provision, the deferredamount shall bear interest at the prime rate (as stated in the Wall Street Journal) in effect on his termination date until paid.(b) Release Payments. In the event that Employee is required to execute a release to receive any payments from theEmployer that constitute nonqualified deferred compensation under Section 409A of the Code, payment of such amounts shall not bemade or commence until the sixtieth (60th) day following such termination of employment. Any payments that are suspended16HOU:0024197/00043:1712670v2Exhibit 10.5during the sixty (60) day period shall be paid on the date the first regular payroll is made immediately following the end of such period.(c) Reimbursement Payments. The following rules shall apply to payments of any amounts under this Agreementthat are treated as “reimbursement payments” under Section 409A of the Code: (i) the amount of expenses eligible for reimbursementin one calendar year shall not limit the available reimbursements for any other calendar year (other than an arrangement providing forthe reimbursement of medical expenses referred to in Section 105(b) of the Code); (ii) Employee shall file a claim for allreimbursement payments not later than thirty (30) days following the end of the calendar year during which the expenses wereincurred, (iii) the Employer shall make such reimbursement payments within thirty (30) days following the date Employee deliverswritten notice of the expenses to the Employer; and (iv) Employee’s right to such reimbursement payments shall not be subject toliquidation or exchange for any other payment or benefit.(d) Separation from Service. For purposes of this Agreement, any reference to “termination” of Employee’semployment shall be interpreted consistent with the meaning of the term “separation from service” in Section 409A(a)(2)(A)(i) of theCode and no portion of the Severance Payments shall be paid to Employee prior to the date such Employee incurs a separation fromservice under Section 409A(a)(2)(A)(i) of the Code.(e) Installment Payments. For purposes of Section 409A of the Code and the regulations and other guidancethereunder and any state law of similar effect (including without limitation Treasury Regulations Section 1.409A-2(b)(2)(iii)), allpayments made under this Agreement (whether severance payments or otherwise) will be treated as a right to receive a series ofseparate payments and, accordingly, each installment payment under this Agreement will at all times be considered a separate anddistinct payment.(f) PPACA. To the extent that any post-termination continuation of health or medical coverage pursuant to thisAgreement would violate either Section 105(h) of the Code or the Patient Protection and Affordable Care Act of 2010 (“PPACA”) andrelated regulations and guidance promulgated thereunder, the Employer may reform this Agreement in such manner as is reasonablynecessary to provide the Employee with the intended benefit hereunder in a manner that complies with the PPACA; provided, however,that such reformation shall not result in a violation of Code Section 409A.(g) General. Notwithstanding anything to the contrary in this Agreement, it is intended that the severance benefits andother payments payable under this Agreement satisfy, to the greatest extent possible, the exemptions from the application of Section409A of the Code provided under Treasury Regulations Sections 1.409A-1(b)(4), 1.409A-1(b)(5), and 1.409A-(b)(9) and thisAgreement will be construed to the greatest extent possible as consistent with those provisions. The commencement of payment orprovision of any payment or benefit under this Agreement shall be deferred to the minimum extent necessary to prevent the impositionof any excise taxes or penalties on the Employer or Employee.17HOU:0024197/00043:1712670v2Exhibit 10.55.15 The paragraph headings have been inserted for purposes of convenience and shall not be used for interpretive purposes.[Signature Page Follows]18HOU:0024197/00043:1712670v2Exhibit 10.5IN WITNESS WHEREOF, Employer and Employee have duly executed this Agreement in multiple originals to beeffective on the Effective Date.EMPLOYERCRESTWOOD OPERATIONS LLCBy: Name: Robert G. PhillipsTitle: Chief Executive OfficerEMPLOYEE Name: Joel Lambert HOU:0024197/00043:1712670V2Exhibit 10.6EMPLOYMENT AGREEMENTThis Employment Agreement (“Agreement”), is made and entered into as of the 1st day of January, 2014, (the “EffectiveDate”) between Crestwood Operations LLC, a Delaware limited liability company (“Employer”), and Joel Moxley (“Employee”).W I T N E S S E T H:WHEREAS, Employer desires to employ Employee, and Employee desires to be employed by Employer, pursuant to theterms and conditions set forth in this Agreement;NOW, THEREFORE, for and in consideration of the mutual promises, covenants, and obligations contained herein,Employer and Employee agree as follows:SECTION 1: EMPLOYMENT AND DUTIES.1.1 Employer agrees to employ Employee, and Employee agrees to be employed solely by Employer, beginning as of theEffective Date and, except as set forth below, continuing through December 31, 2015 (the “Initial Term”), unless earlier terminatedpursuant to Section 3 of this Agreement. Following expiration of the Initial Term, this Agreement will be automatically renewed forsuccessive 1-year terms following the Initial Term (each, a “Renewal Term” and, together with the Initial Term, the “Term”) unlesseither party gives the other party no less than 30 days’ written notice prior to the expiration of the Term of such Party’s intent not torenew the Agreement (a “Notice of Non-Renewal”). Notwithstanding the foregoing, the Term (including any Renewal Terms) andEmployee’s employment pursuant to this Agreement may be terminated at any time as set forth below, subject to the terms of thisAgreement. At the expiration of the Term following delivery of a Notice of Non-Renewal, Employee’s employment with Employer(and any affiliates or assignees of Employer) shall terminate, and this Agreement shall have no further force or effect except withrespect to Employee’s obligations pursuant to Section 3.5.1.2 Beginning as of the Effective Date, Employee shall be employed as Senior Vice President, Operations Services.Employee shall also serve in such other executive capacities as may be reasonably requested from time to time by Employer or theBoard of Directors (the “Board”) of the Employer, and shall report directly to the Chief Executive Officer of the Employer.Employee agrees to perform diligently and to the best of Employee’s abilities, and in a trustworthy, competent, businesslike, andefficient manner, the duties and services pertaining to any such position as reasonably determined by Employer, as well as suchadditional or different duties and services that Employee from time to time may be reasonably directed to perform by Employer.Employee shall, during the period of Employee’s employment by Employer, devote Employee’s full business time, energy, and bestefforts to the business and affairs of Employer.1.3 Employee shall at all times comply with and be subject to such policies and procedures that Employer may establish fromtime to time for Employer’s executives and employees, including,1HOU:0024197/00043:1712695v2Exhibit 10.6without limitation, Employer’s Code of Business Conduct as adopted by Employer and as amended from time to time (the “Code ofBusiness Conduct”).1.4 Except with the advance written permission of the Board and with respect to Employee’s existing directorships identifiedon Exhibit A hereto, Employee may not engage or participate, directly or indirectly, in any other business, investment, or activity that(a) could interfere with Employee’s performance of Employee’s duties hereunder, (b) is contrary to the best interests of Employer,Crestwood Equity Partners, LP, Crestwood Midstream Partners, LP, or any of their respective subsidiaries (each a “Related Entity”), or(c) requires any significant portion of Employee’s business time. Notwithstanding the foregoing, the parties recognize that Employeemay engage in passive personal investments and other non-competitive business activities that do not conflict with the business andaffairs of Employer or any Related Entities or materially interfere with Employee’s performance of Employee’s duties hereunder;provided, that with the exception of any civic, charitable, or educational boards or committees that do not unreasonably interfere withEmployee’s performance of Employee’s duties hereunder, Employee may not serve as a manager or on the board of directors or similarbody of any entity other than Employer or a Related Entity during the Term without prior approval therefor by the Board.1.5 Employee acknowledges and agrees that Employee has a fiduciary duty of loyalty, fidelity, and allegiance to act at all timesin the best interests of Employer and the other Related Entities and to do no act that could, directly or indirectly, injure any such entity’sbusiness, interests, or reputation. In furtherance of the foregoing, Employee shall present to the Employer all material businessopportunities or ventures known to Employee, independently or with others, that are within the purposes of Employer or any RelatedEntity, including, without limitation, opportunities that may compete with Employer or a Related Entity or could reasonably beexpected to be implemented by Employer or a Related Entity. It is agreed that any direct or indirect interest in connection with, or anybenefit from, any outside activities, particularly commercial activities, which might in any way adversely affect Employer or any of theRelated Entities involves a possible conflict of interest. In keeping with Employee’s fiduciary duties to Employer, Employee agrees thatduring the employment relationship Employee shall not knowingly become involved in a conflict of interest with Employer or any ofthe Related Entities, whether directly or indirectly through a spouse or other family member, or upon discovery thereof, allow such aconflict to continue. Moreover, Employee agrees that Employee shall disclose to the Employer any facts which might involve such aconflict of interest that has not been approved in writing by the Employer.SECTION 2: COMPENSATION AND BENEFITS.2.1 Employee’s base salary during the Term shall be Four Hundred Thirty-Five Thousand Dollars ($435,000) per annum,subject to increase at the discretion of the Board (“Base Salary”), which shall be paid in accordance with Employer’s standard payrollpractice. In addition to the Base Salary, Employee shall be eligible to be considered for a target bonus (a “Bonus”) in each calendar yearduring the Term, payable in accordance with and pursuant to Employer’s then-current2HOU:0024197/00043:1712695v2Exhibit 10.6bonus plan (“Bonus Plan”). For the 2014 bonus year, the target bonus for Employee will be equal to 85% of his Base Salary and shall besubject to such terms and conditions as are established by the Board (including, if applicable, its Compensation Committee) for awards ofequity compensation made to similarly situated executives of the Employer. Thereafter, the target bonus for Employee will becomparable to the bonus opportunity provided to similarly situated executives of the Employer. The Bonus Plan will be implementedand administered by the Board, and any Bonuses payable thereunder shall be based upon a number of factors determined and set by theBoard in its sole discretion. Such factors may include, but not be limited to, the achievement by Employer of certain performanceobjectives, and the operation of Employer within the budgets approved by the Board. Employee must be employed by Employer at thetime a Bonus is declared as a condition of receiving any such Bonus.2.2 During the Term, Employee shall be eligible to receive annual awards under the terms of the Crestwood Equity PartnersLP Long Term Incentive Plan and the Crestwood Midstream Partners LP Long Term Incentive Plan. For the 2014 grant cycle, theEmployee shall receive an award of restricted units, with a total target equity grant level for Employee equal to 110% of his Base Salary.These restricted units will be granted equally from both plans and shall be subject to such terms and conditions as are established by theBoard (including, if applicable, its Compensation Committee) for awards of equity compensation made to similarly situated executives ofthe Employer. Thereafter, the target grant level for Employee will be comparable to the level of equity granted to similarly situatedexecutives of the Employer, provided such grants shall be made at the discretion of the Board. Equity awards granted to Employeeunder the foregoing plans shall include provisions that provide for accelerated vesting in the event of a Change in Control, upontermination of Employee’s employment by the Employer without Cause, or upon Employee’s resignation with Employee Cause (forpurposes of this Section 2.2 only, each of “Change in Control,” “Cause” and “Employee Cause” to be as such terms are defined in therespective award agreements). Notwithstanding the foregoing, the level of equity compensation to be awarded to the Employee for the2014 and 2015 grant cycles shall be reduced to reflect his prior award of incentive units in Crestwood Holdings Partners LLC. For the2014 grant cycle, the Employee shall receive 1/3 of what would otherwise be the recommended equity awards proposed by theCompensation Committees of Crestwood Equity Partners LP and Crestwood Midstream Partners LP. For the 2015 grant cycle, theEmployee shall receive 2/3 of such recommended equity awards.2.3 During the Term, Employer shall pay or reimburse Employee for all reasonable and customary business expensesactually incurred by Employee during the Term in the course of Employee’s employment; provided that such expenses are incurredand accounted for in accordance with Employer’s applicable policies and procedures. Employer shall provide to Employeeofficer/director liability insurance coverage to cover any claims that may be made arising from Employee’s past, present, or futureactivities on behalf of Employer or any Related Entity, in the same manner and of the same kind as such insurance is provided to theother officers and directors of Employer.2.4 During the Term, Employer shall furnish Employee with such fringe benefit programs that are maintained by Employerand that are made available to Employer’s management3HOU:0024197/00043:1712695v2Exhibit 10.6generally, under the same terms as those provided to Employer’s management generally. Employee shall bear any tax effects orobligations stemming from any such policies and programs or their amounts.2.5 Employee acknowledges that Employee shall have no vested rights under or in respect of Employee’s participation in anyemployee benefit program, plan, or coverage except as expressly provided under the terms thereof. Notwithstanding anything in thisAgreement, it is specifically understood and agreed that Employer shall not be obligated to institute, maintain, or refrain from changing,amending, or discontinuing any employee benefit program, plan, or coverage applicable to Employee, so long as any such actions orinactions in this regard by Employer are similarly applicable to covered executive employees of Employer generally.2.6 Employee shall be entitled to four (4) weeks of paid vacation per calendar year, to be provided in accordance withEmployer’s standard policy and to be taken at such time as mutually agreed by Employee and Employer.SECTION 3: TERMINATION OF EMPLOYMENT AND EFFECTS OF SUCH TERMINATION.3.1 Termination Generally. Employee’s employment with Employer (a) shall be terminated prior to the end of the Term (i)upon the death of Employee, or (ii) upon Employee’s Permanent Disability (as defined below), and (b) may be terminated prior to theend of the Term (i) at any time by Employer upon notice to Employee, (ii) at any time by Employee upon thirty (30) days’ prior writtennotice to Employer, or (iii) at any time by Employee if Employee has Employee Cause and complies with the notice proceduresdescribed below. The date of termination is referred to herein as the “Termination Date.”3.2 Bad Leaver Termination. If Employee’s employment is terminated under any of the circumstances set forth in Section3.2(a), Employee shall be entitled to receive only the benefits set forth in Section 3.2(b) below:(a) Bad Leaver Conditions.(i) Termination by Employer for Employer Cause. Employer termination of Employee’s employment for“Employer Cause” shall mean termination by Employer for any of the following: if Employee (a) has been indicted or convicted of, orhas entered a plea of guilty or nolo contendere to, a felony charge or crime involving moral turpitude, or, in the course of Employee’semployment has engaged in fraudulent or criminal activity (whether or not prosecuted), (b) has failed to follow reasonable directions ofEmployer, provided that the foregoing failure shall not be “Employer Cause” if Employee in good faith believes that such direction isillegal and promptly so notifies the Board, (c) has failed to devote all of Employee’s professional time to the Employer and affiliates ofEmployer, except as permitted by the Employer, (d) has materially breached any policy or code of conduct of the Employer, (e) hasmaterially breached any4HOU:0024197/00043:1712695v2Exhibit 10.6provision of this Agreement or any other agreement between Employee and the Employer or Related Entity, (f) has received a kickbackor rebate of any fee or expense paid by Employer, (g) has engaged in the use of illegal drugs, the persistent excessive use of alcohol, orany other activity that materially impairs Employee’s ability to perform Employee’s duties hereunder or results in conduct bringingEmployer or any Related Entity into substantial public disgrace or disrepute, or (h) engages in intentional, reckless, or grossly negligentconduct that has or is reasonably likely to have a material adverse effect on Employer or any Related Entity; provided, however, thatwith respect to subsections (c), (d) and (e) of this Section 3.2(a)(i), the Board may elect, in its sole discretion, to allow Employee aperiod of time as determined by the Board to cure the act, conduct or event constituting Employer Cause under such subsections.(ii) Employee Resignation. Employee resigns for any reason other than having Employee Cause (as definedbelow in Section 3.3(a)(i)).(b) Bad Leaver Consequences.(i) Employee shall be entitled to receive, within 30 days of the Termination Date or such shorter period asmay be required by applicable state law, any Base Salary that was accrued (on a pro rata basis) but unpaid as of the Termination Date(“Accrued Salary”) and such other benefits provided to Employee pursuant to the terms of Employer’s employee benefit plans(which, for the avoidance of doubt, does not include any Bonus payments) that were accrued by Employer in its books and records, butnot forfeited, cancelled, or previously paid, as of the Termination Date (“Accrued Benefits,” or, collectively with Accrued Salary,“Accrued Compensation”); and(ii) Except for Accrued Compensation, Employee shall forfeit, from and after the Termination Date,Employee’s rights to any and all future compensation from Employer or any Related Entity to which Employee may be entitled and toall future benefits for which Employee may be eligible, in either case under this Agreement or otherwise, including without limitationany Bonus payments (including any earned but unpaid Bonus payments or portions thereof) that would have been payable had Employeeremained employed through the date such Bonus payments would have been paid. Except for Accrued Compensation, Employer’sobligations to pay or provide Employee with future compensation or benefits shall fully and forever cease and terminate as of theTermination Date.3.3 Good Leaver Termination. Subject to Section 3.8, if Employee’s employment is terminated under any of thecircumstances set forth in Section 3.3(a), and Employee complies with the requirements of Section 3.7, Employee shall be entitled toreceive Accrued Compensation as well as the benefits set forth in Section 3.3(b) below (“Severance Benefits”):(a) Good Leaver Conditions.5HOU:0024197/00043:1712695v2Exhibit 10.6(iii) Employee Resignation with Employee Cause. “Employee Cause” will exist if one of the followingoccurs: (A) a substantial and continuing diminution in the nature of Employee’s responsibilities (provided, however, that neither achange in Employee’s reporting relationship, nor a diminution in responsibilities as a result of Employer exercising its rights underSection 3.7 will trigger this provision); (B) a material breach by Employer of any material provision of this Agreement; (C) a materialand continuing reduction in the aggregated total of Employee’s Base Salary, target Bonus percentage and target equity percentage; or (D)reassignment by the Company of the Employee’s principal place of employment to a location more than fifty (50) miles from hisprincipal place of employment on the Effective Date, but excluding normal business travel consistent with Employee’s duties,responsibilities and position. For Employee to terminate for Employee Cause: (i) Employer must be notified by Employee in writingwithin 30 days of the date Employee becomes aware of the event that would allow Employee to terminate employment for EmployeeCause, with such notice setting forth such event in reasonable detail; (ii) the event must remain uncorrected by Employer for 30 daysfollowing Employer’s receipt of such notice (the “Notice Period”); and (iii) such termination must occur within 30 days after theexpiration of the Notice Period.(iv) Employer Termination without Cause. Employer Termination without Cause shall mean termination byEmployer for any reason other than for Employer Cause.(v) Death. Death shall mean Employee’s death.(vi) Permanent Disability. Termination due to Employee’s “Permanent Disability” shall mean the inabilityof Employee, with or without reasonable accommodation, by reason of illness, incapacity, or other disability, to perform Employee’sduties or fulfill Employee’s employment obligations to Employer, as determined by the Board and as certified in writing by a competentmedical physician chosen by the Board, for a cumulative total of 180 days in any 12 month period; provided, however, that such periodof absence may be extended if required by applicable law.(b) Good Leaver Consequences.(i) A severance payment equal to two (2) times the sum of (A) the Base Salary calculated as of theTermination Date or, if greater, before any reduction not consented to by the Employee and (B) the average of the annual Bonus paid toEmployee for the prior two (2) year period. In the event Employee has not worked one full bonus year as of the Termination Date, theamount for purposes of Section 3.3(b)(i)(B) shall be Employee’s target Bonus amount for 2014 pursuant to Section 2.1; and in the eventEmployee has only worked one full bonus year as of the Termination Date, the amount for purposes of Section 3.3(b)(i)(B) shall beshall be the average of the annual Bonus paid to Employee for the prior year and Employee’s target Bonus amount for 2014 pursuant toSection 2.1. The severance payment shall be paid in equal installments in accordance with the Employer’s normal payroll proceduresover the period commencing on the Termination Date and ending on the date that is eighteen (18) months following the TerminationDate; provided,6HOU:0024197/00043:1712695v2Exhibit 10.6however that in the event that (1) Employee serves a Severance Waiver Notice in accordance with Section 4.1, or (2) Employeeviolates any of the covenants set forth in this Agreement or in any separation agreement, general release, or similar agreement withEmployer, Employee shall thereafter forfeit the right to receive any further severance payment installments payable hereunder.During the period that Employee is entitled to receive severance payments pursuant to this Section 3.3(b), the Employer shall alsoprovide medical benefits to Employee under terms and conditions that are not less favorable than provided to executive officers of theEmployer; provided, however, that (X) Employee must elect to receive continuation of health insurance coverage pursuant to theConsolidated Omnibus Budget Reconciliation Act (COBRA); (Y) Employee will be required to pay the amount that an active employeeof the Employer would pay to receive such coverage and the Employer will be responsible for the employer portion of the insurancepremium payments (which amount will be treated as imputed income to the Employee); and (Z) the Employer’s obligation to pay aportion of the Employee’s COBRA premiums shall cease on the first day of the month after Employee obtains reasonably comparablehealth care coverage from a subsequent employer or other source.(ii) Except as set forth in this Section 3.3(b) and as provided in Section 2.2, from and after the TerminationDate, (A) Employee forfeits Employee’s rights to any and all compensation from Employer or any Related Entity to which Employeemay be entitled and to all future benefits for which Employee may be eligible, in either case under this Agreement or otherwise,including without limitation any Bonus payments (excluding Employee’s Bonus payment for the calendar year of termination, pro-ratedfor the portion of the calendar year of termination during which Employee was employed by Employer, such pro-rated Bonus to bepayable on the date that such bonuses are otherwise paid by the Employer to its employees), and (B) Employer’s obligations to pay orprovide Employee with any such future compensation or future benefits shall fully and forever cease and terminate.(iii) If Employee’s employment is terminated by reason of Employee’s death, Employee’s estate will beentitled to payment of all amounts due under Section 3.3(b). If Employee’s employment is terminated because of Employee’sPermanent Disability, Employee’s legal guardian will be entitled to payment of the amounts due under Section 3.3(b) in accordancewith the terms and conditions set forth therein.3.4 Expiration. If the Agreement expires and Employee’s employment terminates as a result of the delivery of a Notice ofNon-Renewal by Employer to Employee, Employee shall be entitled to receive the Severance Benefits provided pursuant to the termsand conditions of Section 3.3(b); provided, however, that if Employer terminates the Agreement and Employee’s employment forEmployer Cause following Employee’s delivery of a Notice of Non-Renewal but prior to the expiration of the Term, or Employeerefuses to remain employed through the expiration of the Term, Employee shall forfeit and not be entitled to the Severance Benefits. Ifthe Agreement expires and Employee’s employment terminates as a result of the delivery of a Notice of Non-Renewal by7HOU:0024197/00043:1712695v2Exhibit 10.6Employee to Employer, Employee shall only be entitled to receive the Accrued Compensation pursuant to the terms and conditions ofSection 3.2(b).3.5 Continuing Obligations. Termination or expiration of this Agreement and the employment relationship does not terminatethose obligations of Employee imposed by this Agreement that are continuing obligations, including, without limitation, Employee’sobligations under Section 4.3.6 Post-Termination Assistance. During any period during which any Severance Benefits or other monies are being paid toEmployee under this Agreement after the Termination Date, Employee shall provide to Employer reasonable levels of assistance toEmployer in answering questions or otherwise cooperating concerning the business of Employer, transition of responsibility, orlitigation; provided that Employee shall be fully and promptly reimbursed for all out of pocket expenses of Employee reasonablyincurred in connection with such assistance and any such assistance after the period during which any Severance Benefits or othermonies are being paid shall not interfere or conflict with the obligations that Employee may owe to any other employer.3.7 Reduction or Alteration in Duties. When either the Employer or Employee serves a notice of termination or a Notice ofNon-Renewal, the Employer will have the right in its absolute discretion to (i) assign reduced, alternative, or no duties to the Employee,and require the Employee to act as directed by the Employer, including excluding the Employee from the premises of the Employer orother Related Entity, and (ii) prohibit the Employee from discussing the Employee’s termination with employees, agents, or any thirdparty except with respect to Employee’s communication with federal, state or local governmental agencies as may be legally required orotherwise protected by law; provided, however, that in the event of a reduction or alteration of duties in accordance with Section 3.7(i),Employer will still be required to make the Base Salary payments pursuant to Section 2.1 through the date of termination ofEmployee’s employment.3.8 Release. As a condition to the payment of any severance benefit hereunder, including the Severance Benefits, Employer,in its sole discretion, may require Employee (or Employee’s executor, legal guardian, or other legal representative in the case of theEmployee’s death or Permanent Disability) to first execute and not revoke a waiver and release of all claims against Employer and theRelated Entities in a form reasonably acceptable to Employer within 21 days following the Termination Date.3.9 Forfeiture of Benefits. Except as otherwise provided in Section 4.1 hereof, in the event Employee breaches any ofEmployee’s obligations under Section 4 of this Agreement, and if Employee is otherwise entitled to receive Severance Benefits underSection 3.3, Employee shall fully, completely, and permanently forfeit any and all rights to such Severance Benefits, and Employerand each Related Entity shall have the right to fully, completely, and permanently terminate payment of any amounts to whichEmployee would otherwise be entitled pursuant to these provisions and recover the amount equal to the Severance Benefits previouslypaid to Employee under Section 3.3. The foregoing forfeiture of rights to the Severance Benefits shall not in any way limit or restrict8HOU:0024197/00043:1712695v2Exhibit 10.6Employer’s rights and remedies pursuant to Section 4, including the right to seek injunctive relief to enforce compliance with suchobligations and to recover damages for any breach. Employee agrees that all disputes relating to Employee’s employment or terminationof employment shall be resolved through Employer’s Dispute Resolution Plan as provided in Section 5.6 hereof.3.10 Severance Benefits Not an Offer of Employment. The payment of any Severance Benefits or other monies toEmployee under this Agreement after the Termination Date shall not constitute an offer or a continuation of employment of Employee.In no event shall Employee represent or hold himself out to be an employee of Employer after the Termination Date. Except whereEmployer is required by law to withhold any federal, state, or local taxes, Employee shall be responsible for any and all federal, state, orlocal taxes that arise out of any payments to Employee hereunder.3.11 Recharacterization of Termination. Notwithstanding any other provision of this Agreement, if following the terminationof employment Employer discovers that grounds existed as of the Termination Date for a termination for Employer Cause, then suchtermination shall be deemed to be a termination for Employer Cause and Employee shall only be entitled to the payments and benefitsprovided in Section 3.2. In the event Employee’s termination is reclassified as a termination for Employer Cause pursuant to thisSection 3.11, Employee’s termination shall be so treated and classified for all purposes under this Agreement and any other agreementsbetween Employee and Employer, and Employee shall repay to Employer any monies or benefits received by Employee followingtermination to which Employee would not have been entitled upon being terminated for Employer Cause.SECTION 4: COVENANT NOT TO COMPETE; CONFIDENTIALITY.4.1 Non-Compete. The parties hereto recognize that Employee is retained by Employer as part of a professional, management,and executive staff of Employer whose duties include the formulation and execution of management policy. Therefore, in exchange forthe consideration specified herein and as a material incentive for Employer to enter into this Agreement, and to enforce Employee’sobligations regarding confidentiality pursuant to Section 4.5 hereof, Employee hereby agrees that during the term of Employee’semployment hereunder (including any period of employment in which Employee has reduced or altered duties pursuant to Section 3.7)and, in the event of a termination of Employee’s employment pursuant to Section 3.3 (Good Leaver Termination), for a period ofeighteen (18) months following the Termination Date (the “Non-Compete Period”), Employee shall not, within North America, actor engage in material competition with the activities or plans of Employer or any Related Entity as they exist up to the time ofEmployee’s termination of employment. “Material Competition” by Employee shall mean (A) engaging in or conducting anybusiness or investment activity in any capacity that directly competes with or has a material adverse economic effect on any of thematerial business activities or business plans of Employer or any Related Entity, or with respect to a business or asset that was beingevaluated by Employer or any Related Entity at any time during the Term and prior to the termination9HOU:0024197/00043:1712695v2Exhibit 10.6of employment, or (B) rendering advice or services to, whether as an employee, consultant, advisor, agent, shareholder, independentcontractor, investor, partner, member, owner, or otherwise, any company, business or other entity that derives a material part of itsbusiness from activities that directly compete with the business activities or business plans of Employer or any Related Entity; provided,however, that Employee shall be permitted to acquire a passive stock interest in such a business provided that the stock acquired ispublicly traded and Employee does not beneficially own more than 2% of the outstanding interest in such business. Notwithstanding theforegoing, at any time during the eighteen-month period following the Termination Date, Employee may, at Employee’s option, serveon the Employer a written notice waiving the right to any and all future installments of the Severance Benefit payments pursuant toSection 3.3(b)(i) (a “Severance Waiver Notice”), and upon delivery of the Severance Waiver Notice, Employee shall no longer bebound by the restrictions set forth in this Section 4.1 for the period on and after the date on which the Severance Waiver Notice isdelivered to the Employer; provided, however, that notwithstanding the delivery of a Severance Waiver Notice, Employee willcontinue to be bound by the remaining obligations set forth in this Agreement, including but not limited to those covenants of Employeeset forth in Section 4.2 and Section 4.5 hereof.4.2 Non-Solicit. During the term of Employee’s employment hereunder (including any period of employment in whichEmployee has reduced or altered duties pursuant to Section 3.7) and for a period of eighteen (18) months following the TerminationDate (the “Non-Solicitation Period”), Employee will not, directly or indirectly, solicit or induce (i) any person who is employed byEmployer or any of the Related Entities or was so employed within the six-month period prior to the Termination Date (A) to interferewith the activities or businesses of Employer or any Related Entity or (B) to discontinue such person’s employment with Employer orany of the Related Entities, nor shall Employee (or any business or entity with which Employee is then involved) employ any suchperson or (ii) any customer of Employer to discontinue or reduce its business with Employer (either through the transition of suchbusiness to a competitor of Employer or otherwise); provided, however, that general solicitation of the public for employment shall notconstitute a solicitation hereunder so long as such general solicitation is not designed to target any such person.4.3 Recognition of Limitations as Reasonable. Employee understands that the provisions of Sections 4.1 and 4.2 hereof maylimit Employee’s ability to earn a livelihood in a business similar to the business in which Employee is involved, but as a member of themanagement group of Employer Employee nevertheless agrees and hereby acknowledges that (i) such provisions do not impose agreater restraint than is necessary to protect the goodwill, trade secrets, or other business interests of Employer and any of the RelatedEntities; (ii) such provisions contain reasonable limitations as to time, scope of activity, and geographical area to be restrained; and (iii) theconsideration provided hereunder, including without limitation, any amounts or benefits provided under Section 3 hereof and theConfidential Information provided pursuant to Section 4.5, is sufficient to compensate Employee for the restrictions contained inSections 4.1 and 4.2 hereof. In consideration of the foregoing and in light of Employee’s education, skills, and abilities, Employee agreesthat Employee will not assert that, and it should not be considered that, any provisions of10HOU:0024197/00043:1712695v2Exhibit 10.6Section 4.1 or 4.2 otherwise are void, voidable, or unenforceable or should be voided or held unenforceable.4.4 Modifications to Section 4. If, at the time of enforcement of Section 4 of this Agreement, a court shall hold that the period,scope, or geographical area restrictions stated herein are unreasonable under circumstances then existing, the parties hereto agree thatthe maximum period, scope, or geographical area reasonable under such circumstances shall be substituted for the stated period, scope,or geographical area and that the court shall revise the restrictions contained herein to cover the maximum period, scope, andgeographical area permitted by law. If, in any proceeding, a court refuses to enforce all of the separate covenants deemed included hereinbecause, taken together, they are deemed more extensive than necessary to assure Employer of the intended benefit of this Agreement,it is expressly understood and agreed that those of such covenants or portions of such covenants that, if eliminated, would permit theremaining separate covenants or portions thereof to be enforced in such proceeding shall, for the purpose of such proceeding, be deemedeliminated from the provisions hereof. Employee acknowledges that Employee is a member of Employer’s management group withaccess to Employer’s confidential business information and Employee’s services are unique to Employer and the Related Entities.Employee therefore agrees that the remedy at law for any breach by Employee of any of the covenants and agreements set forth in thisSection 4 will be inadequate and that in the event of any such breach, Employer may, in addition to the other remedies that may beavailable to it at law, apply to any court of competent jurisdiction to obtain specific performance and/or injunctive relief prohibitingEmployee (together with all those persons associated with Employee) from the breach of such covenants and agreements and toenforce, or prevent any violations of, the provisions of this Agreement. In addition, in the event of an alleged breach or violation byEmployee of this Section 4, the applicable Non-Compete Period and Non-Solicitation Period set forth in this Section shall be tolled untilsuch breach or violation has been cured.4.5 Confidential Information. Employee acknowledges that pursuant to the employment hereunder, Employee occupies aposition of trust and confidence. Accordingly, in order to facilitate the performance of this Agreement and the activities contemplated bythis Agreement, Employee shall be provided with or given access to, or Employee may develop, certain proprietary or confidentialinformation (“Confidential Information”) of Employer or a Related Entity. Confidential Information includes, without limitation,information pertaining to Employer’s or the Related Entities’ past, current and future business plans, corporate opportunities,operations, acquisition, merger or sale strategies, production, product development, product names and marks, marketing, cost andpricing structure, margins, profitability, operation or production procedures or results, partners, partnership or other businessarrangements or agreements with third parties, customers, customer sales volumes, customer contracts, books, records and documents,technical information, equipment, services and processes. Subject to the last sentence of this Section, during the term of Employee’semployment and after the termination of Employee’s employment, Employee hereby agrees not to use or to disclose to any person,other than in the discharge of Employee’s duties under this Agreement, any Confidential Information of Employer or any RelatedEntities.11HOU:0024197/00043:1712695v2Exhibit 10.6Information shall not be deemed to be Confidential Information for purposes of this Agreement that: (i) is or hereafter becomes publiclyknown through no act or omission of Employee; (ii) is received by Employee without restriction on disclosure from a third party whodisclosed the information without violating any restriction on confidentiality or disclosure; or (iii) is independently developed after thetermination of Employee’s employment with Employer by Employee without reference to the Confidential Information and withoutviolation of any confidentiality restriction. If Employee violates this agreement of confidentiality, Employer shall, in addition to anyother remedy provided by law, be permitted to pursue an action for injunctive relief; monetary damages, or both. Employeeacknowledges that all such Confidential Information constitutes confidential and/or proprietary information of Employer and the RelatedEntities and agrees that such Confidential Information shall be kept confidential, such Confidential Information shall be used solely forthe purpose of performing the obligations hereunder or activities contemplated by this Agreement, and that Employee shall nototherwise disclose or make use of such Confidential Information except in response to a court order, provided that when responding to acourt order, Employee shall provide written notice of the court order to Employer in advance of any disclosure in response thereto.4.6 Intangible Rights. Employee agrees that all ideas, concepts, processes, discoveries, devices, machines, tools, materials,designs, improvements, inventions, computer software, and other things of value (“Intangible Rights”), if patented or subject to apatent application, and Confidential Information, which are conceived, made, invented or suggested either by Employee alone or incollaboration with others during the Term and relating to the business of Employer or a Related Entity, shall be promptly disclosed inwriting to Employer and shall be the sole and exclusive property of Employer. Employee hereby assigns to Employer all of Employee’sright, title, and interest in and to all such intangible rights that are patented or subject to a patent application by Employer and itssuccessors or assigns, and in and to Confidential Information. In the event that any of said Intangible Rights shall be deemed byEmployer to be patentable or otherwise registerable under any federal, state or foreign law, Employee further agrees that during theTerm plus 60 days, at the expense of Employer, Employee will execute all documents and do all things necessary, advisable, or properto obtain patents therefor or registration thereof; and to vest in Employer full title thereto. Employee agrees that all right, title, andinterest in any and all copyrights, copyright registrations, and copyrightable subject matter that occur as a result of Employee’semployment with Employer, shall be the sole and exclusive property of Employer, and agrees that such works comprise “works forhire.” Employee hereby assigns and agrees to assign to Employer all right, title, and interest in any such copyrights, copyrightregistrations, and copyrightable subject matter that occur because of such employment.4.7 Non-Disparagement. Employee shall refrain, both during the employment relationship and after the employmentrelationship terminates, from publishing any oral or written statements about Employer or any Related Entity, or any of their respectiveofficers, employees, shareholders, investors, directors, agents or representatives that are malicious, obscene, threatening, harassing,intimidating or discriminatory and which are designed to harm any of the foregoing. The foregoing restriction shall include, but not belimited to, statements made, whether directly or12HOU:0024197/00043:1712695v2Exhibit 10.6indirectly, to or on social media, internet websites, blogs and electronic bulletin boards, as well as statements to the media, includingwriters, researchers, reporters, magazines, newspapers, book publishers, television stations, radio stations, the motion picture industry,public interest groups, and the publishing industry generally. In the event such a communication is made to anyone, it will be considereda material breach of the terms of this Agreement, and all commitments to make any payments under Section 3.3(b) will be null andvoid. Additionally, in the event any such communication materially damages the reputation of Employer, any Related Entity, or theirrespective agents, officers, directors, or employees, the Employee will be required to reimburse the Employer for any and allSeverance Benefits made under the terms of this Agreement. This provision is not intended to limit Employee’s right to give non-malicious and truthful testimony should Employee be subpoenaed to give such testimony, and the foregoing restrictions in this Section4.7 shall not apply with respect to Employee’s communication with federal, state or local governmental agencies as may be legallyrequired or otherwise protected by law.4.8 Agreement to Covenants. Each of the covenants of this Section 4 are given by Employee as part of the consideration forthis Agreement and as an inducement to Employer to enter into this Agreement and accept the obligations hereunder. Employee has hadadequate time to consider these covenants and to consult with an attorney or other advisor concerning them. Employee acknowledgesthat Employee understands these covenants and agrees to them freely and voluntarily.SECTION 5: MISCELLANEOUS.5.1 Employee and Employer expressly understand and agree that Employer may at its sole discretion assign this Agreementand transfer Employee’s employment to another Related Entity (“Subsequent Employer”) as of, or at any time after, the EffectiveDate, and no such assignment and transfer shall be deemed to be a termination of employment for purposes of Section 3, or grounds fortermination for Employee Cause; provided, however, that, effective with such assignment and transfer, all of Employer’s obligationshereunder shall be unchanged, assumed by, and be binding upon, and all of Employer’s rights hereunder shall be assigned to, suchSubsequent Employer and the defined term “Employer” as used herein shall thereafter refer to such Subsequent Employer. Employeeexpressly consents to such assignment and transfer. Except for Employee’s title, as applicable, and as otherwise provided in this Section5.1, all of the terms and conditions of this Agreement, including without limitation, Employee’s rights and obligations, shall remain infull force and effect following any such assignment and transfer of employment.5.2 Except as otherwise required by law, any written notice hereunder shall be deemed validly given, made or served (i) onthe date on which it is delivered personally, (ii) five business days after it shall have been sent by registered or certified mail (receiptrequested and postage prepaid), (iii) one business day after it is sent by overnight courier (charges prepaid), or (iv) on the same businessday when sent before 5:00 p.m., recipient’s time, and on the next business day when sent after 5:00 p.m., recipient’s time, by facsimile.If to Employer, addressed to: Crestwood Operations LLC13HOU:0024197/00043:1712695v2Exhibit 10.6700 Louisiana, Suite 2060Houston, TX 77002Facsimile: (832) 519-2200Attention: Chief Executive OfficerCopy to: Crestwood Operations LLC700 Louisiana, Suite 2060Houston, TX 77002Facsimile: (832) 519-2200Attention: Senior Vice President and GeneralCounselIf to Employee: Joel Moxley[ ][ ]or to Employee’s last known personal address.5.3 This Agreement shall be construed and enforced, and this Agreement and any disputes or controversies related heretoshall be governed by, in all respects in accordance with, the law of the State of Texas, without regard to principles of conflicts of lawthat would apply the laws of any other jurisdiction, unless preempted by federal law, in which case federal law shall govern.5.4 No failure by either party hereto at any time to give notice of any breach by the other party of, or to require compliancewith, any condition or provision of this Agreement shall be deemed a waiver of similar or dissimilar provisions or conditions at the sameor at any prior or subsequent time.5.5 It is a desire and intent of the parties that the terms, provisions, covenants, and remedies contained in this Agreement shallbe enforceable to the fullest extent permitted by law. If any such term, provision, covenant, or remedy of this Agreement or theapplication thereof to any person, association, or entity or circumstances shall, to any extent, be construed to be invalid or unenforceablein whole or in part, then such term, provision, covenant, or remedy shall be construed or re-written in a manner so as to permit itsenforceability under the applicable law to the fullest extent permitted by law. In any case, the remaining provisions of this Agreement orthe application thereof to any person, association, or entity or circumstances other than those to which they have been held invalid orunenforceable, shall remain in full force and effect.5.6 It is the mutual intention of the parties to have the option to resolve any dispute concerning this Agreement out of court.Accordingly, the parties agree that either party may elect to have any such dispute submitted for resolution through Employer’s DisputeResolution Plan or, if no such plan is in place, then pursuant to binding arbitration to be held in Harris County, Texas, in accordance withthe employment arbitration rules (except as modified below) of the American Arbitration Association and with the Expedited Proceduresthereof (collectively, the “Rules”);14HOU:0024197/00043:1712695v2Exhibit 10.6provided, however, that Employer, on its own behalf and on behalf of any of the Related Entities, shall be entitled to seek a restrainingorder or injunction in any court of competent jurisdiction to prevent any breach, threatened breach, or the continuation of any breach ofthe provisions of Sections 4 and 5 and Employee hereby consents that such restraining order or injunction may be granted without thenecessity of Employer posting any bond. Each of the parties hereto agrees that arbitration pursuant to this Section 5.6 shall be conductedby a single arbitrator selected in accordance with the Rules; provided that such arbitrator shall be experienced in deciding casesconcerning the matter which is the subject of the dispute. Each of the parties agrees that in any such arbitration that the award shall bemade in writing no more than 30 days following the end of the proceeding, that the arbitration shall not be conducted as a class action,that the arbitration award shall include factual findings or conclusions of law, and that no punitive damages shall be awarded. Any awardrendered by the arbitrator shall be final and binding and judgment may be entered on it in any court of competent jurisdiction. Each of theparties hereto agrees to treat as confidential the results of any arbitration (including, without limitation, any findings of fact and/or lawmade by the arbitrator) and not to disclose such results to any unauthorized person. In any dispute related to a termination of Employee’semployment pursuant to Section 3.2(a)(i), Employee shall only be permitted to dispute or contest whether or not a determination ofEmployer Cause was made in good faith by the Board. Employer shall bear all administrative fees and expenses of the arbitration andunless the arbitrator directs otherwise, each party shall bear its own counsel fees and expenses. Either party may appeal the arbitrationaward and judgment thereon and, in actions seeking to vacate an award, the standard of review to be applied to the arbitrator’s findings offact and conclusions of law will be the same as that applied by an appellate court reviewing a decision of a trial court sitting without a jury.5.7 This Agreement shall be binding upon and inure to the benefit of Employer, its successors in interest, or any other person,association, or entity that may hereafter acquire or succeed to all or substantially all of the business assets of Employer by any means,whether indirectly or directly, and whether by purchase, merger, consolidation, or otherwise. Employee’s rights and obligations underthis Agreement are personal and such rights, benefits, and obligations of Employee shall not be voluntarily or involuntarily assigned,alienated, or transferred, whether by operation of law or otherwise, without the prior written consent of Employer, other than in thecase of death or Permanent Disability of Employee.5.8 This Agreement and the other agreements and arrangements referred to in this Agreement supersede and replace anyprevious agreements and discussions pertaining to the subject matter covered herein. This Agreement and any Exhibit hereto(collectively, the “Employment Documents”) constitute the entire agreement of the parties with regard to the terms of Employee’semployment, termination of employment and severance benefits, and contain all of the covenants, promises, representations,warranties, and agreements between the parties with respect to such matters. Each party to this Agreement acknowledges that norepresentation, inducement, promise, or agreement, oral or written, has been made by either party with respect to the foregoing mattersthat is not embodied in the Employment Documents, and that no agreement, statement, or promise relating to the employment ofEmployee by Employer that is not contained in the Employment15HOU:0024197/00043:1712695v2Exhibit 10.6Documents shall be valid or binding. Any modification or waiver of this Agreement will be effective only if it is in writing and signed byeach party whose rights hereunder are affected thereby.5.9 The parties recognize and acknowledge, and hereby expressly waive, any right any of them may have to punitive damages.5.10 Employee represents that Employee is fully competent to manage Employee’s business affairs, has read this documentcarefully, understands all of its contents, fully understands the final and binding effect of this Agreement, has had the opportunity toconsult with Employee’s attorney, and executes this Agreement freely and voluntarily. Employee represents and acknowledges that inexecuting this Agreement Employee does not rely and has not relied upon any representation or statement not set forth herein made byEmployer or the Board or by any of their respective agents, representatives, or attorneys with regard to the subject matter, basis, oreffect of this Agreement or otherwise.5.11 The parties to this Agreement hereby agree that no special relationship of trust and reliance is, has been, or will be createdby the provisions of this Agreement or Employee’s employment arrangement.5.12 This Agreement may be executed in one or more counterparts, each of which shall be deemed to be an original, but all ofwhich together will constitute one and the same Agreement.5.13 Employer may withhold from any compensation or benefits payable under this Agreement all federal, state, city or othertaxes as may be required pursuant to any law or governmental regulation or ruling, as well as any other authorized deduction orwithholding. Furthermore, should Employee owe Employer or a Related Entity any money at the time of termination of employment,Employee authorizes and consents to Employer deducting the amount owed by Employee from compensation otherwise owedEmployee.5.14 The provisions of this Section 5.14 shall apply solely to the extent that a payment under this Agreement is subject toSection 409A of the Internal Revenue Code of 1986, as amended (the “Code”).(a) General Suspension of Payments. If Employee is a “specified employee,” as such term is defined within themeaning of Section 409A of the Code, any payments or benefits payable or provided as a result of Employee’s termination ofemployment that would otherwise be paid or provided prior to the first day of the seventh month following such termination (other thandue to death) shall instead be paid or provided on the earlier of (i) the six months and one day following Employee’s termination, (ii) thedate of Employee’s death, or (iii) any date that otherwise complies with Section 409A of the Code. In the event that Employee is entitledto receive payments during the suspension period provided under this Section, Employee shall receive the accumulated benefits thatwould have been paid or provided under this Agreement within the suspension period on the first payroll date next following the earliestday that would be permitted under Section 409A of the Code. In the event of any delay in payment under this provision, the deferredamount shall16HOU:0024197/00043:1712695v2Exhibit 10.6bear interest at the prime rate (as stated in the Wall Street Journal) in effect on his termination date until paid.(b) Release Payments. In the event that Employee is required to execute a release to receive any payments from theEmployer that constitute nonqualified deferred compensation under Section 409A of the Code, payment of such amounts shall not bemade or commence until the sixtieth (60th) day following such termination of employment. Any payments that are suspended duringthe sixty (60) day period shall be paid on the date the first regular payroll is made immediately following the end of such period.(c) Reimbursement Payments. The following rules shall apply to payments of any amounts under this Agreementthat are treated as “reimbursement payments” under Section 409A of the Code: (i) the amount of expenses eligible for reimbursementin one calendar year shall not limit the available reimbursements for any other calendar year (other than an arrangement providing forthe reimbursement of medical expenses referred to in Section 105(b) of the Code); (ii) Employee shall file a claim for allreimbursement payments not later than thirty (30) days following the end of the calendar year during which the expenses wereincurred, (iii) the Employer shall make such reimbursement payments within thirty (30) days following the date Employee deliverswritten notice of the expenses to the Employer; and (iv) Employee’s right to such reimbursement payments shall not be subject toliquidation or exchange for any other payment or benefit.(d) Separation from Service. For purposes of this Agreement, any reference to “termination” of Employee’semployment shall be interpreted consistent with the meaning of the term “separation from service” in Section 409A(a)(2)(A)(i) of theCode and no portion of the Severance Payments shall be paid to Employee prior to the date such Employee incurs a separation fromservice under Section 409A(a)(2)(A)(i) of the Code.(e) Installment Payments. For purposes of Section 409A of the Code and the regulations and other guidancethereunder and any state law of similar effect (including without limitation Treasury Regulations Section 1.409A-2(b)(2)(iii)), allpayments made under this Agreement (whether severance payments or otherwise) will be treated as a right to receive a series ofseparate payments and, accordingly, each installment payment under this Agreement will at all times be considered a separate anddistinct payment.(f) PPACA. To the extent that any post-termination continuation of health or medical coverage pursuant to thisAgreement would violate either Section 105(h) of the Code or the Patient Protection and Affordable Care Act of 2010 (“PPACA”) andrelated regulations and guidance promulgated thereunder, the Employer may reform this Agreement in such manner as is reasonablynecessary to provide the Employee with the intended benefit hereunder in a manner that complies with the PPACA; provided, however,that such reformation shall not result in a violation of Code Section 409A.17HOU:0024197/00043:1712695v2Exhibit 10.6(g) General. Notwithstanding anything to the contrary in this Agreement, it is intended that the severance benefits andother payments payable under this Agreement satisfy, to the greatest extent possible, the exemptions from the application of Section409A of the Code provided under Treasury Regulations Sections 1.409A-1(b)(4), 1.409A-1(b)(5), and 1.409A-(b)(9) and thisAgreement will be construed to the greatest extent possible as consistent with those provisions. The commencement of payment orprovision of any payment or benefit under this Agreement shall be deferred to the minimum extent necessary to prevent the impositionof any excise taxes or penalties on the Employer or Employee.5.15 The paragraph headings have been inserted for purposes of convenience and shall not be used for interpretive purposes.[Signature Page Follows]IN WITNESS WHEREOF, Employer and Employee have duly executed this Agreement in multiple originals to beeffective on the Effective Date.EMPLOYERCRESTWOOD OPERATIONS LLCBy: Name: Title: EMPLOYEE Name: Joel Moxley 18HOU:0024197/00043:1712695v2Exhibit 10.7CRESTWOOD EQUITY PARTNERS LP LONG TERM INCENTIVE PLANformerly known as the Inergy Long Term Incentive Plan (as Amended and Restated Effective February 11, 2010)SECTION 1 INTRODUCTION1.1Establishment. Inergy Holdings, LLC, a Delaware limited liability company ("Holdings"), originally established, effective June 1, 2001, theInergy Long Term Incentive Plan (the "Plan") for certain employees, non-employee directors and consultants of Holdings, Inergy GP,LLC, a Delaware limited liability company ("Inergy GP"), Inergy, L.P., a Delaware limited partnership (the "Partnership"), and theirAffiliates.Effective May 1, 2002, Holdings assigned and transferred its position and title as plan sponsor of this Plan, as well as its right, title andinterest in all outstanding Unit Option Agreements issued hereunder, to Inergy GP. Inergy GP has accepted its title and position as successorplan sponsor of this Plan.Effective April 4, 2003 Inergy GP amended the Plan increasing the aggregate number of Units that may be granted under the Plan to 867,550Common Units, including up to 282,800 phantom units;Effective January 1, 2006, Inergy GP amended and restated the Plan in order to (i) provide for the grant of Restricted Unit Awards, and (ii)clarify certain Plan provisions relating to the exercisability and vesting of Unit Options prior to the end of the Subordination Period for allSenior Subordinated Units.Effective September 11, 2007, Inergy GP amended and restated the Plan in order to (i) increase the maximum number of Units that may beissued under the Plan to 5,000,000 Common Units, and (ii) eliminate the limitation on the number of Common Units that may be issuedpursuant to phantom units awards.Effective August 14, 2008, Inergy GP amended and restated the Plan in order to allow for an automatic increase of the maximum number ofUnits that may be issued under the Plan. The increase shall occur automatically on October 1 of each year or at an earlier date in thediscretion of the Committee.Effective February 11, 2010, Inergy GP amended and restated the Plan in order to limit the term of the Plan to ten (10) years from August14, 2008, so that the Plan will terminate on August 14, 2018.Effective October 7, 2013, Inergy, L.P.’s name was changed to Crestwood Equity Partners LP and the Inergy GP, LLC’s name was changedto Crestwood Equity GP, LLC.1.2Purpose. The purpose of this Plan is to encourage employees of the Partnership, Holdings, Inergy GP, and their Affiliates to acquire a proprietaryinterest in the growth and performance of the Partnership. The Plan is also designed to assist the Partnership, Holdings, Inergy GP andtheir Affiliates in attracting and retaining employees, non-employee directors and consultants by providing them with the opportunity toparticipate in the financial success and profitability of the Partnership.SECTION 2 DEFINITIONS2.1Capitalized terms used in this document shall have the meanings as defined herein and in Appendix A to this Plan.12.2Gender and Number. Except when otherwise indicated by the context, the masculine gender shall also include the feminine gender, and thedefinition of any term herein in the singular shall also include the plural.SECTION 3 PARTICIPATION3.1Participants in the Plan shall be those Service Providers, who, in the judgment of the Committee, are performing, or during the term of their incentivearrangement will perform, important services in the management, operation and financial success of Holdings, Inergy GP or the Partnership, andsignificantly contribute, or are expected to significantly contribute, to the achievement of long-term economic objectives. Participants may begranted from time to time one or more Awards; provided, however, that the grant of each such Award shall be separately approved by theCommittee, the receipt of one such Award shall not result in the automatic receipt of any other Award, and written notice shall be given to theAward recipient, specifying the terms, conditions, rights and duties related thereto. Each Participant shall enter into an Award Agreement withInergy GP, in such form as the Committee shall determine and which is consistent with the provisions of this Plan, specifying such terms,conditions, rights and duties. Unless otherwise explicitly stated in the Award Agreement, Awards shall be deemed to be granted as of the datespecified in the grant resolution of the Committee.SECTION 4 UNIT OPTIONS4.1Grant of Options. A Participant may be granted one or more Options. The Committee may grant one or more Options to the same Participant atthe same time or at different times. Options shall be clearly identified, and in no event shall the right to exercise one Option affect the rightto exercise any other Option or affect the number of Units for which any other Option may be exercised.4.2Terms of Options. Each Option granted under the Plan (i) shall be evidenced by a written Option Award Agreement entered into by Inergy GP andthe Participant to whom the Option is granted (the "Option Holder"), (ii) shall contain those terms and conditions required by this section4.2, and (iii) may contain such other terms and conditions not inconsistent with this section 4.2, as the Committee may considerappropriate in each case.(a)Number of Units. Each Option Award Agreement shall set forth the number of Units subject to the Option, as determined by theCommittee.(b)Price. Each Option Award Agreement shall state the Option exercise price for each Unit subject to the Option. Such price shall bedetermined in each case by the Committee and may be more or less than the Unit's Fair Market Value as of the Date of Grant;provided, however, that any Option granted with an exercise price below the Unit Fair Market Value on the Date of Grant must(i) only be exercised on a date that would otherwise be a permissible distribution date for deferred compensation under Codesection 409A and (ii) in all other respects comply with Code section 409A.(c)Duration of Options and Exercisability. Each Option Award Agreement may state the duration of the Option and the extent to whichit shall become exercisable; provided, however, except in the event of a Change in Control or as provided in Section 4.5, underno circumstance shall an Option be exercisable prior to the end of the Subordination Period for all of the Senior SubordinatedUnits. To the extent that an Option Award Agreement does not state the Option Period, the Option Period shall be ten years fromthe Option's Date of2Grant. If any Option is not exercised during its Option Period, it shall be deemed to have been forfeited and of no further force oreffect.To the extent that an Option Award Agreement does not state the extent to which the Option shall become exercisable, thefollowing rules shall apply:Subject to the Restriction Period provided below in Section 4.2(c)(iii), and subject to subsections (c)(i) and (c)(ii), noOption granted under the Plan shall become exercisable until the fifth (5th) anniversary of an Option's Date of Grant or, if earlier,the fifth (5th) anniversary of an Option's Vesting Commencement Date, if any such Vesting Commencement Date is specified inthe Award Agreement. In the event of a Change in Control, all Options shall become immediately exercisable.(i)Subject to subsection (c)(iii), in the event that an Option Holder ceases to be a Service Provider because of the Option Holder's death or Disability, theOption shall be exercisable according to the following schedule based upon the number of years that have elapsed since the Option'sDate of Grant or, if a longer period of time, the number of years that have elapsed since the Option's Vesting Commencement Date,if such a date is specified in the Award Agreement.Anniversary of Option'sDate of Grant orVesting Commencement Date Percentage Exercisable1st 40%2nd 60%3rd 80%4th and beyond 100%(ii)Subject to subsection (c)(iii), in the event that an Option Holder ceases to be a Service Provider because of the termination of the Option Holder's serviceby his or her Employer without Cause, the Option shall be exercisable according to the following schedule based upon the numberof years that have elapsed from the Option's Date of Grant or, if a longer period of time, the number of years that have elapsedsince the Option's Vesting Commencement Date, if such a date is specified in the Award Agreement.Anniversary of Option'sDate of Grant orVesting Commencement Date Percentage Exercisable1st 20%2nd 40%3rd 60%4th 80%5th and beyond 100%(iii)Notwithstanding the number of years that have elapsed from an Option's Date of Grant or, if applicable, the Option's Vesting Commencement Date, inno event shall an Option be exercisable prior to the end of the Subordination Period for all of the Senior Subordinated Units except(i) as permitted under Section 4.5 and (ii) upon a Change in Control.3(d)Termination of Service, Death, Disability, etc. Each Option Award Agreement may state the period of time the Option, or exercisableportion thereof, may be exercised after a Participant ceases to be a Service Provider on account of the Service Provider's death,Disability, retirement, voluntary resignation, removal from the Board, or the Employer having terminated the Service Provider'semployment with or without Cause. To the extent that an Option Award Agreement does not state the period of time theexercisable portion of an Option may be exercised after a Participant ceases to be a Service Provider, or to the extent an OptionAward Agreement does not explain in as much specificity how the below expiration rules operate (e.g., time of day an Optionexpires) the following rules shall apply:(i)If the Participant ceases to be a Service Provider within the Option Period due to the termination by the Employer of the Participant's service (or removalas a non-employee director) for Cause, the entire Option, regardless of whether it is then exercisable, shall immediately expire and bevoid for all purposes. The effect of this Section 4.2(d)(i) shall be limited to determining the conditions under which an Option may berendered null and void, and nothing in this Section 4.2(d)(i) shall restrict or otherwise interfere with the employer's discretion withrespect to the termination of any Service Provider's employment or continuance as a director.(ii)If the Participant ceases to be a Service Provider in a manner determined by the Committee, in its sole discretion, to constitute retirement (whichdetermination shall be communicated to the Option Holder), that portion of an Option which is exercisable on the date the OptionHolder retires (ignoring any restriction on exercisability due to the Subordination Period for all of the Senior Subordinated Unitshaving not yet ended), shall remain exercisable until 5:00 p.m., Kansas City, Missouri time, on the 365th calendar day (or thefirst Business Day thereafter if the 365th day is a non-Business Day) following the date of the Participant'sretirement; provided, however, in no event may any portion of the Option be exercised following the expirationof the Option Period.In the event that, during the 365-day exercise window described above, the Option (orapplicable portion thereof) cannot be exercised solely because the Subordination Period for all of the Senior SubordinatedUnits has not yet ended, that portion of the Option which otherwise would have been exercisable at the time of theParticipant's retirement shall remain exercisable until the later of (A) 5:00 p.m., Kansas City, Missouri time, on the 180thcalendar day (or the first Business Day thereafter if the 180th day is a non-Business Day) following the end of suchSubordination Period or (B) 5:00 p.m., Kansas City, Missouri time, on the 365th calendar day (or the first Business Daythereafter if the 365th day is a non-Business Day) following the date of the Participant's retirement. If the exercisable portion of the Option is not exercised within the above permitted periods of time, the entire Option shallexpire at 5:01 p.m., Kansas City, Missouri time, on the last day such portion of the Option is exercisable and, thereafter,the Option shall be void for all purposes.(iii)If the Participant dies (A) while he or she is a Service Provider, or (B) within the 365-day period referred to in clause (ii) above, that portion of anOption which is4exercisable on the date the Option Holder dies (ignoring any restriction on exercisability due to the Subordination Periodfor all of the Senior Subordinated Units having not yet ended), shall remain exercisable by those Beneficiaries entitled todo so until 5:00 p.m., Kansas City, Missouri time, on the 365th calendar day (or the first Business Day thereafter if the365th day is a non-Business Day) following the Participant's death; provided, however, in no event may the Option beexercised following the expiration of the Option Period. In the event that, during the 365-day exercise window described above, the Option (or applicable portion thereof) cannotbe exercised solely because the Subordination Period for all of the Senior Subordinated Units has not yet ended, thatportion of the Option which otherwise would have been exercisable at the time of the Participant's death shall remainexercisable until the later of (A) 5:00 p.m., Kansas City, Missouri time, on the 180th calendar day (or the first BusinessDay thereafter if the 180th day is a non-Business Day) following the end of such Subordination Period or (B) 5:00 p.m.,Kansas City, Missouri time, on the 365th calendar day (or the first Business Day thereafter if the 365th day is a non-Business Day) following the date of the Participant's death. If the exercisable portion of the Option is not exercised within the above permitted periods of time, the entire Option shallexpire at 5:01 p.m., Kansas City, Missouri time, on the last day such portion of the Option is exercisable and, thereafter,the Option shall be void for all purposes.(iv)If the Participant ceases to be a Service Provider because the Participant is Disabled, that portion of an Option which is exercisable on the date of suchcessation of service (ignoring any restriction on exercisability due to the Subordination Period for all of the Senior SubordinatedUnits having not yet ended) shall remain exercisable until 5:00 p.m., Kansas City, Missouri time, on the 365th calendar day(or the first Business Day thereafter if the 365th day is a non-Business Day) following the date the Participantceased to be a Service Provider because of his or her Disability; provided, however, in no event may theOption be exercised following the expiration of the Option Period.In the event that, during the 365-day exercise window described above, the Option (or applicable portion thereof) cannotbe exercised solely because the Subordination Period for all of the Senior Subordinated Units has not yet ended, thatportion of the Option which otherwise would have been exercisable at the time of the Participant's cessation of service onaccount of a Disability shall remain exercisable until the later of (A) 5:00 p.m., Kansas City, Missouri time, on the 180thcalendar day (or the first Business Day thereafter if the 180th day is a non-Business Day) following the end of suchSubordination Period or (B) 5:00 p.m., Kansas City, Missouri time, on the 365th calendar day (or the first Business Daythereafter if the5365th day is a non-Business Day) following the date of the Participant having ceased to be a Service Provider on accountof a Disability. If the exercisable portion of the Option is not exercised within such above permitted periods of time, the entire Option shallexpire at 5:01 p.m., Kansas City, Missouri time, on the last day such portion of the Option is exercisable and, thereafter,the Option shall be void for all purposes.(v)If the Participant ceases to be a Service Provider due to (A) the Participant's voluntary resignation or (B) the removal of the Participant from the Boardor the Employer's termination of employment without Cause, that portion of the Option which is exercisable on the date the OptionHolder ceased to be a Service Provider (ignoring any restriction on exercisability due to the Subordination Period for all of theSenior Subordinated Unit having not yet ended), shall remain exercisable until 5:00 p.m., Kansas City, Missouri time, on the180th calendar day (or the first Business Day thereafter if the 180th day is a non-Business Day) following thedate the Participant ceased to be a Service Provider; provided, however, in no event may the Option beexercised following the expiration of the Option Period.In the event that, during the 180-day exercise window described above, the Option (or applicable portion thereof) cannotbe exercised solely because the Subordination Period for the Senior Subordinated Units has not yet ended, that portion ofthe Option which otherwise would have been exercisable at the time the Participant ceased to be a Service Provider, shallremain exercisable until the later of (A) 5:00 p.m., Kansas City, Missouri time, on the 180th calendar day (or the firstBusiness Day thereafter if the 180th day is a non-Business Day) following the end of such Subordination Period or (B)5:00 p.m., Kansas City, Missouri time, on the 180th calendar day (or the first Business Day thereafter if the 180th day is anon-Business Day) following the date the Participant's ceased to be a Service Provider.If the exercisable portion of the Option is not exercised within the above permitted periods of time, the entire Option shallexpire at 5:01 p.m., Kansas City, Missouri time, on the last day such portion of the Option is exercisable and, thereafter,the Option shall be void for all purposes.(e)Transferability. Except as otherwise determined by the Committee and as provided in Section 10.3, Options shall not be transferable bythe Option Holder except by will or pursuant to the laws of descent and distribution; each Option shall be exercisable (to theextent permitted under the Plan and terms of the applicable Award Agreement) during the Option Holder's lifetime only by him orher, or in the event of Disability or incapacity, by his or her guardian or legal representative; and Units issuable pursuant to anyOption shall be delivered only to or for the account of the Option Holder, or in the event of Disability or incapacity, his or herguardian or legal representative.(f)Exercise, Payments, etc. Each Option Award Agreement may set forth the acceptable method(s) under which the Option may beexercised and the permissible payment method(s) for exercising the Option granted therein. Unless otherwise provided in theAward Agreement, acceptable payment methods permitted under this Plan include, but are not limited to: (i) cash; (ii) cashier'scheck payable to the order of Inergy GP; (iii) a "cashless broker" exercise;6(iv) delivery of other securities or other property; (v) a recourse note from the Option Holder; or (vi) any combination (i) – (v),above, having a Fair Market Value on the exercise date equal to the relevant aggregate exercise price. The exercise of the Optionshall be deemed effective upon receipt of proper notice by Inergy GP and payment to Inergy GP.(g)Date of Grant. Unless otherwise specified in the Option Award Agreement, an Option shall be considered as having been granted on thedate specified in the grant resolution of the Committee.(h)Vesting Commencement Date. An Option Award Agreement may provide for a Vesting Commencement Date. An Option's VestingCommencement Date may be the same as or different from the Option's Date of Grant. Unless otherwise provided in the AwardAgreement, the Vesting Commencement Date is the Date of Grant.4.3Adjustment of Options. Subject to the limitations contained in this Section 4 and Section 12, the Committee may make any adjustment to anoutstanding Option it desires including, without limitation, (a) adjusting the Option Price or the number of Units subject to an outstandingOption and (b) subsequently granting a new Option or substituting an existing Option for a new Option. Such amendment, substitution,or re-grant may result in terms and conditions (including Option Price, number of Units covered, Restriction Period or Option Period)that differ from the terms and conditions of the original Option or previously granted Options. The Committee may not, however,adversely affect the rights of any Option Holder without the consent of such Option Holder.4.4Member Privileges. No Option Holder shall have any rights as a limited partner with respect to any Unit covered by an Option until the OptionHolder becomes the holder of record of such Unit, and no adjustments shall be made for distributions, dividends or other rights as towhich there is a record date preceding the date such Option Holder becomes the holder of record of such Unit, except as provided inSection 9.4.4.5Exercisability of Options Prior to End of Subordination Period for Senior Subordinated Units. To the extent that the SubordinationPeriod for the Senior Subordinated Units has not yet ended, outstanding Options may only be exercised in the event of a Change inControl and as provided below.(a)Awards Held By Current Service Providers. To the extent an Option is held by a Holder who is continuing to provide services to theEmployer as a Service Provider, the Committee may elect to let such person exercise that portion of the otherwise exercisableportion of an Option (ignoring any restriction imposed on exercise due to the Subordination Period for all of the SeniorSubordinated Units having not yet ended) which bears the same ratio to (A) the aggregate number of Units that have convertedfrom Senior Subordinated Units to Common Units over (B) the aggregate original number of Senior Subordinated Units on theEffective Date.[For illustrative purposes only, assume a Holder has an option to purchase 1,000 Units. The Holder is beyond the5th Anniversary of the Option's Date of Grant, and thus, but for not all of the Senior Subordinated Units havingconverted, the Holder would be entitled to exercise 100% of the Option. If 20% of all of the original SeniorSubordinated Units have converted to Common Units, the Committee may allow, in its sole discretion, the Holder toexercise up to 20% of the 1,000 Units subject to the Option. Thus, under this example, the Committee could permitthe Holder to purchase up to a maximum of 200 Units. ](b)Awards Held by Terminated Service Providers. To the extent an Option is held by a Holder who is no longer a Service Providerbecause the Service Provider (i) voluntarily resigned,7(ii) was terminated by the Employer without cause, (iii) became disabled, or (iv) retired, no portion of the Option may be exerciseduntil the Subordination Period for all Senior Subordinated Units has ended. It shall be the Holder's responsibility to monitor anddetermine when the Subordination Period for all Senior Subordinated Units has ended.SECTION 5 PHANTOM UNITS5.1Awards Granted by Committee. Coincident with or following designation for participation in the Plan, a Participant may be granted one or morePhantom Unit Awards consisting of Phantom Units. The number of Units subject to a Phantom Unit Award shall be determined by theCommittee.5.2Restrictions/Vesting. Phantom Units received by a Holder will be subject to a Restricted Period. The terms of such Restricted Period shall be setforth in a Phantom Unit Award Agreement along with the conditions pursuant to which the Phantom Units may become vested orforfeited. A Phantom Unit Award Agreement may provide for, without limitation, the accelerated vesting of Phantom Units upon theachievement of specified performance goals, whether DERs are granted with respect to such Phantom Units, and such other terms andconditions as the Committee may establish with respect to such Awards. A Holder's right to sell, encumber or otherwise transfer aPhantom Unit shall be subject to the limitations of Section 11 hereof. The Committee may in its sole discretion decide the methods ofenforcing the restrictions referred to in Section 5.2 and 5.3.5.3Termination of Service. Unless otherwise stated in the Phantom Unit Award Agreement and subject to Section 7, in the event a Participantceases to be a Service Provider for any reason, any Phantom Unit Award then held by the Holder and as to which the Restricted Periodhas not lapsed shall be forfeited as of the date the Participant ceases to be a Service Provider. The Committee may, in its discretion, waivein whole or in part such forfeiture with respect to a Participant’s Phantom UnitsSECTION 6 RESTRICTED UNITS6.1Grant of Restricted Units. Coincident with or following designation for participation in the Plan, a Participant may be granted one or moreRestricted Unit Awards consisting of Restricted Units. The number of Restricted Units granted to a Participant shall be determined by theCommittee.6.2Restrictions/Vesting. Restricted Units received by a Holder will be subject to a Restricted Period. The terms of such Restricted Period shall beset forth in a Restricted Unit Award Agreement and will set forth the conditions under which the Restricted Units may become vested orforfeited, which may include, without limitation, the accelerated vesting upon the achievement of specified performance goals, and suchother terms and conditions as the Committee may establish with respect to such Awards.6.3Termination of Service. Unless otherwise stated in a Restricted Unit Award Agreement and subject to Section 7, in the event a Participantceases to be a Service Provider for any reason, any Restricted Unit Award then held by the Holder and as to which the Restricted Periodhas not lapsed shall be forfeited as of the date the Participant ceases to be a Service Provider. The Committee may, in its discretion, waivein whole or in part such forfeiture with respect to a Participant’s Restricted Units.6.4DERs. Unless otherwise specifically provided for in an Award Agreement, all Restricted Units shall be granted along with DERs relating to suchRestricted Units. To the extent provided by the Committee, in its discretion, a grant of Restricted Units may provide that distributionsmade by the Company with respect to the Restricted Units shall be subject to the same forfeiture and other restrictions as the RestrictedUnit and, if restricted, such distributions shall be held, without interest,8until the Restricted Unit vests or is forfeited with the DERs being paid or forfeited at the same time, as the case may be. Absent such arestriction on the DERs in the Award Agreement, DERs shall be paid to the holder of the Restricted Unit without restriction.6.5Lapse of Restrictions. Upon or as soon as reasonably practical following the vesting of each Restricted Unit, the Participant shall be entitled tohave the restrictions removed from his or her Unit certificate so that the Participant then holds an unrestricted Unit.6.6Section 83(b) Election. To the extent a Participant desires to make a Code Section 83(b) election, the Participant must notify the Companywithin the period beginning on the Date of Grant of the Restricted Units and ending thirty (30) calendar days thereafter. If no suchnotification is made by the Participant within such thirty (30) day period, the Participant shall be precluded from making such a Section83(b) election.SECTION 7 REORGANIZATION, CHANGE IN CONTROL OR LIQUIDATION7.1In the event of a Change in Control, all Awards then outstanding shall become fully exercisable and payable in full, as the case may be, on such Change inControl or at such earlier time as the Committee may provide. In the event the Partnership, Inergy Partners, LLC or Inergy GP, LLC shall becomea party to any corporate or partnership merger, consolidation, split-up, spin-off, reorganization, change in the membership of the board ofdirectors (or its equivalent), or liquidation that does not constitute a Change in Control (a “Similar Event”), the Committee, in its sole discretion,may provide for the complete or partial acceleration of any time periods relating to the exercise or vesting of any outstanding Award so that suchAward may be exercised or paid in full, as the case may be, on or before the date such Award would otherwise have been exercisable or payable.In addition, in the event of a Change in Control or a Similar Event the Committee may, without the approval of any Person, including anyParticipant, in its sole discretion (A) cause any Award then outstanding to be assumed by the surviving entity in such transaction; (B) require themandatory surrender to Inergy GP by any Participant or beneficiary of some or all of the outstanding Awards held by such Person (irrespective ofwhether such Awards are then exercisable or payable under the provisions of the Plan) as of a date specified by the Committee, in which eventsuch Awards shall be cancelled and each Person paid an amount of cash per unit equal to the amount that could have been attained upon theexercise or vesting of such Award or realization of the holder’s rights had such Award been currently exercisable or payable; (C) require thesubstitution of a new Award for some or all of the outstanding Awards held by a holder (irrespective of whether such Awards are then exercisableor vested under the provisions of the Plan) provided that any replacement or substituted Award shall be equivalent in economic value to theholder, as determined by the Committee; (D) make such adjustments to any Award then outstanding as the Committee deems appropriate toreflect such Change in Control or Similar Event; and (E) require that any Award must be exercised in connection with or prior to the closing ofsuch Change in Control or Similar Event, and that if not so exercised such Award will expire. Any such determinations by the Committee may bemade generally with respect to all Participants, or may be made on a case-by-case basis with respect to particular Participant(s). However, noaction shall be taken by the Committee that would cause an Award to be subject to the additional 20% income tax provided by Code Section409A.SECTION 8 PLAN ADMINISTRATION8.1Authority of Committee. The Plan shall be administered by the Committee. Subject to the terms of the Plan and applicable law, and in addition toother express powers and authorizations conferred on the Committee by the Plan, the Committee shall have full power and authority to: (i)select the9Service Providers to whom Awards may from time to time be granted hereunder; (ii) determine the type or types of Awards to be granted toeligible Service Providers; (iii) determine the number of Units to be covered by, or with respect to which payments, rights, or other mattersare to be calculated in connection with, Awards; (iv) determine the terms and conditions of any Award; (v) determine whether, and to whatextent, and under what circumstances Awards may be settled or exercised in cash, Units, other Awards or other property, (vi) determinewhether, to what extent, under what circumstances, and the method(s) by which Awards may be exercised, settled, canceled, forfeited, orsuspended; (vii) determine whether, to what extent, and under what circumstances cash, Units, other Awards, other property, and otheramounts payable with respect to an Award shall be deferred either automatically or at the election of the holder thereof or of the Committee;(viii) determine whether, to what extent, and under what circumstances Awards may be transferred under circumstances other than bytransfer by will or by the laws of descent and distribution; (ix) correct any defect, supply an omission, reconcile any inconsistency andotherwise interpret and administer the Plan and any Award Agreement relating to the Plan or any Award hereunder; (x) modify and amend thePlan, establish, amend, suspend, or waive such rules, regulations and procedures of the Plan, and appoint such agents as it shall deemappropriate for the proper administration of the Plan; and (xi) make any other determination and take any other action that the Committeedeems necessary or desirable for the administration of the Plan. A majority of the members of the Committee may determine its actions andfix the time and place of its meetings.8.2Determination Under the Plan. Unless otherwise expressly provided in the Plan, all designations, determinations, interpretations, and otherdecisions under or with respect to the Plan or any Award shall be within the sole discretion of the Committee, may be made at any time andshall be final, conclusive, and binding upon all persons, including Holdings, Inergy GP, the Partnership, any Participant, any Holder, andany shareholder. No member of the Committee shall be liable for any action, determination or interpretation made in good faith, and allmembers of the Committee shall, in addition to their rights as directors, be fully protected by the Partnership with respect to any suchaction, determination or interpretation.SECTION 9 UNITS SUBJECT TO THE PLAN9.1Number of Units. Subject to adjustment as provided for in this Section 9, the maximum number of Units that may be issued under the Plan is5,000,000; provided, however, that the maximum number of Units that may be issued under the Plan shall increase automatically on thefirst business day of the Partnership’s fiscal year, commencing October 1, 2008, to equal 10% of the Partnership’s total common unitsoutstanding as of such date. The Committee shall have the right in its reasonable discretion to accelerate the date of the annual automaticincrease in the event of a merger, acquisition or other significant transaction involving the Partnership. In no event shall number of Unitsavailable for issuance under the Plan be reduced as a result of this provision.9.2Unused and Forfeited Units. Any Unit that is subject to an Award under this Plan that is not issued or is forfeited because the terms andconditions of the Award are not met, or because such Award is terminated or canceled, shall automatically become available for use withrespect to future Awards under the Plan.Sources of Units Deliverable Under Awards. Any Units delivered pursuant to an Award shall consist, in whole or in part, of Unitsacquired in the open market, from any Affiliate, the Partnership or other combination of the foregoing, as determined by the Committee in itsdiscretion.9.3Adjustments for Change in Capitalization. In the event that the Committee determines that any distribution (whether in the form of cash,Units, other securities, or other property), liquidation,10recapitalization, unit split, stock split, reverse split, reorganization, merger, consolidation, split-up, spin-off, combination, repurchase, orexchange of Units or other securities of the Partnership, issuance of warrants or other rights to purchase Units or other securities of thePartnership, or other similar transaction or event affects the Units such that an adjustment is determined by the Committee to be appropriate inorder to prevent dilution or enlargement of the benefits or potential benefits intended to be made available under the Plan, then the Committeeshall, in such manner as it may deem equitable, adjust any or all of (i) the number and type of Units (or other securities or property) withrespect to which Awards may be granted, (ii) the number and type of Units (or other securities or property) subject to outstanding Awards,and (iii) the grant or exercise price with respect to any Award or, if deemed appropriate, make provision for a cash payment to the Holder ofan outstanding Award; provided, that the number of Units subject to any Award shall always be a whole number. In the case of any suchsubstitution or adjustment affecting an Option, such substitution or adjustments shall be made in a manner that is in accordance with thesubstitution and assumption rules set forth in Treasury Regulations 1.424-1 and the applicable guidance relating to Code section 409A.9.4Unit Certificates. All certificates for Units or other securities of the Partnership delivered under the Plan pursuant to any Award or the exercisethereof shall be subject to such stop transfer orders and other restrictions as the Committee may deem advisable under the Plan or therules, regulations, and other requirements of the SEC, any stock exchange upon which such Units or other securities are then listed, andany applicable federal or state laws, and the Committee may cause a legend or legends to be put on any such certificates to makeappropriate reference to such restrictions.9.5Determination by Committee, etc. Adjustments under this Section 9 shall be made by the Committee, whose determinations with regard theretoshall be final and binding upon all persons.SECTION 10 RIGHTS OF EMPLOYEES; PARTICIPANTS10.1Employment. Nothing contained in the Plan or in any Award granted under the Plan shall confer upon any Participant any right with respect tothe continuation of his or her services as a Service Provider or interfere in any way with the right of his or her employer, subject to theterms of any separate employment or consulting agreement to the contrary, at any time to terminate such services or to increase ordecrease the compensation of the Participant from the rate in existence at the time of the grant of an Award. Whether an authorized leaveof absence, or absence in military or government service, shall constitute a termination of the Participant's services as a Service Providershall be determined by the Committee at the time.10.2Nontransferability. Except as provided in Section 10.3, no right of any Holder in an Award granted pursuant to the Plan shall be assignable ortransferable during the lifetime of the Holder either voluntarily or involuntarily, or be subjected to any lien, directly or indirectly, byoperation of law, or otherwise, including execution, levy, garnishment, attachment, pledge or bankruptcy. In the event of a Holder'sdeath, a Holder's rights in all Awards shall, to the extent permitted by the Committee and as provided for in accordance with this Plan, betransferable by testamentary will or the laws of descent and distribution, and payment of any amounts due under the Plan shall be madeto, and the exercise of any Options may be made by, the Holder's legal representatives, heirs or legatees. If, in the opinion of theCommittee, a person entitled to payments or to exercise rights with respect to the Plan is disabled from caring for his or her affairsbecause of a mental condition, physical condition or age, payment due such person may be made to, and such rights shall be exercisedby, such person's guardian, conservator, or other legal personal representative upon furnishing the Committee with evidence satisfactoryto the Committee of such disabled status.1110.3Permitted Transfers. Pursuant to conditions and procedures established by the Committee from time to time, the Committee may permit Awardsto be transferred to, exercised by and paid to certain persons or entities related to a Participant, including but not limited to members ofthe Participant's immediate family, charitable institutions, or trusts or other entities whose beneficiaries or beneficial owners aremembers of the Participant's immediate family and/or charitable institutions. In the case of initial Awards, at the request of theParticipant, the Committee may permit the naming of the related person or entity as the Option recipient. Any permitted transfer shall besubject to the condition that the Committee receive evidence satisfactory to it that the transfer is being made for estate and/or taxplanning purposes on a gratuitous or donative basis and without consideration (other than nominal consideration).SECTION 11 GENERAL RESTRICTIONS11.1Investment Representations. Inergy GP may require any person to whom an Option or other Award is granted, as a condition of exercisingsuch Option or receiving Units under the Award, to give written assurances in substance and form satisfactory to Inergy GP and itscounsel to the effect that such person is acquiring the Unit subject to the Option or the Award for his own account for investment andnot with any present intention of selling or otherwise distributing the same, and to such other effects as Inergy GP deems necessary orappropriate in order to comply with federal and applicable state securities laws. Legends evidencing such restrictions may be placed onthe certificates evidencing the Unit.11.2Compliance with Securities Laws. Each Award shall be subject to the requirement that, if at any time counsel to the Partnership shalldetermine that the listing, registration or qualification of the Units subject to such Award upon any securities exchange or under any stateor federal law, or the consent or approval of any governmental or regulatory body, is necessary as a condition of, or in connection with,the issuance or purchase of Units thereunder, such Award may not be accepted or exercised in whole or in part unless such listing,registration, qualification, consent or approval shall have been effected or obtained on conditions acceptable to the Committee. Nothingherein shall be deemed to require the Partnership to apply for or to obtain such listing, registration or qualification.11.3Unit Restriction Agreement. The Committee may provide that Units issuable upon the exercise of an Option or the vesting of a RestrictedUnit or Phantom Unit shall, under certain conditions, be subject to restrictions whereby Inergy GP has a right of first refusal withrespect to such Units or a right or obligation to repurchase all or a portion of such Units, which restrictions may survive a Participant'scessation or termination as a Service Provider.SECTION 12 PLAN AMENDMENT, MODIFICATION AND TERMINATION12.1The Committee may at any time terminate, and from time to time may amend or modify, the Plan; provided, however, that no amendment ormodification may become effective without approval of the amendment or modification by Inergy GP if Inergy GP's approval is required toenable the Plan to satisfy any applicable statutory or regulatory requirements, or if Inergy GP, on the advice of counsel, determines that InergyGP's approval is otherwise necessary or desirable. Prior to the end of the Subordination Period for all of the Senior Subordinated Units, noamendment to the Plan may be made without the approval of the Unit Majority (as defined in the Partnership Agreement) that would (i) allowOptions to become exercisable, (ii) allow Phantom Units or Restricted Units to vest, or (iii) permit DERs to be granted, earlier than otherwisepermitted under the terms of this Plan as of the Effective Date.12Solely with respects to Awards then outstanding under the Plan, no amendment, modification or termination of the Plan shall adverselyaffect, in a material way, Holders of such outstanding Awards, without the consent of the Holder holding such Awards.SECTION 13 WITHHOLDING13.1Withholding Requirement. Inergy GP's obligations to deliver Units upon the exercise of an Option, or upon the vesting of any other Award,shall be subject to the Holder's satisfaction of all applicable federal, state and local income, employment and other tax withholdingrequirements.SECTION 14 NONEXCLUSIVITY OF THE PLAN14.1The acceptance by Inergy GP of the sponsorship of the Plan shall not be construed as creating any limitations on the power or authority of Inergy GP toadopt such other or additional incentive or other compensation arrangements of whatever nature as Inergy GP may deem necessary or desirableor preclude or limit the continuation of any other plan, practice or arrangement for the payment of compensation or fringe benefits to employees,non-employee directors, or consultants generally, or to any class or group of employees, directors, or consultants, which Inergy GP now haslawfully put into effect, including, without limitation, any retirement, pension, savings and stock purchase plan, insurance, death anddisability benefits and executive short-term incentive plans.SECTION 15 REQUIREMENTS OF LAW15.1Requirements of Law. The issuance of Units and the payment of cash pursuant to the Plan shall be subject to all applicable laws, rules andregulations.15.2Rule 16b-3. Transactions under the Plan and to the extent even applicable within the scope of Rule 16b-3 are intended to comply with allapplicable conditions of Rule 16b-3. To the extent any provision of the Plan or any action by the Committee under the Plan fails to socomply, such provision or action shall, without further action by any person, be deemed to be automatically amended to the extentnecessary to effect compliance with Rule 16b-3; provided, however, that if such provision or action cannot be amended to effect suchcompliance, such provision or action shall be deemed null and void to the extent permitted by law and deemed advisable by theCommittee.15.3Code Section 409A. In the event that any provision of this Plan shall be determined to contravene Code section 409A, the regulationspromulgated thereunder, regulatory interpretations or announcements with respect to section 409A or applicable judicial decisionsconstruing section 409A, any such provision shall be void and have no effect. Moreover, this Plan shall be interpreted at all times insuch a manner that the terms and provisions of the Plan comply with Code section 409A, the regulations promulgated thereunder,regulatory interpretations or announcements with respect to section 409A and applicable judicial decisions construing section 409A.15.4Governing Law. The Plan and all agreements hereunder shall be construed in accordance with and governed by the laws of the State ofDelaware, without regard to conflict of laws principles.SECTION 16 DURATION OF THE PLAN16.1This Plan shall terminate on August 14, 2018. No Award shall be granted under the Plan after the Plan is terminated; provided, however, that any Awardtheretofore granted may be amended, altered, adjusted, suspended, discontinued, or terminated by the Committee and the Committee's authority13to waive any conditions or rights under any such Award shall extend beyond the Plan's termination date.14Exhibit 10.7APPENDIX ADEFINITIONSFor purposes of the Plan the following terms shall have the meanings set forth below.(a)"1934 Act" means the Securities Exchange Act of 1934, as amended. Reference to a specific section of the 1934 Act or regulationthereunder shall include such section or regulation, any valid regulation promulgated under such section, and any comparableprovision of any future legislation or regulation amending, supplementing, or superseding such section or regulation.(b)"Affiliate" means, with respect to any Person, any other Person that directly or indirectly through one or more intermediaries controls, iscontrolled by or is under common control with, the Person in question. As used herein, the term "control" means the possession,direct or indirect, of the power to direct or cause the direction of the management and policies of a Person, whether throughownership of voting securities, by contract or otherwise.(c)"Award" means an Option, Phantom Unit or Restricted Unit granted under the Plan, and shall include any tandem DERs granted withrespect to a Phantom Unit or Restricted Unit.(d)"Award Agreement" means a written agreement or instrument between the Partnership and a Holder evidencing an Award.(e)"Beneficiary" means the Person who has been designated by a Holder in his or her most recent written beneficiary designation filed withInergy GP or an Affiliate thereof to receive the benefits specified under this Plan upon the death of the Holder, or, if there is nodesignated Beneficiary or surviving designated Beneficiary, then the Person entitled by will or the laws of descent anddistribution to receive such benefits.(f)"Board" means the Board of Directors of Inergy GP.(g)"Business Day" means any day other than a Saturday, a Sunday or a day which is declared to be a Federal holiday by the United StatesGovernment.(h)"Cause" means (i) willful failure by the Participant to carry out the reasonable and lawful policies and directives of Holdings, Inergy GP,the Partnership or their Affiliates; (ii) willful engaging by the Participant in misconduct that causes material injury to, or damagesthe reputation of, Holdings, Inergy GP, the Partnership or one of their Affiliates, as determined in good faith by the Committee;(iii) any act of dishonesty of the Participant; (iv) commission by the Participant of a criminal offense, other than a minor trafficmisdemeanor; (v) any use by the Participant of an illegal controlled substance; or (vi) excessive absenteeism other than forillness, after receiving a warning in writing from Holdings, Inergy GP, the Partnership or one of their Affiliates to refrain fromsuch behavior.(i)"Change in Control" shall be deemed to have occurred upon the occurrence of one of the following events: (i) any sale, lease,exchange or other transfer (in one or a series of related transactions) of all or substantially all of the assets of the Non-ManagingGP or the Partnership to any Person or its Affiliates, other than Inergy GP, the Partnership or any of their Affiliates, or (ii) anymerger, reorganization, consolidation or other transaction pursuant to which more than 50% of the combined voting power of theequity interests in Inergy GP or the Non-Managing GP cease to be controlled by Holdings.APPENDIX A-1Exhibit 10.7(j)"Code" means the Internal Revenue Code of 1986, as it may be amended from time to time, and the rules and regulations promulgatedthereunder.(k)"Committee" means the Compensation Committee of the Board or such other committee of the Board appointed by the Board toadminister the Plan.(l)"Date of Grant" means, with respect to any Award, the date as of which such Award is granted under the Plan.(m)"DER" means a contingent right, granted in tandem with a specific Phantom Unit or Restricted Unit, to receive an amount in cash equalto the cash distributions made by the Partnership with respect to a Unit during the period such Phantom Unit or Restricted Unitis outstanding.(n)"Disability" or "Disabled" means disabled as defined in Section 22(e) of the Code, except that Disability or Disabled may, subject tothe discretion of the Committee, mean qualifying for and receiving payments under a disability pay plan of Holdings, Inergy GP,the Partnership or one of their Affiliates.(o)"Employer" means any of Holdings, Inergy GP, the Partnership or any one of such entity's Affiliates who is either (i) the common lawemployer of a Participant, or , (ii) the service recipient of any non-employee Service Provider.(p)"Effective Date" means June 1, 2001.(q)“Fair Market Value” means, as of any date, the value of a Unit determined in good faith, from time to time, by the Committee in its solediscretion and the Committee may adopt such formulas as in its opinion shall reflect the true fair market value of such stock from timeto time and may rely on such independent advice with respect to such fair market value as the Committee shall deem appropriate. In theevent that the Units are traded on a national securities exchange, the Committee may determine that the Fair Market Value of a Unit shallbe based upon the last sale before or the first sale after the Date of Grant, the closing price on the trading day before or the trading day ofthe Date of Grant, or any other reasonable basis using actual transactions in such Units as reported in The Wall Street Journal andconsistently applied. The determination of Fair Market Value also may be based upon an average selling price during a specifiedperiod that is within 30 days before or 30 days after the Date of Grant, provided that the commitment to grant the stock rightbased on such valuation method must be irrevocable before the beginning of the specified period, and such valuation methodmust be used consistently for grants of Awards under the same and substantially similar programs.(r)"General Partner" means Inergy GP, LLC, a Delaware limited liability company.(s)"Holder" means a Participant or a Beneficiary who is in possession of an Award Agreement representing an Award that has been grantedto such individual (or received by such individual in a transfer permitted by Committee and the Award Agreement) and has notexpired, been canceled or terminated.(t)"Holdings" means Inergy Holdings, LLC, a Delaware limited liability company.(u)"Non-Managing GP" means Inergy Partners, LLC, a Delaware limited liability company.(v)"Option" means a right to purchase a Unit at a stated price for a specified period of time.APPENDIX A-2Exhibit 10.7(w)"Option Period" means the maximum period of time from the Option Date of Grant that an Option as provided under the Option AwardAgreement may remain exercisable. Notwithstanding an Option's Option Period, an Option may cease to be exercisable andbecome null and void prior to the expiration of the Option Period as provided in accordance with the terms of this Plan and therespective Award Agreement.(x)"Option Price" means the price at which a Unit subject to an Option may be purchased, determined in accordance with Section 4.2(b).(y)"Participant" means a Service Provider designated by the Committee from time to time during the term of the Plan to receive one ormore Awards under the Plan.(z)"Partnership" means Inergy, L.P., a Delaware limited partnership, and any of its Affiliates.(aa)"Partnership Agreement" means the Amended and Restated Agreement of Limited Partnership of Inergy, L.P., as amended from timeto time.(bb)"Person" means an individual or a corporation, limited liability company, partnership, joint venture, trust, unincorporated organization,association, governmental agency or political subdivision thereof or other entity.(cc)"Phantom Unit" means a phantom (notional) Unit granted under the Plan which upon vesting entitles the Participant to receive a Unit oran amount of cash equal to the Fair Market Value of a Unit, whichever is determined by the Committee.(dd)"Plan" means the Inergy Long Term Incentive Plan, as set forth in this instrument and as hereafter amended or restated from time totime.(ee)"Plan Year" means each 12-month period beginning January 1 and ending the following December 31, except that for the first year ofthe Plan it shall begin on the Effective Date and extend to December 31 of that year.(ff)"Restricted Period" or "Restriction Period" means the period established by the Committee with respect to an Award during whichthe Award remains subject to forfeiture and is not exercisable by or payable to the Participant; provided, however, the RestrictedPeriod with respect to any Award may not terminate prior to the end of the Subordination Period for all of the SeniorSubordinated Units (as defined in the Partnership Agreement) except (i) at the same time and in the same proportion as suchSenior Subordinated Units are converted into Units, and (ii) upon a Change in Control.(gg)“Restricted Unit” means a Unit granted under the Plan that is subject to a Restricted Period.(hh)"Rule 16b-3" means Rule 16b-3 promulgated under the 1934 Act, and any future regulation amending, supplementing, or supersedingsuch regulation.(ii)"Section 16 Person" means a person who, with respect to a Unit, is subject to Section 16 of the 1934 Act.(jj)"Senior Subordinated Units" shall have the same meaning as defined in the Partnership Agreement.(kk)"Service Provider" means an employee (full or part-time), non-employee director or consultant of Holdings, Inergy GP, Partnership,or any of their Affiliates who renders service to or for the benefit of Inergy GP or the Partnership.(ll)"Subordinated Units" shall have the same meaning as defined in the Partnership Agreement.APPENDIX A-3Exhibit 10.7(mm)"Subordination Period" shall have the same meaning as defined in the Partnership Agreement(nn)"Unit" means a non-subordinated common Unit of the Partnership.APPENDIX A-4Exhibit 12.1CRESTWOOD EQUITY PARTNERS LPCOMPUTATION OF RATIO OF EARNINGS TO FIXED CHARGES(in millions, except for ratio) For the Years Ended December 31, 2013 2012 2011 2010 2009Earnings: Pre-tax income from continuing operations before adjustment for non-controlling interest and equity earnings (including amortization ofexcess cost of equity investment) per statements of income$(49.6) $25.6 $43.4 $29.8 $34.9Add: Fixed charges86.7 38.4 30.3 13.7 9.1 Amortized capitalized interest0.1 0.1 0.1 0.1 0.1Less: Capitalized interest(3.4) (0.2) (0.2) — (0.3)Non-controlling interest in pre-tax income of subsidiary with no fixedcharges(4.9)(3 ) — — — — Total earnings available for fixed charges$28.9 $63.9 $73.6 $43.6 $43.8 Fixed charges: Interest and debt expense81.3 36.0 27.8 13.5 8.8 Interest component of rent5.4 2.4 2.5 0.2 0.3 Total fixed charges$86.7 $38.4 $30.3 $13.7 $9.1 Ratio of earnings to fixed charges(1)—(2 ) 1.7 2.4 3.2 4.8(1)For purposes of computing the ratio of earnings to fixed charges, "earnings" consists of pretax income from continuing operations before adjustment for non-controlling interest andincome from equity investee plus fixed charges (excluding capitalized interest) and amortized capitalized interest. "Fixed charges" represents interest incurred (whether expensed orcapitalized), amortization of debt costs and that portion of rental expense on operating leases deemed to be the equivalent of interest.(2)Earnings for the year ended December 31, 2013 were inadequate to cover fixed charges.(3)Dividend requirement of preferred securities issued by our consolidated subsidiary was paid in units and therefore were not considered a fixed charge for purposes of thiscomputation.Exhibit 21.1LIST OF SUBSIDIARIES OF CRESTWOOD EQUITY PARNTERS LP AS OF FEBRUARY 14, 2014:NameJurisdictionArlington Storage Company, LLCDelawareArrow Field Services, LLCDelawareArrow Midstream Holdings, LLCDelawareArrow Pipeline, LLCDelawareArrow Water, LLCDelawareCentral New York Oil And Gas Company, L.L.C.New YorkCEQP Finance Corp.DelawareCowtown Gas Processing Partners L.P.TexasCowtown Pipeline Partners L.P.TexasCrestwood Appalachia Pipeline LLCTexasCrestwood Arkansas Pipeline LLCTexasCrestwood Canada CompanyNova ScotiaCrestwood Crude Logistics LLCDelawareCrestwood Crude Terminals LLCDelawareCrestwood Dakota Pipelines LLCDelawareCrestwood Gas Marketing LLCDelawareCrestwood Gas Services GP, LLCDelawareCrestwood Gas Services Operating GP LLCDelawareCrestwood Gas Services Operating LLCDelawareCrestwood Marcellus Midstream LLCDelawareCrestwood Marcellus Pipeline LLCDelawareCrestwood Midstream Finance Corp.DelawareCrestwood Midstream GP LLCDelawareCrestwood Midstream Holdings LPDelawareCrestwood Midstream Operations LLCDelawareCrestwood Midstream Partners LP (NYSE: CMLP)DelawareCrestwood New Mexico Pipeline LLCTexasCrestwood Niobrara LLCDelawareCrestwood Ohio Midstream Pipeline LLCDelawareCrestwood Operations LLCDelawareCrestwood Panhandle Pipeline LLCTexasCrestwood Partners LLCDelawareCrestwood Pipeline East LLCDelawareCrestwood Pipeline LLCTexasCrestwood Sabine Pipeline LLCTexasCrestwood Sales & Service IncDelawareCrestwood Services LLCDelawareCrestwood Storage Inc.DelawareCrestwood Transportation LLCDelawareCrestwood West Coast LLCDelawareExhibit 21.1E. Marcellus Asset Company, LLCDelawareFinger Lakes LPG Storage, LLCDelawareIPCH Acquisition Corp.DelawareJackalope Gas Gathering Services, L.L.C.DelawareL & L Transportation, LLCDelawareMGP GP, LLCDelawarePowder River Basin Industrial Complex, LLCDelawareSabine Treating LLCTexasStellar Propane Service, LLCDelawareTres Palacios Gas Storage LLCDelawareTres Palacios Midstream, LLCDelawareUS Salt, LLCDelawareExhibit 23.1Consent of Independent Registered Public Accounting FirmWe consent to the incorporation by reference in the following Registration Statements:(1)Registration Statement (Form S-8 No. 333-148619);(2)Registration Statement (Form S-8 No. 333-131767); and(3)Registration Statement (Form S-8 No. 333-83872);of our reports dated February 28, 2014, with respect to the consolidated financial statements and schedules as of and for the year ended December 31, 2013 ofCrestwood Equity Partners LP and the effectiveness of internal control over financial reporting of Crestwood Equity Partners LP, included in this AnnualReport (Form 10-K) of Crestwood Equity Partners LP for the year ended December 31, 2013./s/ ERNST & YOUNG LLPHouston, TexasFebruary 28, 2014Exhibit 23.2Consent of Independent Registered Public Accounting FirmWe consent to the incorporation by reference in Registration Statement Nos. 333-148619, 333-131767, and 333-83872 on Forms S-8 of Crestwood EquityPartners LP of our report dated July 23, 2013 (August 5, 2013 as to net income per limited partner unit) (February 28, 2014 as to retrospective adjustments forchange in segments in Note 17), relating to the consolidated financial statements of Crestwood Equity Partners LP (formerly known as Inergy, L.P. (formerlyknown as Crestwood Gas Services GP LLC)) and subsidiaries, (collectively the "Company") (which report expresses an unqualified opinion and includes anexplanatory paragraph relating to the acquisition of Crestwood Marcellus Midstream LLC which was accounted for at historical cost as a reorganization ofentities under common control as described in Note 11, an explanatory paragraph for the retrospective adjustments for earnings per unit relating to the commonand subordinated units issued in connection with the acquisition of Crestwood Gas Services GP, LLC as described in Note 8, an explanatory paragraph forretrospective adjustments for a change in segments as a result of the Crestwood Merger as described in Note 17, and an explanatory paragraph on theunaudited pro forma information for the acquisitions of Inergy Midstream, L.P. and Arrow Midstream Holdings LLC presented in Note 4), appearing in thisAnnual Report on Form 10-K of Crestwood Equity Partners LP for the year ended December 31, 2013. /s/ DELOITTE & TOUCHE LLPHouston, TexasFebruary 28, 2014Exhibit 31.1CERTIFICATIONSI, Robert G. Phillips, certify that:1.I have reviewed this annual report on Form 10-K of Crestwood Equity Partners LP (the “registrant”);2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make thestatements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by thisreport;3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects thefinancial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;4.The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined inExchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over the financial reporting (as defined in Exchange Act Rules 13a-15(f)) for theregistrant and have:a.Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under oursupervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us byothers within those entities, particularly during the period in which this report is being prepared;b.Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under oursupervision, to provide reasonable assurance regarding the reliability of financial reporting and preparation of financial statements forexternal purposes in accordance with generally accepted accounting principles;c.Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about theeffectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; andd.Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's mostrecent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likelyto materially affect, the registrant's internal control over financial reporting; and5.The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to theregistrant's auditors and the audit committee of registrant's board of directors (or persons performing the equivalent functions):a.All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which arereasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; andb.Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internalcontrol over financial reporting.Date: February 28, 2014 /s/ Robert G. PhillipsRobert G. PhillipsChairman, President and Chief Executive OfficerExhibit 31.2CERTIFICATIONSI, Michael J. Campbell, certify that:1.I have reviewed this annual report on Form 10-K of Crestwood Equity Partners LP (the “registrant”);2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make thestatements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by thisreport;3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects thefinancial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;4.The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined inExchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over the financial reporting (as defined in Exchange Act Rules 13a-15(f)) for theregistrant and have:a.Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under oursupervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us byothers within those entities, particularly during the period in which this report is being prepared;b.Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under oursupervision, to provide reasonable assurance regarding the reliability of financial reporting and preparation of financial statements forexternal purposes in accordance with generally accepted accounting principles;c.Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about theeffectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; andd.Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's mostrecent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likelyto materially affect, the registrant's internal control over financial reporting; and5.The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to theregistrant's auditors and the audit committee of registrant's board of directors (or persons performing the equivalent functions):a.All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which arereasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; andb.Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internalcontrol over financial reporting.Date: February 28, 2014/s/ Michael J. CampbellMichael J. CampbellSenior Vice President and Chief Financial OfficerExhibit 32.1Certification of the Chief Executive OfficerPursuant to 18 U.S.C. Section 1350As Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002In connection with the Annual Report of Crestwood Equity Partners LP (the “Company”) on Form 10-K for the period ended December 31, 2013, as filed withthe Securities and Exchange Commission on the date hereof (the “Report”), I, Robert G. Phillips, Chief Executive Officer of Crestwood Equity Partners LP,certify, pursuant to 18 U.S.C. § 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:(1)The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and(2)The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company. /s/ Robert G. PhillipsFebruary 28, 2014Robert G. Phillips Chief Executive OfficerA signed original of this written statement required by Section 906, or other document authenticating, acknowledging, or otherwise adopting thesignature that appears in typed form within the electronic version of this written statement required by Section 906, has been provided to the Companyand will be retained by the Company and furnished to the Securities and Exchange Commission or its staff upon request.Exhibit 32.2Certification of the Chief Financial OfficerPursuant to 18 U.S.C. Section 1350As Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002In connection with the Annual Report of Crestwood Equity Partners LP (the “Company”) on Form 10-K for the period ended December 31, 2013, as filed withthe Securities and Exchange Commission on the date hereof (the “Report”), I, Michael J. Campbell, Chief Financial Officer of Crestwood Equity Partners LP,certify, pursuant to 18 U.S.C. § 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:(1)The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and(2)The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company. /s/ Michael J. CampbellFebruary 28, 2014Michael J. CampbellChief Financial OfficerA signed original of this written statement required by Section 906, or other document authenticating, acknowledging, or otherwise adopting thesignature that appears in typed form within the electronic version of this written statement required by Section 906, has been provided to the Companyand will be retained by the Company and furnished to the Securities and Exchange Commission or its staff upon request.Left to right: Joel Lambert, Joel Moxley, Bill Gautreaux, Robert G. Phillips, Heath Deneke, Mike Campbell, Steven Dougherty, Will Moore CORPORATE LEADERSHIP Robert G. Phillips Chairman, President and Chief Executive Officer J. Heath Deneke President, Natural Gas Business Unit BOARD OF DIRECTORS Robert G. Phillips†* Chairman, President and Chief Executive Officer Alvin Bledsoe (1)†* Retired Partner, Pricewaterhouse-Coopers Director of SunCoke Energy, Inc. Michael G. France†* Managing Director, First Reserve Corporation Director of Cobalt International Energy, Inc. INVESTOR INFORMATION Exchange Information Our common units are traded on the NYSE under the symbols “CMLP” and “CEQP”. William C. Gautreaux President, Liquids & Crude Business Unit Steven M. Dougherty Senior Vice President & Chief Accounting Officer William H. Moore Senior Vice President, Strategy & Corporate Development Michael J. Campbell Senior Vice President & Chief Financial Officer Joel C. Lambert Senior Vice President & General Counsel and Corporate Secretary Joel D. Moxley Senior Vice President, Operations Services Philip D. Gettig (2)(4)† Retired General Counsel, Union Pacific Fuels, Inc. David Lumpkins (4)(5)† Executive Chairman of the Board of PetroLogistics GP LLC Warren H. Gfeller (6)†* Private investor Former President and Chief Executive Officer of Ferrellgas Partners, L.P. Arthur B. Krause (4)* Former Executive Vice President and Chief Financial Officer, Sprint Corporation Director of Westar Energy, Inc Randy E. Moeder (2)(4)* Chief Executive Officer and President of Moeder Oil & Gas, LLC John J. Sherman†* Former Chief Executive Officer and President of Inergy, L.P. and Inergy Midstream, L.P. John W. Somerhalder II (5)* Chairman, President and Chief Executive Officer AGL Resources Inc. David M. Wood (3)†* Former President and Chief Executive Officer and Former Director of Murphy Oil Corporation. (1) Chair of Audit Committee (2) Chair of Conflicts Committee (3) Chair of Compensation Committee (4) Member of Audit Committee (5) Member of Conflicts Committee (6) Member of Compensation Committee † Director of CMLP * Director of CEQP Additional Information For more information, please visit our website at www.crestwoodlp.com. Through our website, you may elect to receive news, SEC filings and other information. Transfer Agent For information regarding change of address or other matters concerning your units, please contact our transfer agent: American Stock Transfer & Trust Co. 6201 15th Avenue Brooklyn, NY 11219 P: (800) 937-5449 Info@AmStock.com Principal Executive Offices 700 Louisiana Street Suite 2060 Houston, TX 77002 P: (832) 519.2200 F: (832) 519.2250 CONNECTIONS FOR AMERICA’S ENERGY 700 Louisiana Street, Suite 2060 • Houston, TX 77002 • (832) 519.2200 • www.crestwoodlp.com 

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