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UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

 

Form 10-Q

 

x

QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

 

For the quarterly period ended June 30, 2014

 

or

 

o

TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

 

For the transition period from            to           

 

Commission File Number: 001-35172

 

NGL Energy Partners LP

(Exact Name of Registrant as Specified in Its Charter)

 

Delaware

 

27-3427920

(State or Other Jurisdiction of Incorporation or
Organization)

 

(I.R.S. Employer Identification No.)

 

 

 

6120 South Yale Avenue
Suite 805
Tulsa, Oklahoma

 

74136

(Address of Principal Executive Offices)

 

(Zip code)

 

(918) 481-1119

(Registrant’s Telephone Number, Including Area Code)

 

Indicate 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 during the 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 requirements for the past 90 days. Yes x  No o

 

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (Section 232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes x No o

 

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.

 

Large accelerated filer x

 

Accelerated filer o

 

 

 

Non-accelerated filer o

 

Smaller reporting company o

 

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes o  No x

 

At August 4, 2014, there were 83,565,394 common units and 5,919,346 subordinated units issued and outstanding.

 

 

 



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TABLE OF CONTENTS

 

PART I

Item 1.

Financial Statements (Unaudited)

 

3

 

 

 

 

 

Condensed Consolidated Balance Sheets at June 30, 2014 and March 31, 2014

 

3

 

Condensed Consolidated Statements of Operations for the three months ended June 30, 2014 and 2013

 

4

 

Condensed Consolidated Statements of Comprehensive Loss for the three months ended June 30, 2014 and 2013

 

5

 

Condensed Consolidated Statement of Changes in Equity for the three months ended June 30, 2014

 

6

 

Condensed Consolidated Statements of Cash Flows for the three months ended June 30, 2014 and 2013

 

7

 

Notes to Condensed Consolidated Financial Statements

 

8

 

 

 

 

Item 2.

Management’s Discussion and Analysis of Financial Condition and Results of Operations

 

42

Item 3.

Quantitative and Qualitative Disclosures About Market Risk

 

65

Item 4.

Controls and Procedures

 

66

 

 

 

 

PART II

 

 

 

 

Item 1.

Legal Proceedings

 

68

Item 1A.

Risk Factors

 

68

Item 2.

Unregistered Sales of Equity Securities and Use of Proceeds

 

68

Item 3.

Defaults Upon Senior Securities

 

68

Item 4.

Mine Safety Disclosures

 

68

Item 5.

Other Information

 

68

Item 6.

Exhibits

 

69

 

 

 

 

Signatures

 

 

70

 

 

 

 

Exhibit Index

 

71

 

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Forward-Looking Statements

 

This Quarterly Report on Form 10-Q (“Quarterly Report”) contains various forward-looking statements and information that are based on our beliefs and those of our general partner, as well as assumptions made by and information currently available to us. These forward-looking statements are identified as any statement that does not relate strictly to historical or current facts. When used in this Quarterly Report, words such as “anticipate,” “project,” “expect,” “plan,” “goal,” “forecast,” “estimate,” “intend,” “could,” “believe,” “may,” “will” and similar expressions and statements regarding our plans and objectives for future operations, are intended to identify forward-looking statements. Although we and our general partner believe that the expectations on which such forward-looking statements are based are reasonable, neither we nor our general partner can give assurances that such expectations will prove to be correct. Forward-looking statements are subject to a variety of risks, uncertainties and assumptions. If one or more of these risks or uncertainties materialize, or if underlying assumptions prove incorrect, our actual results may vary materially from those anticipated, estimated, projected or expected. Among the key risk factors that impact our consolidated financial position and results of operations are:

 

·                  the prices for crude oil, natural gas, natural gas liquids, refined products, ethanol, and biodiesel;

 

·                  energy prices generally;

 

·                  the price of propane relative to the price of alternative and competing fuels;

 

·                  the price of gasoline relative to the price of corn, which impacts the price of ethanol;

 

·                  the general level of crude oil, natural gas, and natural gas liquids production;

 

·                  the general level of demand for crude oil, natural gas liquids, refined products, ethanol, and biodiesel;

 

·                  the availability of supply of crude oil, natural gas liquids, refined products, ethanol, and biodiesel;

 

·                  the level of crude oil and natural gas drilling and production in producing basins in which we have water treatment facilities;

 

·                  the ability to obtain adequate supplies of propane and distillates for retail sale in the event of an interruption in supply or transportation and the availability of capacity to transport propane and distillates to market areas;

 

·                  actions taken by foreign oil and gas producing nations;

 

·                  the political and economic stability of petroleum producing nations;

 

·                  the effect of weather conditions on supply and demand for crude oil, natural gas liquids, refined products, ethanol, and biodiesel;

 

·                  the effect of natural disasters, lightning strikes, or other significant weather events;

 

·                  availability of local, intrastate and interstate transportation infrastructure, including with respect to our truck, railcar, and barge transportation services;

 

·                  availability, price, and marketing of competitive fuels;

 

·                  the impact of energy conservation efforts on product demand;

 

·                  energy efficiencies and technological trends;

 

·                  governmental regulation and taxation;

 

·                  the impact of legislative and regulatory actions on hydraulic fracturing and on the treatment of flowback and produced water;

 

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·                  hazards or operating risks incidental to the transporting and distributing of petroleum products that may not be fully covered by insurance;

 

·                  the maturity of the crude oil and natural gas liquids industries and competition from other marketers;

 

·                  the loss of key personnel;

 

·                  the ability to hire drivers;

 

·                  the ability to renew contracts with key customers;

 

·                  the ability to maintain or increase the margins we realize for our terminal, barging, trucking and water disposal, recycling and discharge services;

 

·                  the ability to renew leases for general purpose and high pressure railcars;

 

·                  the ability to renew leases for underground natural gas liquids storage;

 

·                  the nonpayment or nonperformance by our customers;

 

·                  the availability and cost of capital and our ability to access certain capital sources;

 

·                  a deterioration of the credit and capital markets;

 

·                  the ability to successfully identify and consummate strategic acquisitions at purchase prices that are accretive to our financial results;

 

·                  the ability to successfully integrate acquired assets and businesses;

 

·                  changes in the volume of crude oil recovered during the wastewater treatment process;

 

·                  changes in the financial condition and results of operations of entities in which we own noncontrolling equity interests;

 

·                  changes in laws and regulations to which we are subject, including tax, environmental, transportation and employment regulations or new interpretations by regulatory agencies concerning such laws and regulations and the impact of such laws and regulations (now existing or in the future) on our business operations, including our sales of crude oil, condensate, natural gas liquids, refined products, ethanol and biodiesel, our processing of wastewater, and transportation and risk management activities;

 

·                  the costs and effects of legal and administrative proceedings;

 

·                  the demand for refined products;

 

·                  any reduction or the elimination of the Renewable Fuels Standard;

 

·                  the operational and financial success of our joint ventures; and

 

·                  changes in the jurisdictional characteristics of, or the applicable regulatory policies with respect to, our joint venture’s pipeline assets.

 

You should not put undue reliance on any forward-looking statements. All forward-looking statements speak only as of the date of this Quarterly Report. Except as required by state and federal securities laws, we undertake no obligation to publicly update or revise any forward-looking statements as a result of new information, future events, or otherwise. When considering forward-looking statements, please review the risks described under “Item 1A — Risk Factors” in our Annual Report on Form 10-K for the fiscal year ended March 31, 2014.

 

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PART I

 

Item 1.                   Financial Statements (Unaudited)

 

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Unaudited Condensed Consolidated Balance Sheets

(U.S. Dollars in Thousands, except unit amounts)

 

 

 

June 30,

 

March 31,

 

 

 

2014

 

2014

 

ASSETS

 

 

 

 

 

CURRENT ASSETS:

 

 

 

 

 

Cash and cash equivalents

 

$

39,679

 

$

10,440

 

Accounts receivable - trade, net of allowance for doubtful accounts of $2,732 and $2,822, respectively

 

903,011

 

900,904

 

Accounts receivable - affiliates

 

1,110

 

7,445

 

Inventories

 

373,633

 

310,160

 

Prepaid expenses and other current assets

 

58,613

 

80,350

 

Total current assets

 

1,376,046

 

1,309,299

 

 

 

 

 

 

 

PROPERTY, PLANT AND EQUIPMENT, net of accumulated depreciation of $127,628 and $109,564, respectively

 

863,457

 

829,346

 

GOODWILL

 

1,101,471

 

1,107,006

 

INTANGIBLE ASSETS, net of accumulated amortization of $140,677 and $116,728, respectively

 

699,315

 

714,956

 

INVESTMENTS IN UNCONSOLIDATED ENTITIES

 

211,480

 

189,821

 

OTHER NONCURRENT ASSETS

 

13,733

 

16,795

 

Total assets

 

$

4,265,502

 

$

4,167,223

 

 

 

 

 

 

 

LIABILITIES AND EQUITY

 

 

 

 

 

CURRENT LIABILITIES:

 

 

 

 

 

Accounts payable - trade

 

$

810,149

 

$

740,211

 

Accounts payable - affiliates

 

37,706

 

76,846

 

Accrued expenses and other payables

 

123,939

 

141,690

 

Advance payments received from customers

 

56,373

 

29,965

 

Current maturities of long-term debt

 

6,168

 

7,080

 

Total current liabilities

 

1,034,335

 

995,792

 

 

 

 

 

 

 

LONG-TERM DEBT, net of current maturities

 

1,441,875

 

1,629,834

 

OTHER NONCURRENT LIABILITIES

 

8,000

 

9,744

 

 

 

 

 

 

 

COMMITMENTS AND CONTINGENCIES

 

 

 

 

 

 

 

 

 

 

 

EQUITY, per accompanying statement:

 

 

 

 

 

General partner, representing a 0.1% interest, 87,435 and 79,420 notional units at June 30, 2014 and March 31, 2014, respectively

 

(41,308

)

(45,287

)

Limited partners, representing a 99.9% interest -
Common units, 81,427,921 and 73,421,309 units issued and outstanding at June 30, 2014 and March 31, 2014, respectively

 

1,822,572

 

1,570,074

 

Subordinated units, 5,919,346 units issued and outstanding at June 30, 2014 and March 31, 2014

 

(5,248

)

2,028

 

Accumulated other comprehensive loss

 

(51

)

(236

)

Noncontrolling interests

 

5,327

 

5,274

 

Total equity

 

1,781,292

 

1,531,853

 

Total liabilities and equity

 

$

4,265,502

 

$

4,167,223

 

 

The accompanying notes are an integral part of these condensed consolidated financial statements.

 

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NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Unaudited Condensed Consolidated Statements of Operations

(U.S. Dollars in Thousands, except unit and per unit amounts)

 

 

 

Three Months Ended June 30,

 

 

 

2014

 

2013

 

REVENUES:

 

 

 

 

 

Crude oil logistics

 

$

1,929,283

 

$

930,794

 

Water solutions

 

47,314

 

20,513

 

Liquids

 

475,157

 

360,959

 

Retail propane

 

77,902

 

72,217

 

Refined products

 

986,223

 

 

Renewables

 

131,274

 

 

Other

 

1,461

 

1,474

 

Total Revenues

 

3,648,614

 

1,385,957

 

 

 

 

 

 

 

COST OF SALES:

 

 

 

 

 

Crude oil logistics

 

1,897,639

 

909,219

 

Water solutions

 

10,573

 

583

 

Liquids

 

462,016

 

350,251

 

Retail propane

 

47,524

 

43,023

 

Refined products

 

983,012

 

 

Renewables

 

131,301

 

 

Other

 

1,988

 

 

Total Cost of Sales

 

3,534,053

 

1,303,076

 

 

 

 

 

 

 

OPERATING COSTS AND EXPENSES:

 

 

 

 

 

Operating

 

67,868

 

49,045

 

General and administrative

 

27,873

 

18,454

 

Depreciation and amortization

 

39,375

 

22,724

 

Operating Loss

 

(20,555

)

(7,342

)

 

 

 

 

 

 

OTHER INCOME (EXPENSE):

 

 

 

 

 

Earnings of unconsolidated entities

 

2,565

 

 

Interest expense

 

(20,494

)

(10,622

)

Other, net

 

(391

)

50

 

Loss Before Income Taxes

 

(38,875

)

(17,914

)

 

 

 

 

 

 

INCOME TAX (PROVISION) BENEFIT

 

(1,035

)

406

 

 

 

 

 

 

 

Net Loss

 

(39,910

)

(17,508

)

 

 

 

 

 

 

NET INCOME ALLOCATED TO GENERAL PARTNER

 

(9,381

)

(1,688

)

 

 

 

 

 

 

NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS

 

(65

)

(125

)

 

 

 

 

 

 

NET LOSS ALLOCATED TO LIMITED PARTNERS

 

$

(49,356

)

$

(19,321

)

 

 

 

 

 

 

BASIC AND DILUTED LOSS PER COMMON UNIT

 

$

(0.61

)

$

(0.35

)

 

 

 

 

 

 

BASIC AND DILUTED LOSS PER SUBORDINATED UNIT

 

$

(0.68

)

$

(0.46

)

 

 

 

 

 

 

BASIC AND DILUTED WEIGHTED AVERAGE UNITS OUTSTANDING:

 

 

 

 

 

Common units

 

74,126,205

 

47,703,313

 

Subordinated units

 

5,919,346

 

5,919,346

 

 

The accompanying notes are an integral part of these condensed consolidated financial statements.

 

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NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Unaudited Condensed Consolidated Statements of Comprehensive Loss

(U.S. Dollars in Thousands)

 

 

 

Three Months Ended June 30,

 

 

 

2014

 

2013

 

 

 

 

 

 

 

Net loss

 

$

(39,910

)

$

(17,508

)

Other comprehensive income (loss)

 

185

 

(25

)

Comprehensive loss

 

$

(39,725

)

$

(17,533

)

 

The accompanying notes are an integral part of these condensed consolidated financial statements.

 

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NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Unaudited Condensed Consolidated Statement of Changes in Equity

(U.S. Dollars in Thousands, except unit amounts)

 

 

 

 

 

 

 

 

 

 

 

 

 

Accumulated

 

 

 

 

 

 

 

 

 

Limited Partners

 

Other

 

 

 

 

 

 

 

General

 

Common

 

 

 

Subordinated

 

 

 

Comprehensive

 

Noncontrolling

 

Total

 

 

 

Partner

 

Units

 

Amount

 

Units

 

Amount

 

Income (Loss)

 

Interests

 

Equity

 

BALANCES AT MARCH 31, 2014

 

$

(45,287

)

73,421,309

 

$

1,570,074

 

5,919,346

 

$

2,028

 

$

(236

)

$

5,274

 

$

1,531,853

 

Distributions

 

(5,754

)

 

(40,474

)

 

(3,263

)

 

(12

)

(49,503

)

Contributions

 

352

 

 

 

 

 

 

 

352

 

Sales of units, net of issuance costs

 

 

8,000,000

 

338,033

 

 

 

 

 

338,033

 

Equity issued pursuant to incentive compensation plan

 

 

6,612

 

282

 

 

 

 

 

282

 

Net income (loss)

 

9,381

 

 

(45,343

)

 

(4,013

)

 

65

 

(39,910

)

Other comprehensive income

 

 

 

 

 

 

185

 

 

185

 

BALANCES AT JUNE 30, 2014

 

$

(41,308

)

81,427,921

 

$

1,822,572

 

5,919,346

 

$

(5,248

)

$

(51

)

$

5,327

 

$

1,781,292

 

 

The accompanying notes are an integral part of these condensed consolidated financial statements.

 

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NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Unaudited Condensed Consolidated Statements of Cash Flows

(U.S. Dollars in Thousands)

 

 

 

Three Months Ended June 30,

 

 

 

2014

 

2013

 

OPERATING ACTIVITIES:

 

 

 

 

 

Net loss

 

$

(39,910

)

$

(17,508

)

Adjustments to reconcile net income to net cash provided by operating activities:

 

 

 

 

 

Depreciation and amortization, including debt issuance cost amortization

 

43,424

 

24,746

 

Non-cash equity-based compensation expense

 

7,769

 

7,075

 

Loss on disposal or impairment of assets

 

432

 

373

 

Provision for doubtful accounts

 

251

 

364

 

Commodity derivative loss

 

17,485

 

7,209

 

Earnings of unconsolidated entities

 

(2,565

)

 

Other

 

192

 

187

 

Changes in operating assets and liabilities, exclusive of acquisitions:

 

 

 

 

 

Accounts receivable - trade

 

(2,875

)

17,501

 

Accounts receivable - affiliates

 

6,335

 

8,404

 

Inventories

 

(63,536

)

(81,124

)

Prepaid expenses and other assets

 

(14,993

)

218

 

Accounts payable - trade

 

70,113

 

35,231

 

Accounts payable - affiliates

 

(39,140

)

3,604

 

Accrued expenses and other liabilities

 

(184

)

6,373

 

Advance payments received from customers

 

26,408

 

12,880

 

Net cash provided by operating activities

 

9,206

 

25,533

 

 

 

 

 

 

 

INVESTING ACTIVITIES:

 

 

 

 

 

Purchases of long-lived assets

 

(48,867

)

(30,192

)

Acquisitions of businesses, including acquired working capital, net of cash acquired

 

(15,869

)

(4,959

)

Cash flows from commodity derivatives

 

(9,967

)

(11,054

)

Proceeds from sales of assets

 

989

 

1,088

 

Investments in unconsolidated entities

 

(4,094

)

 

Net cash used in investing activities

 

(77,808

)

(45,117

)

 

 

 

 

 

 

FINANCING ACTIVITIES:

 

 

 

 

 

Proceeds from borrowings under revolving credit facility

 

494,500

 

255,000

 

Payments on revolving credit facility

 

(681,000

)

(212,000

)

Proceeds from borrowings on other long-term debt

 

 

880

 

Payments on other long-term debt

 

(2,347

)

(2,884

)

Debt issuance costs

 

(2,194

)

(2,211

)

Contributions

 

352

 

1,000

 

Distributions

 

(49,503

)

(27,159

)

Proceeds from sale of common units, net of offering costs

 

338,033

 

 

Net cash provided by financing activities

 

97,841

 

12,626

 

Net increase (decrease) in cash and cash equivalents

 

29,239

 

(6,958

)

Cash and cash equivalents, beginning of period

 

10,440

 

11,561

 

Cash and cash equivalents, end of period

 

$

39,679

 

$

4,603

 

 

The accompanying notes are an integral part of these condensed consolidated financial statements.

 

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NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements

At June 30, 2014 and March 31, 2014, and for the

Three Months Ended June 30, 2014 and 2013

 

Note 1 — Organization and Operations

 

NGL Energy Partners LP (“we,” “us,” “our,” or the “Partnership”) is a Delaware limited partnership. NGL Energy Holdings LLC serves as our general partner. At June 30, 2014, our operations include:

 

·                  Our crude oil logistics business, the assets of which include owned and leased crude oil storage terminals, pipeline injection stations, a fleet of trucks, a fleet of leased and owned railcars, and a fleet of barges and towboats, and a 50% interest in a crude oil pipeline. Our crude oil logistics business purchases crude oil from producers and transports it for resale at owned and leased pipeline injection points, storage terminals, barge loading facilities, rail facilities, refineries, and other trade hubs.

 

·                  Our water solutions business, the assets of which include water treatment and disposal facilities and a 27.5% interest in a water supply company. Our water solutions business generates revenues from the treatment and disposal of wastewater generated from crude oil and natural gas production operations, and from the sale of recycled water and recovered hydrocarbons.

 

·                  Our liquids business, which supplies natural gas liquids to retailers, wholesalers, refiners, and petrochemical plants throughout the United States and in Canada, and which provides natural gas liquids terminaling services through its 22 terminals throughout the United States and railcar transportation services through its fleet of leased and owned railcars. Our liquids business purchases propane, butane, and other products from refiners, processing plants, producers, and other parties, and sells the product to retailers, refiners, and other participants in the wholesale markets.

 

·                  Our retail propane business, which sells propane, distillates, and equipment and supplies to end users consisting of residential, agricultural, commercial, and industrial customers and to certain re-sellers in more than 20 states.

 

·                  Our refined products and renewables marketing business, which purchases gasoline and diesel fuel from suppliers and typically sells these products in back-to-back contracts to customers at a nationwide network of third-party owned terminaling and storage facilities, and which purchases ethanol primarily at production facilities and transports the ethanol to refiners and blenders at various locations. We also purchase biodiesel from production facilities located in the Midwest and Houston, Texas, and transport the biodiesel via railcars for sale to refiners and blenders. We also own an 11% interest in an ethanol production facility in Nebraska.

 

Note 2 — Significant Accounting Policies

 

Basis of Presentation

 

The unaudited condensed consolidated financial statements as of and for the three months ended June 30, 2014 and 2013 include our accounts and those of our controlled subsidiaries. All significant intercompany transactions and account balances have been eliminated in consolidation. The unaudited condensed consolidated balance sheet at March 31, 2014 is derived from audited financial statements. We have made certain reclassifications to prior period financial statements to conform to classification methods used in fiscal year 2015. These reclassifications had no impact on previously reported amounts of equity or net income.

 

The accompanying unaudited condensed consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States (“GAAP”) for interim consolidated financial information in accordance with the rules and regulations of the Securities and Exchange Commission. The unaudited condensed consolidated financial statements include all adjustments that we consider necessary for a fair presentation of our consolidated financial position and results of operations for the interim periods presented. Such adjustments consist of only normal recurring items, unless otherwise disclosed herein. Accordingly, the unaudited condensed consolidated financial statements do not include all the information and notes required by GAAP for complete annual consolidated financial statements. However, we believe that the disclosures made are adequate to make the information not misleading. These interim unaudited condensed consolidated financial statements should be read in conjunction with our audited consolidated financial statements for the fiscal year ended March 31, 2014 included in our Annual Report on Form 10-K (the “Annual Report”). Due to the seasonal nature of our natural gas liquids operations and other factors, the results of operations for interim periods are not necessarily indicative of the results to be expected for a full year.

 

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NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements - Continued

At June 30, 2014 and March 31, 2014, and for the

Three Months Ended June 30, 2014 and 2013

 

Use of Estimates

 

The preparation of consolidated financial statements in conformity with GAAP requires us to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the consolidated financial statements and the reported amount of revenues and expenses during the period. Actual results could differ from those estimates.

 

Significant Accounting Policies

 

Our significant accounting policies are consistent with those disclosed in Note 2 of our audited consolidated financial statements included in our Annual Report.

 

Revenue Recognition

 

We record revenues from product sales at the time title to the product transfers to the purchaser, which typically occurs upon receipt of the product by the purchaser. We record terminaling, storage, and service revenues at the time the service is performed, and we record tank and other rentals over the term of the lease. Revenues for our water solutions business are recognized upon receipt of the wastewater at our disposal facilities.

 

We report taxes collected from customers and remitted to taxing authorities, such as sales and use taxes, on a net basis. Amounts billed to customers for shipping and handling costs are included in revenues in our consolidated statements of operations.

 

We enter into certain contracts whereby we agree to purchase product from a counterparty and sell the same volume of product to the same counterparty at a different location or time. When such agreements are entered into concurrently and are entered into in contemplation of each other, we record the revenues for these transactions net of cost of sales.

 

Fair Value Measurements

 

We apply fair value measurements to certain assets and liabilities, principally our commodity derivative instruments and assets and liabilities acquired in business combinations. Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability (an exit price) in an orderly transaction between market participants at the measurement date. Fair value is based upon assumptions that market participants would use when pricing an asset or liability, including assumptions about risk and risks inherent in valuation techniques and inputs to valuations. This includes not only the credit standing of counterparties and credit enhancements but also the impact of our own nonperformance risk on our liabilities. Fair value measurements assume that the transaction occurs in the principal market for the asset or liability or, in the absence of a principal market, the most advantageous market for the asset or liability (the market for which the reporting entity would be able to maximize the amount received or minimize the amount paid). We evaluate the need for credit adjustments to our derivative instrument fair values in accordance with the requirements noted above. Such adjustments were not material to the fair values of our derivative instruments.

 

We use the following fair value hierarchy, which prioritizes the inputs to valuation techniques used to measure fair value into three broad levels:

 

·                  Level 1 — Quoted prices (unadjusted) in active markets for identical assets and liabilities that we have the ability to access at the measurement date.

 

·                  Level 2 — Inputs other than quoted prices included within Level 1 that are either directly or indirectly observable for the asset or liability, including quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in inactive markets, inputs other than quoted prices that are observable for the asset or liability, and inputs that are derived from observable market data by correlation or other means. Instruments categorized in Level 2 include non-exchange traded derivatives such as over-the-counter commodity price swap and option contracts and interest rate protection agreements. The majority of our fair value measurements related to our derivative financial instruments were categorized as Level 2 at June 30, 2014 and March 31, 2014 (see Note 11). We determine the fair value of all our derivative financial instruments utilizing pricing models for significantly similar instruments. Inputs to the pricing model include publicly available prices and forward curves generated from a compilation of data gathered from third parties.

 

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Table of Contents

 

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements - Continued

At June 30, 2014 and March 31, 2014, and for the

Three Months Ended June 30, 2014 and 2013

 

·                  Level 3 — Unobservable inputs for the asset or liability including situations where there is little, if any, market activity for the asset or liability. We did not have any fair value measurements categorized as Level 3 at June 30, 2014 or March 31, 2014.

 

The fair value hierarchy gives the highest priority to quoted prices in active markets (Level 1) and the lowest priority to unobservable data (Level 3). In some cases, the inputs used to measure fair value might fall into different levels of the fair value hierarchy. The lowest level input that is significant to a fair value measurement determines the applicable level in the fair value hierarchy. Assessing the significance of a particular input to the fair value measurement requires judgment, considering factors specific to the asset or liability.

 

Supplemental Cash Flow Information

 

Supplemental cash flow information is as follows:

 

 

 

Three Months Ended June 30,

 

 

 

2014

 

2013

 

 

 

(in thousands)

 

Interest paid, exclusive of debt issuance costs and letter of credit fees

 

$

25,984

 

$

8,485

 

Income taxes paid

 

$

1,005

 

$

281

 

 

Cash flows from settlements of commodity derivative instruments are classified as cash flows from investing activities in the consolidated statements of cash flows, and adjustments to the fair value of commodity derivative instruments are included in the reconciliation of net loss to net cash provided by operating activities.

 

Inventories

 

We value our inventory at the lower of cost or market, with cost determined using either the weighted average cost or the first in, first out (FIFO) methods, including the cost of transportation and storage. In performing this analysis, we take into consideration fixed-price forward sale commitments and the opportunity to transfer propane inventory from our wholesale business to our retail business for sale in the retail markets.

 

Inventories consist of the following:

 

 

 

June 30,
2014

 

March 31,
2014

 

 

 

(in thousands)

 

Crude oil

 

$

139,465

 

$

156,473

 

Natural gas liquids —

 

 

 

 

 

Propane

 

137,115

 

85,159

 

Butane and other

 

47,531

 

19,051

 

Refined products

 

17,518

 

23,209

 

Renewables

 

17,413

 

11,778

 

Other

 

14,591

 

14,490

 

 

 

$

373,633

 

$

310,160

 

 

Investments in Unconsolidated Entities

 

In December 2013, as part of our acquisition of Gavilon, LLC (“Gavilon Energy”), we acquired a 50% interest in Glass Mountain Pipeline, LLC (“Glass Mountain”), and an 11% interest in a limited liability company that owns an ethanol production facility. In June 2014, we acquired a 27.5% interest in a limited liability company that owns water solutions properties. We account for these investments under the equity method of accounting. Under the equity method, we do not report the individual assets and liabilities of these entities on our condensed consolidated balance sheets; instead, our ownership interests are reported within investments in unconsolidated entities on our condensed consolidated balance sheets. We record our share of any income or loss generated by these entities as an increase or decrease to our equity method investments, and record any distributions we receive from these entities as reductions to our equity method investments.

 

10



Table of Contents

 

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements - Continued

At June 30, 2014 and March 31, 2014, and for the

Three Months Ended June 30, 2014 and 2013

 

Accrued Expenses and Other Payables

 

Accrued expenses and other payables consist of the following:

 

 

 

June 30,

 

March 31,

 

 

 

2014

 

2014

 

 

 

(in thousands)

 

Accrued compensation and benefits

 

$

57,660

 

$

45,006

 

Derivative liabilities

 

14,371

 

42,214

 

Product exchange liabilities

 

12,230

 

3,719

 

Accrued interest

 

9,997

 

18,668

 

Income and other tax liabilities

 

9,298

 

13,421

 

Other

 

20,383

 

18,662

 

 

 

$

123,939

 

$

141,690

 

 

Business Combination Measurement Period

 

We record the assets acquired and liabilities assumed in a business combination at their acquisition-date fair values. Pursuant to GAAP, an entity is allowed a reasonable period of time (not to exceed one year) to obtain the information necessary to identify and measure the fair value of the assets acquired and liabilities assumed in a business combination. As described in Note 4, certain of our acquisitions are still within this measurement period, and as a result, the acquisition-date fair values we have recorded for the assets acquired and liabilities assumed are subject to change. Also as described in Note 4, we made certain adjustments during the three months ended June 30, 2014 to our estimates of the acquisition date fair values of assets acquired and liabilities assumed in business combinations that occurred during the year ended March 31, 2014.

 

Note 3 — Earnings Per Unit

 

Our earnings per common and subordinated unit were computed as follows:

 

 

 

Three Months Ended June 30,

 

 

 

2014

 

2013

 

 

 

(in thousands, except unit and per unit amounts)

 

Net loss attributable to parent equity

 

$

(39,975

)

$

(17,633

)

Net income allocated to general partner (1)

 

(9,381

)

(1,688

)

Net loss allocated to limited partners

 

$

(49,356

)

$

(19,321

)

 

 

 

 

 

 

Net loss allocated to:

 

 

 

 

 

Common unitholders

 

$

(45,343

)

$

(16,609

)

Subordinated unitholders

 

$

(4,013

)

$

(2,712

)

 

 

 

 

 

 

Weighted average common units outstanding

 

74,126,205

 

47,703,313

 

Weighted average subordinated units outstanding

 

5,919,346

 

5,919,346

 

 

 

 

 

 

 

Loss per common unit - basic and diluted

 

$

(0.61

)

$

(0.35

)

Loss per subordinated unit - basic and diluted

 

$

(0.68

)

$

(0.46

)

 


(1)         The net income allocated to the general partner includes distributions to which it is entitled as the holder of incentive distribution rights, which are described in Note 10.

 

The restricted units described in Note 10 were antidilutive for the three months ended June 30, 2014 and 2013, but could impact earnings per unit in future periods.

 

11



Table of Contents

 

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements - Continued

At June 30, 2014 and March 31, 2014, and for the

Three Months Ended June 30, 2014 and 2013

 

Note 4 — Acquisitions

 

Three Months Ended June 30, 2014

 

On June 9, 2014, we paid cash of $15.0 million in exchange for a 27.5% interest in a water supply company operating in Colorado. We account for this investment using the equity method of accounting.

 

Year Ended March 31, 2014

 

As described in Note 2, pursuant to GAAP, an entity is allowed a reasonable period of time to obtain the information necessary to identify and measure the fair value of the assets acquired and liabilities assumed in a business combination. The business combinations for which this measurement period was still open as of March 31, 2014 are summarized below.

 

Gavilon Energy

 

On December 2, 2013, we completed a business combination in which we acquired Gavilon Energy. We paid $832.4 million of cash, net of cash acquired, in exchange for these assets and operations. The acquisition agreement also contemplates a post-closing adjustment to the purchase price for certain working capital items.

 

The assets of Gavilon Energy include crude oil terminals in Oklahoma, Texas, and Louisiana, a 50% interest in Glass Mountain, which owns a crude oil pipeline that originates in western Oklahoma and terminates in Cushing, Oklahoma, and an 11% interest in an ethanol production facility in Nebraska. The operations of Gavilon Energy include the marketing of crude oil, refined products, ethanol, biodiesel, and natural gas liquids and owned and leased crude oil storage in Cushing, Oklahoma.

 

We are in the process of identifying and determining the fair value of the assets acquired and liabilities assumed in this business combination. The estimates of fair value reflected at June 30, 2014 are subject to change, and such changes could be material. We expect to complete this process prior to finalizing our financial statements for the quarter ending September 30, 2014. We have preliminarily estimated the fair values of the assets acquired (and useful lives) and liabilities assumed as follows (in thousands):

 

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Table of Contents

 

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements - Continued

At June 30, 2014 and March 31, 2014, and for the

Three Months Ended June 30, 2014 and 2013

 

 

 

Estimated At

 

 

 

 

 

June 30,

 

March 31,

 

 

 

 

 

2014

 

2014

 

Change

 

Accounts receivable - trade

 

$

349,529

 

$

349,529

 

$

 

Accounts receivable - affiliates

 

2,564

 

2,564

 

 

Inventories

 

107,430

 

107,430

 

 

Prepaid expenses and other current assets

 

68,322

 

68,322

 

 

Property, plant and equipment:

 

 

 

 

 

 

 

Vehicles (3 years)

 

791

 

791

 

 

Crude oil tanks and related equipment (3–40 years)

 

83,429

 

77,429

 

6,000

 

Information technology equipment (3–7 years)

 

4,046

 

4,046

 

 

Buildings and leasehold improvements (3–40 years)

 

7,716

 

7,716

 

 

Land

 

6,427

 

6,427

 

 

Linefill and tank bottoms

 

15,230

 

15,230

 

 

Other (7 years)

 

170

 

170

 

 

Construction in progress

 

7,190

 

7,190

 

 

Goodwill

 

358,847

 

359,169

 

(322

)

Intangible assets:

 

 

 

 

 

 

 

Customer relationships (10–20 years)

 

101,600

 

101,600

 

 

Lease agreements (1–5 years)

 

8,700

 

8,700

 

 

Investments in unconsolidated entities

 

178,000

 

178,000

 

 

Other noncurrent assets

 

3,918

 

9,918

 

(6,000

)

Accounts payable - trade

 

(342,792

)

(342,792

)

 

Accounts payable - affiliates

 

(2,585

)

(2,585

)

 

Accrued expenses and other payables

 

(70,677

)

(70,999

)

322

 

Advance payments received from customers

 

(10,667

)

(10,667

)

 

Other noncurrent liabilities

 

(44,740

)

(44,740

)

 

Fair value of net assets acquired

 

$

832,448

 

$

832,448

 

$

 

 

Goodwill represents the excess of the consideration paid for the acquired business over the fair value of the individual assets acquired, net of liabilities assumed. Goodwill primarily represents the value of synergies between the acquired entity and the Partnership, the opportunity to use the acquired business as a platform for growth, and the acquired assembled workforce. We estimate that all of the goodwill will be deductible for federal income tax purposes.

 

Our preliminary estimate of the fair value of investments in unconsolidated entities exceeds our share of the historical net book value of these subsidiaries’ net assets by approximately $70 million. This difference relates primarily to goodwill and customer relationships.

 

The acquisition method of accounting requires that executory contracts that are at unfavorable terms relative to current market conditions at the acquisition date be recorded as assets or liabilities in the acquisition accounting. Since certain crude oil storage lease commitments were at unfavorable terms relative to current market conditions, we recorded a liability of $12.9 million related to these lease commitments in the acquisition accounting, and we amortized $1.9 million of this balance through cost of sales during the three months ended June 30, 2014. We will amortize the remainder of this liability over the term of the leases. The future amortization of this liability is shown below (in thousands):

 

Year Ending March 31,

 

 

 

2015 (nine months)

 

$

4,641

 

2016

 

3,260

 

2017

 

300

 

 

Certain personnel who were employees of Gavilon Energy are entitled to a bonus, half of which was payable upon successful completion of the business combination and the remainder of which is payable in December 2014. We are recording this as compensation expense over the vesting period. We recorded expense of $2.7 million during the three months ended

 

13



Table of Contents

 

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements - Continued

At June 30, 2014 and March 31, 2014, and for the

Three Months Ended June 30, 2014 and 2013

 

June 30, 2014 related to these bonuses, and we expect to record an additional expense of $3.9 million during the remainder of the year ending March 31, 2015.

 

Oilfield Water Lines, LP

 

On August 2, 2013, we completed a business combination with entities affiliated with Oilfield Water Lines LP (collectively, “OWL”), whereby we acquired water disposal and transportation assets in Texas. We issued 2,463,287 common units, valued at $68.6 million, and paid $167.7 million of cash, net of cash acquired, in exchange for OWL. During the three months ended June 30, 2014, we completed the acquisition accounting for this business combination. The following table presents the final calculation of the fair values of the assets acquired (and useful lives) and liabilities assumed in the acquisition of OWL:

 

 

 

 

 

Estimated

 

 

 

 

 

 

 

at

 

 

 

 

 

 

 

March 31,

 

 

 

 

 

Final

 

2014

 

Change

 

 

 

(in thousands)

 

Accounts receivable - trade

 

$

6,837

 

$

7,268

 

$

(431

)

Inventories

 

154

 

154

 

 

Prepaid expenses and other current assets

 

402

 

402

 

 

Property, plant and equipment:

 

 

 

 

 

 

 

Vehicles (5–10 years)

 

8,143

 

8,157

 

(14

)

Water treatment facilities and equipment (3–30 years)

 

23,173

 

23,173

 

 

Buildings and leasehold improvements (7–30 years)

 

2,198

 

2,198

 

 

Land

 

710

 

710

 

 

Other (3–5 years)

 

53

 

53

 

 

Intangible assets:

 

 

 

 

 

 

 

Customer relationships (8–10 years)

 

110,000

 

110,000

 

 

Non-compete agreements (3 years)

 

2,000

 

2,000

 

 

Goodwill

 

90,144

 

89,699

 

445

 

Accounts payable - trade

 

(6,469

)

(6,469

)

 

Accrued expenses and other payables

 

(992

)

(992

)

 

Other noncurrent liabilities

 

(64

)

(64

)

 

Fair value of net assets acquired

 

$

236,289

 

$

236,289

 

$

 

 

Other Water Solutions Acquisitions

 

During the year ended March 31, 2014, we completed two separate acquisitions of businesses to expand our water solutions operations in Texas. On a combined basis, we issued 222,381 common units, valued at $6.8 million, and paid $158.4 million of cash, net of cash acquired, in exchange for the assets and operations of these businesses. During the three months ended June 30, 2014, we completed the acquisition accounting for these business combinations. The following table presents the final calculation of the fair values of the assets acquired (and useful lives) and liabilities assumed for these acquisitions:

 

14



Table of Contents

 

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements - Continued

At June 30, 2014 and March 31, 2014, and for the

Three Months Ended June 30, 2014 and 2013

 

 

 

 

 

Estimated

 

 

 

 

 

 

 

at

 

 

 

 

 

 

 

March 31,

 

 

 

 

 

Final

 

2014

 

Change

 

 

 

(in thousands)

 

Accounts receivable - trade

 

$

2,146

 

$

2,146

 

$

 

Inventories

 

192

 

192

 

 

Prepaid expenses and other current assets

 

62

 

61

 

1

 

Property, plant and equipment:

 

 

 

 

 

 

 

Vehicles (5–10 years)

 

76

 

90

 

(14

)

Water treatment facilities and equipment (3–30 years)

 

11,717

 

14,394

 

(2,677

)

Buildings and leasehold improvements (7–30 years)

 

3,278

 

1,906

 

1,372

 

Land

 

207

 

206

 

1

 

Other (3–5 years)

 

12

 

12

 

 

Intangible assets:

 

 

 

 

 

 

 

Customer relationships (8–10 years)

 

72,000

 

72,000

 

 

Trade names (indefinite life)

 

3,325

 

3,325

 

 

Non-compete agreements (3 years)

 

260

 

260

 

 

Water facility development agreement (5 years)

 

14,000

 

14,000

 

 

Water facility option agreement

 

2,500

 

2,500

 

 

Goodwill

 

49,067

 

47,750

 

1,317

 

Accounts payable - trade

 

(119

)

(119

)

 

Accrued expenses and other payables

 

(293

)

(293

)

 

Other noncurrent liabilities

 

(64

)

(64

)

 

Fair value of net assets acquired

 

$

158,366

 

$

158,366

 

$

 

 

As part of one of these business combinations, we entered into an option agreement with the seller of the business whereby we had the option to purchase a saltwater disposal facility that was under construction. We recorded an intangible asset of $2.5 million at the acquisition date related to this option agreement. On March 1, 2014, we purchased the saltwater disposal facility for additional cash consideration of $3.7 million.

 

In addition, as part of one of these business combinations, we entered into a development agreement that provides us a first right of refusal to purchase disposal facilities that may be developed by the seller through June 2018. On March 1, 2014, we purchased our first disposal facility pursuant to the development agreement for $21.0 million.

 

We have preliminarily estimated the fair values of the assets acquired (and useful lives) and liabilities assumed as follows (in thousands):

 

15



Table of Contents

 

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements - Continued

At June 30, 2014 and March 31, 2014, and for the

Three Months Ended June 30, 2014 and 2013

 

 

 

Estimated At

 

 

 

 

 

June 30,

 

March 31,

 

 

 

 

 

2014

 

2014

 

Change

 

Accounts receivable - trade

 

$

124

 

$

245

 

$

(121

)

Inventories

 

119

 

197

 

(78

)

Property, plant and equipment:

 

 

 

 

 

 

 

Water treatment facilities and equipment (3–30 years)

 

10,539

 

10,540

 

(1

)

Buildings and leasehold improvements (7–30 years)

 

1,130

 

1,130

 

 

Land

 

213

 

213

 

 

Other (3–5 years)

 

1

 

1

 

 

Goodwill

 

15,443

 

15,281

 

162

 

Accounts payable - trade

 

(232

)

(263

)

31

 

Accrued expenses and other payables

 

 

(7

)

7

 

Other noncurrent liabilities

 

(50

)

(50

)

 

Fair value of net assets acquired

 

$

27,287

 

$

27,287

 

$

 

 

Crude Oil Logistics Acquisitions

 

During the year ended March 31, 2014, we completed two separate acquisitions of businesses to expand our crude oil logistics operations in Texas and Oklahoma. On a combined basis, we issued 175,211 common units, valued at $5.3 million, and paid $67.8 million of cash, net of cash acquired, in exchange for the assets and operations of these businesses. During the three months ended June 30, 2014, we completed the acquisition accounting for these business combinations. The following table presents the final calculation of the fair values of the assets acquired (and useful lives) and liabilities assumed for these acquisitions:

 

 

 

 

 

Estimated

 

 

 

 

 

 

 

at

 

 

 

 

 

 

 

March 31,

 

 

 

 

 

Final

 

2014

 

Change

 

 

 

(in thousands)

 

Accounts receivable - trade

 

$

1,221

 

$

1,235

 

$

(14

)

Inventories

 

1,021

 

1,021

 

 

Prepaid expenses and other current assets

 

58

 

54

 

4

 

Property, plant and equipment:

 

 

 

 

 

 

 

Vehicles (5–10 years)

 

2,980

 

2,977

 

3

 

Buildings and leasehold improvements (5–30 years)

 

58

 

280

 

(222

)

Crude oil tanks and related equipment (2–30 years)

 

3,822

 

3,462

 

360

 

Barges and towboats (20 years)

 

20,065

 

20,065

 

 

Other (3–5 years)

 

57

 

53

 

4

 

Intangible assets:

 

 

 

 

 

 

 

Customer relationships (3 years)

 

13,300

 

6,300

 

7,000

 

Non-compete agreements (3 years)

 

35

 

35

 

 

Trade names (indefinite life)

 

530

 

530

 

 

Goodwill

 

30,730

 

37,867

 

(7,137

)

Accounts payable - trade

 

(521

)

(665

)

144

 

Accrued expenses and other payables

 

(266

)

(124

)

(142

)

Fair value of net assets acquired

 

$

73,090

 

$

73,090

 

$

 

 

Retail Propane and Liquids Acquisitions

 

During the year ended March 31, 2014, we completed four acquisitions of retail propane businesses and the acquisition of four natural gas liquids terminals. On a combined basis, we paid $21.9 million of cash to acquire these assets and operations. The agreements for certain of these acquisitions contemplate post-closing payments for certain working capital items. We are in the process of identifying and determining the fair value of the assets acquired and liabilities assumed in certain of these business combinations, and as a result, the estimates of fair value reflected at June 30, 2014 are subject to change.

 

16



Table of Contents

 

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements - Continued

At June 30, 2014 and March 31, 2014, and for the

Three Months Ended June 30, 2014 and 2013

 

Note 5 — Property, Plant and Equipment

 

Our property, plant and equipment consists of the following:

 

 

 

June 30,

 

March 31,

 

Description and Estimated Useful Lives

 

2014

 

2014

 

 

 

(in thousands)

 

Natural gas liquids terminal assets (2–30 years)

 

$

126,902

 

$

75,141

 

Retail propane equipment (2–30 years)

 

162,486

 

160,758

 

Vehicles and railcars (3–25 years)

 

178,320

 

152,676

 

Water treatment facilities and equipment (3–30 years)

 

179,952

 

180,985

 

Crude oil tanks and related equipment (2–40 years)

 

111,890

 

106,125

 

Barges and towboats (5–40 years)

 

52,071

 

52,217

 

Information technology equipment (3–7 years)

 

21,615

 

20,768

 

Buildings and leasehold improvements (3–40 years)

 

63,774

 

60,004

 

Land

 

30,629

 

30,241

 

Tank bottoms

 

16,807

 

13,403

 

Other (5–30 years)

 

6,782

 

6,341

 

Construction in progress

 

39,857

 

80,251

 

 

 

991,085

 

938,910

 

Less: Accumulated depreciation

 

(127,628

)

(109,564

)

Net property, plant and equipment

 

$

863,457

 

$

829,346

 

 

Depreciation expense was $18.5 million and $13.4 million for the three months ended June 30, 2014 and 2013, respectively.

 

Crude oil volumes required for the operation of storage tanks, known as tank bottoms, are recorded at historical cost. Tank bottoms are the volume of crude oil that must be maintained in a storage tank to enable operation of the storage tank. We recover tank bottom crude oil when we no longer use the storage tanks or the storage tanks are taken out of service. At June 30, 2014, tank bottoms consisted of approximately 173,000 barrels.

 

Note 6 — Goodwill and Intangible Assets

 

The changes in the balance of goodwill during the three months ended June 30, 2014 were as follows (in thousands):

 

Beginning of period

 

$

1,107,006

 

Revisions to acquisition accounting (Note 4)

 

(5,535

)

End of period

 

$

1,101,471

 

 

Goodwill by reportable segment is as follows:

 

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NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements - Continued

At June 30, 2014 and March 31, 2014, and for the

Three Months Ended June 30, 2014 and 2013

 

 

 

June 30,

 

March 31,

 

 

 

2014

 

2014

 

 

 

(in thousands)

 

Crude oil logistics

 

$

598,924

 

$

606,383

 

Water solutions

 

264,127

 

262,203

 

Liquids

 

90,135

 

90,135

 

Retail propane

 

114,285

 

114,285

 

Refined products

 

22,000

 

22,000

 

Renewables

 

12,000

 

12,000

 

 

 

$

1,101,471

 

$

1,107,006

 

 

Our intangible assets consist of the following:

 

 

 

 

 

June 30, 2014

 

March 31, 2014

 

 

 

Amortizable

 

Gross Carrying

 

Accumulated

 

Gross Carrying

 

Accumulated

 

 

 

Lives

 

Amount

 

Amortization

 

Amount

 

Amortization

 

 

 

(in thousands)

 

Amortizable —

 

 

 

 

 

 

 

 

 

 

 

Customer relationships (1)

 

3—20 years

 

$

704,468

 

$

100,942

 

$

697,405

 

$

83,261

 

Water facility development agreement

 

5 years

 

14,000

 

2,800

 

14,000

 

2,100

 

Executory contracts and other agreements

 

5—10 years

 

23,920

 

15,328

 

23,920

 

13,190

 

Non-compete agreements

 

2—7 years

 

14,212

 

7,342

 

14,161

 

6,388

 

Trade names

 

2—10 years

 

14,489

 

3,644

 

15,489

 

3,081

 

Debt issuance costs

 

5—10 years

 

46,283

 

10,621

 

44,089

 

8,708

 

Total amortizable

 

 

 

817,372

 

140,677

 

809,064

 

116,728

 

 

 

 

 

 

 

 

 

 

 

 

 

Non-amortizable —

 

 

 

 

 

 

 

 

 

 

 

Trade names

 

 

 

22,620

 

 

 

22,620

 

 

 

Total

 

 

 

$

839,992

 

$

140,677

 

$

831,684

 

$

116,728

 

 


(1)         The weighted-average remaining amortization period for customer relationship intangible assets is approximately nine years.

 

Amortization expense was as follows:

 

 

 

Three Months Ended June 30,

 

Recorded In

 

2014

 

2013

 

 

 

(in thousands)

 

Depreciation and amortization

 

$

20,893

 

$

9,276

 

Cost of sales

 

2,137

 

625

 

Interest expense

 

1,912

 

1,397

 

 

 

$

24,942

 

$

11,298

 

 

Expected amortization of our intangible assets is as follows (in thousands):

 

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NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements - Continued

At June 30, 2014 and March 31, 2014, and for the

Three Months Ended June 30, 2014 and 2013

 

Year Ending March 31,

 

 

 

2015 (nine months)

 

$

67,042

 

2016

 

85,263

 

2017

 

78,652

 

2018

 

74,684

 

2019

 

67,481

 

Thereafter

 

303,573

 

 

 

$

676,695

 

 

Note 7 — Long-Term Debt

 

Our long-term debt consists of the following:

 

 

 

June 30,

 

March 31,

 

 

 

2014

 

2014

 

 

 

(in thousands)

 

Revolving credit facility —

 

 

 

 

 

Expansion capital loans

 

$

270,000

 

$

532,500

 

Working capital loans

 

465,500

 

389,500

 

6.875% Notes due 2021

 

450,000

 

450,000

 

6.650% Notes due 2022

 

250,000

 

250,000

 

Other notes payable

 

12,543

 

14,914

 

 

 

1,448,043

 

1,636,914

 

Less - current maturities

 

6,168

 

7,080

 

Long-term debt

 

$

1,441,875

 

$

1,629,834

 

 

Credit Agreement

 

On June 19, 2012, we entered into a credit agreement (as amended, the “Credit Agreement”) with a syndicate of banks. The Credit Agreement includes a revolving credit facility to fund working capital needs (the “Working Capital Facility”) and a revolving credit facility to fund acquisitions and expansion projects (the “Expansion Capital Facility,” and together with the Working Capital Facility, the “Revolving Credit Facility”). On June 12, 2014, we executed the sixth amendment to the Credit Agreement, which increased our total borrowing capacity to $2.193 billion.

 

The Working Capital Facility had a total capacity of $1,335.0 million for cash borrowings and letters of credit at June 30, 2014. At that date, we had outstanding cash borrowings of $465.5 million and outstanding letters of credit of $220.3 million on the Working Capital Facility. The Expansion Capital Facility had a total capacity of $858.0 million for cash borrowings at June 30, 2014. At that date, we had outstanding cash borrowings of $270.0 million on the Expansion Capital Facility. The capacity available under the Working Capital Facility may be limited by a “borrowing base,” as defined in the Credit Agreement, which is calculated based on the value of certain working capital items at any point in time.

 

The commitments under the Credit Agreement expire on November 5, 2018. We have the right to prepay outstanding borrowings under the Credit Agreement without incurring any penalties, and prepayments of principal may be required if we enter into certain transactions to sell assets or obtain new borrowings.

 

All borrowings under the Credit Agreement bear interest, at our option, at (i) an alternate base rate plus a margin of 0.50% to 1.50% per annum or (ii) an adjusted LIBOR rate plus a margin of 1.50% to 2.50% per annum. The applicable margin is determined based on our consolidated leverage ratio, as defined in the Credit Agreement. At June 30, 2014, all borrowings under the Credit Agreement were LIBOR borrowings with an interest rate as of June 30, 2014 of 2.16%, calculated as the LIBOR rate of 0.16% plus a margin of 2.00%. At June 30, 2014, the interest rate in effect on letters of credit was 2.00%. Commitment fees are charged at a rate ranging from 0.38% to 0.50% on any unused credit. At June 30, 2014, our outstanding borrowings and interest rates under our Revolving Credit Facility were as follows (dollars in thousands):

 

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NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements - Continued

At June 30, 2014 and March 31, 2014, and for the

Three Months Ended June 30, 2014 and 2013

 

 

 

Amount

 

Rate

 

Expansion Capital Facility —

 

 

 

 

 

LIBOR borrowings

 

$

270,000

 

2.16

%

Working Capital Facility —

 

 

 

 

 

LIBOR borrowings

 

465,500

 

2.16

%

 

The Credit Agreement is secured by substantially all of our assets. The Credit Agreement specifies that our leverage ratio, as defined in the Credit Agreement, cannot exceed 4.25 to 1 at any quarter end. At June 30, 2014, our leverage ratio was approximately 3 to 1. The Credit Agreement also specifies that our interest coverage ratio, as defined in the Credit Agreement, cannot be less than 2.75 to 1 as of the last day of any fiscal quarter. At June 30, 2014, our interest coverage ratio was approximately 6 to 1.

 

The Credit Agreement contains various customary representations, warranties, and additional covenants, including, without limitation, limitations on fundamental changes and limitations on indebtedness and liens. Our obligations under the Credit Agreement may be accelerated following certain events of default (subject to applicable cure periods), including, without limitation, (i) the failure to pay principal or interest when due, (ii) a breach by the Partnership or its subsidiaries of any material representation or warranty or any covenant made in the Credit Agreement, or (iii) certain events of bankruptcy or insolvency.

 

At June 30, 2014, we were in compliance with the covenants under the Credit Agreement.

 

2019 Notes

 

On July 9, 2014, we issued $400.0 million of 5.125% Senior Notes Due 2019 (the “2019 Notes”) in a private placement exempt from registration under the Securities Act of 1933, as amended (the “Securities Act”), pursuant to Rule 144A and Regulation S under the Securities Act. We received net proceeds of $393.5 million, after the initial purchasers’ discount of $6.0 million and estimated offering costs of $0.5 million. We used the net proceeds to reduce the outstanding balance on our Revolving Credit Facility.

 

The 2019 Notes mature on July 15, 2019. Interest is payable on January 15 and July 15 of each year. We have the right to redeem the 2019 Notes prior to the maturity date, although we would be required to pay a premium for early redemption.

 

The Partnership and NGL Energy Finance Corp. are co-issuers of the 2019 Notes, and the obligations under the 2019 Notes are guaranteed by certain of our existing and future restricted subsidiaries that incur or guarantee indebtedness under certain of our other indebtedness, including the Revolving Credit Facility. The purchase agreement and the indenture governing the 2019 Notes contain various customary representations, warranties, and additional covenants, including, without limitation, limitations on fundamental changes and limitations on indebtedness and liens. Our obligations under the purchase agreement and the indenture may be accelerated following certain events of default (subject to applicable cure periods), including, without limitation, (i) the failure to pay principal or interest when due, (ii) experiencing an event of default on certain other debt agreements, or (iii) certain events of bankruptcy or insolvency.

 

We also entered into a registration rights agreement whereby we have committed to exchange the 2019 Notes for a new issue of notes registered under the Securities Act that has substantially identical terms to the 2019 Notes on or before July 9, 2015. If we are unable to fulfill this obligation, we would be required to pay liquidated damages to the holders of the 2019 Notes.

 

2021 Notes

 

On October 16, 2013, we issued $450.0 million of 6.875% Senior Notes Due 2021 (the “2021 Notes”) in a private placement exempt from registration under the Securities Act pursuant to Rule 144A and Regulation S under the Securities Act. We received net proceeds of $438.4 million, after the initial purchasers’ discount of $10.1 million and offering costs of $1.5 million. We used the net proceeds to reduce the outstanding balance on our Revolving Credit Facility.

 

The 2021 Notes mature on October 15, 2021. Interest is payable on April 15 and October 15 of each year. We have the right to redeem the 2021 Notes prior to the maturity date, although we would be required to pay a premium for early redemption.

 

The Partnership and NGL Energy Finance Corp. are co-issuers of the 2021 Notes, and the obligations under the 2021 Notes are guaranteed by certain of our existing and future restricted subsidiaries that incur or guarantee indebtedness under certain of our other indebtedness, including the Revolving Credit Facility. The purchase agreement and the indenture governing the 2021 Notes contain various customary

 

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Table of Contents

 

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements - Continued

At June 30, 2014 and March 31, 2014, and for the

Three Months Ended June 30, 2014 and 2013

 

representations, warranties, and additional covenants, including, without limitation, limitations on fundamental changes and limitations on indebtedness and liens. Our obligations under the purchase agreement and the indenture may be accelerated following certain events of default (subject to applicable cure periods), including, without limitation, (i) the failure to pay principal or interest when due, (ii) experiencing an event of default on certain other debt agreements, or (iii) certain events of bankruptcy or insolvency.

 

At June 30, 2014, we were in compliance with the covenants under the purchase agreement and indenture governing the 2021 Notes.

 

We also entered into a registration rights agreement whereby we have committed to exchange the 2021 Notes for a new issue of notes registered under the Securities Act that has substantially identical terms to the 2021 Notes on or before October 16, 2014. If we are unable to fulfill this obligation, we would be required to pay liquidated damages to the holders of the 2021 Notes.

 

2022 Notes

 

On June 19, 2012, we entered into a Note Purchase Agreement (as amended, the “Note Purchase Agreement”) whereby we issued $250.0 million of Senior Notes in a private placement (the “2022 Notes”). The 2022 Notes bear interest at a fixed rate of 6.65%. Interest is payable quarterly. The 2022 Notes are required to be repaid in semi-annual installments of $25.0 million beginning on December 19, 2017 and ending on the maturity date of June 19, 2022. We have the option to prepay outstanding principal, although we would incur a prepayment penalty. The 2022 Notes are secured by substantially all of our assets and rank equal in priority with borrowings under the Credit Agreement.

 

The Note Purchase Agreement contains various customary representations, warranties, and additional covenants that, among other things, limit our ability to (subject to certain exceptions): (i) incur additional debt, (ii) pay dividends and make other restricted payments, (iii) create or permit certain liens, (iv) create or permit restrictions on the ability of certain of our subsidiaries to pay dividends or make other distributions to us, (v) enter into transactions with affiliates, (vi) enter into sale and leaseback transactions and (vii) consolidate or merge or sell all or substantially all or any portion of our assets. In addition, the Note Purchase Agreement contains substantially the same leverage ratio and interest coverage ratio requirements as our Credit Agreement, which are described above.

 

The Note Purchase Agreement provides for customary events of default that include, among other things (subject in certain cases to customary grace and cure periods): (i) nonpayment of principal or interest, (ii) breach of certain covenants contained in the Note Purchase Agreement or the 2022 Notes, (iii) failure to pay certain other indebtedness or the acceleration of certain other indebtedness prior to maturity if the total amount of such indebtedness unpaid or accelerated exceeds $10.0 million, (iv) the rendering of a judgment for the payment of money in excess of $10.0 million, (v) the failure of the Note Purchase Agreement, the 2022 Notes, or the guarantees by the subsidiary guarantors to be in full force and effect in all material respects and (vi) certain events of bankruptcy or insolvency. Generally, if an event of default occurs (subject to certain exceptions), the trustee or the holders of at least 51% in aggregate principal amount of the then outstanding 2022 Notes of any series may declare all of the 2022 Notes of such series to be due and payable immediately.

 

At June 30, 2014, we were in compliance with the covenants under the Note Purchase Agreement.

 

Other Notes Payable

 

We have executed various noninterest bearing notes payable, primarily related to non-compete agreements entered into in connection with acquisitions of businesses. We also have certain notes payable related to equipment financing, which have interest rates ranging from 2.1% to 4.9% at June 30, 2014.

 

Debt Maturity Schedule

 

The scheduled maturities of our long-term debt are as follows at June 30, 2014:

 

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NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements - Continued

At June 30, 2014 and March 31, 2014, and for the

Three Months Ended June 30, 2014 and 2013

 

 

 

Revolving

 

 

 

 

 

Other

 

 

 

 

 

Credit

 

2021

 

2022

 

Notes

 

 

 

Year Ending March 31,

 

Facility

 

Notes

 

Notes

 

Payable

 

Total

 

 

 

(in thousands)

 

2015 (nine months)

 

$

 

$

 

$

 

$

4,696

 

$

4,696

 

2016

 

 

 

 

3,640

 

3,640

 

2017

 

 

 

 

2,376

 

2,376

 

2018

 

 

 

25,000

 

1,413

 

26,413

 

2019

 

735,500

 

 

50,000

 

239

 

785,739

 

Thereafter

 

 

450,000

 

175,000

 

179

 

625,179

 

 

 

$

735,500

 

$

450,000

 

$

250,000

 

$

12,543

 

$

1,448,043

 

 

Note 8 — Income Taxes

 

We believe that we qualify as a partnership for income tax purposes. As such, we generally do not pay United States federal income tax. Rather, each owner reports his or her share of our income or loss on his or her individual tax return. The aggregate difference in the basis of our net assets for financial and tax reporting purposes cannot be readily determined, as we do not have access to information regarding each partner’s basis in the Partnership.

 

We have certain taxable corporate subsidiaries in the United States and in Canada. In addition, our operations in Texas are subject to a state franchise tax that is calculated based on revenues net of cost of sales.

 

A publicly-traded partnership is required to generate at least 90% of its gross income (as defined for federal income tax purposes) from certain qualifying sources. Income generated by our taxable corporate subsidiaries is excluded from this qualifying income calculation. Although we routinely generate income outside of our corporate subsidiaries that is non-qualifying, we believe that at least 90% of our gross income has been qualifying income for each of the calendar years since our initial public offering.

 

We evaluate uncertain tax positions for recognition and measurement in the consolidated financial statements. To recognize a tax position, we determine whether it is more likely than not that the tax position will be sustained upon examination, including resolution of any related appeals or litigation, based on the technical merits of the position. A tax position that meets the more likely than not threshold is measured to determine the amount of benefit to be recognized in the consolidated financial statements. We had no material uncertain tax positions that required recognition in the consolidated financial statements at June 30, 2014.

 

Note 9 — Commitments and Contingencies

 

Legal Contingencies

 

We are party to various claims, legal actions, and complaints arising in the ordinary course of business. In the opinion of our management, the ultimate resolution of these claims, legal actions, and complaints, after consideration of amounts accrued, insurance coverage, and other arrangements, will not have a material adverse effect on our consolidated financial position, results of operations or cash flows. However, the outcome of such matters is inherently uncertain, and estimates of our liabilities may change materially as circumstances develop.

 

Customer Dispute

 

A customer of our crude oil logistics segment has disputed the transportation rate schedule we used to bill the customer for services that we provided from November 2012 through February 2013, which was the same rate schedule that Pecos Gathering & Marketing, L.L.C. and certain of its affiliated companies (collectively, “Pecos”), used to bill the customer from April 2011 through October 2012 (prior to our November 1, 2012 acquisition of Pecos). The customer has not paid $1.7 million of the amount we charged for services we provided from November 2012 through February 2013. In May 2013, we filed a petition in the District Court of Harris County, Texas seeking to collect these unpaid fees from the customer. Later in May 2013, the customer filed an answer and counterclaim seeking to recover $5.5 million that it paid to Pecos prior to our acquisition of Pecos. We have not recorded revenue for the $1.7 million of unpaid fees charged from November 2012 through February 2013, pending resolution of the dispute.

 

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Table of Contents

 

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements - Continued

At June 30, 2014 and March 31, 2014, and for the

Three Months Ended June 30, 2014 and 2013

 

During August 2013, the customer notified us that it intended to withhold payment of $3.3 million for services performed by us during the period from June 2013 through August 2013, pending resolution of the dispute, although the customer has not disputed the validity of the amounts billed for services performed during this time frame. Upon receiving this notification, we ceased providing services under this contract, and on November 5, 2013, we filed a petition in the District Court of Harris County, Texas seeking to collect these unpaid fees from the customer. We are not able to reliably predict the outcome of this dispute at this time, but we do not believe the outcome will have a material adverse effect on our consolidated financial position or results of operations.

 

Environmental Matters

 

Our operations are subject to extensive federal, state, and local environmental laws and regulations. Although we believe our operations are in substantial compliance with applicable environmental laws and regulations, risks of additional costs and liabilities are inherent in our business, and there can be no assurance that significant costs will not be incurred. Moreover, it is possible that other developments, such as increasingly stringent environmental laws, regulations and enforcement policies thereunder, and claims for damages to property or persons resulting from the operations, could result in substantial costs. Accordingly, we have adopted policies, practices, and procedures in the areas of pollution control, product safety, occupational health, and the handling, storage, use, and disposal of hazardous materials designed to prevent material environmental or other damage, and to limit the financial liability that could result from such events. However, some risk of environmental or other damage is inherent in our business.

 

Asset Retirement Obligations

 

We have recorded a liability of $2.3 million at June 30, 2014 for asset retirement obligations. This liability is related to wastewater disposal facilities and crude oil facilities for which we have contractual and regulatory obligations to perform remediation and, in some instances, dismantlement and removal activities when the assets are retired.

 

In addition to the obligations described above, we may be obligated to remove facilities or perform other remediation upon retirement of certain other assets. We do not believe the present value of these asset retirement obligations, under current laws and regulations, after taking into consideration the estimated lives of our facilities, is material to our consolidated financial position or results of operations.

 

Operating Leases

 

We have executed various noncancelable operating lease agreements for product storage, office space, vehicles, real estate, railcars, and equipment. Future minimum lease payments under contractual commitments at June 30, 2014 are as follows (in thousands):

 

Year Ending March 31,

 

 

 

2015 (nine months)

 

$

95,506

 

2016

 

89,761

 

2017

 

70,821

 

2018

 

56,960

 

2019

 

35,279

 

Thereafter

 

75,895

 

Total

 

$

424,222

 

 

Rental expense relating to operating leases was $25.3 million and $21.9 million during the three months ended June 30, 2014 and 2013, respectively.

 

Pipeline Capacity Agreements

 

We have executed noncancelable agreements with crude pipeline operators, which guarantee us minimum monthly shipping capacity on the pipelines. In exchange, we are obligated to pay the minimum shipping fees in the event actual shipments are less than our allotted capacity. Future minimum throughput payments under throughput agreements at June 30, 2014 are as follows (in thousands):

 

Year Ending March 31:

 

 

 

2015 (nine months)

 

$

39,237

 

2016

 

82,293

 

2017

 

82,293

 

2018

 

82,293

 

2019

 

81,413

 

Thereafter

 

 

72,947

 

Total

 

$

440,476

 

 

Sales and Purchase Contracts

 

We have entered into sales and purchase contracts for products to be delivered in future periods for which we expect the parties to physically settle the contracts with inventory. At June 30, 2014, we had the following such commitments outstanding:

 

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Table of Contents

 

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements - Continued

At June 30, 2014 and March 31, 2014, and for the

Three Months Ended June 30, 2014 and 2013

 

 

 

Volume

 

Value

 

 

 

(in thousands)

 

Natural gas liquids fixed-price purchase commitments (gallons)

 

48,959

 

$

59,367

 

Natural gas liquids index-price purchase commitments (gallons)

 

709,787

 

836,967

 

Natural gas liquids fixed-price sale commitments (gallons)

 

171,561

 

216,222

 

Natural gas liquids index-price sale commitments (gallons)

 

436,086

 

618,799

 

Crude oil index-price purchase commitments (barrels)

 

3,711

 

355,337

 

Crude oil index-price sale commitments (barrels)

 

1,750

 

173,437

 

 

We account for the contracts shown in the table above as normal purchases and normal sales. Under this accounting policy election, we do not record the contracts at fair value at each balance sheet date; instead, we record the purchase or sale at the contracted value once the delivery occurs. Contracts in the table above may have offsetting derivative contracts (described in Note 11) or inventory positions (described in Note 2).

 

Certain other forward purchase and sale contracts do not qualify for the normal purchase and normal sale election. These contracts are recorded at fair value on our condensed consolidated balance sheet and are not included in the data in the table above. These contracts are included in the derivative disclosures in Note 11, and represent $12.5 million of our prepaid expenses and other current assets and $4.2 million of our accrued expenses and other payables at June 30, 2014.

 

Note 10 — Equity

 

Partnership Equity

 

The Partnership’s equity consists of a 0.1% general partner interest and a 99.9% limited partner interest. Limited partner equity includes common and subordinated units. The common and subordinated units share equally in the allocation of income or loss. The principal difference between common and subordinated units is that in any quarter during the subordination period, holders of the subordinated units are not entitled to receive any distribution until the common units have received the minimum quarterly distribution plus any arrearages in the payment of the minimum quarterly distribution from prior quarters. Subordinated units will not accrue arrearages.

 

The subordination period will end in August 2014 when we pay our next distribution. When the subordination period ends, all remaining subordinated units will convert into common units on a one-for-one basis and the common units will no longer be entitled to arrearages.

 

Our general partner is not obligated to make any additional capital contributions or to guarantee or pay any of our debts and obligations.

 

Equity Issuances

 

On June 23, 2014, we completed a public offering of 8,000,000 common units. We received net proceeds of $338.0 million, after underwriting discounts and commissions of $12.3 million and offering costs of $0.5 million. During July 2014, the underwriters exercised their option to purchase an additional 767,100 units. We received net proceeds of $32.5 million from the sale of these units.

 

Distributions

 

Our general partner has adopted a cash distribution policy that will require us to pay a quarterly distribution to the extent we have sufficient cash from operations after establishment of cash reserves and payment of fees and expenses, including payments to the general partner and its affiliates, referred to as “available cash,” in the following manner:

 

·                  First, 99.9% to the holders of common units and 0.1% to the general partner, until each common unit has received the specified minimum quarterly distribution, plus any arrearages from prior quarters.

 

·                  Second, 99.9% to the holders of subordinated units and 0.1% to the general partner, until each subordinated unit has received the specified minimum quarterly distribution.

 

·                  Third, 99.9% to all unitholders, pro rata, and 0.1% to the general partner.

 

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Table of Contents

 

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements - Continued

At June 30, 2014 and March 31, 2014, and for the

Three Months Ended June 30, 2014 and 2013

 

The general partner will also receive, in addition to distributions on its 0.1% general partner interest, additional distributions based on the level of distributions to the limited partners. These distributions are referred to as “incentive distributions.”

 

The following table illustrates the percentage allocations of available cash from operating surplus between the unitholders and our general partner based on the specified target distribution levels. The amounts set forth under “Marginal Percentage Interest In Distributions” are the percentage interests of our general partner and the unitholders in any available cash from operating surplus we distribute up to and including the corresponding amount in the column “Total Quarterly Distribution Per Unit.” The percentage interests shown for our unitholders and our general partner for the minimum quarterly distribution are also applicable to quarterly distribution amounts that are less than the minimum quarterly distribution. The percentage interests set forth below for our general partner include its 0.1% general partner interest, assume our general partner has contributed any additional capital necessary to maintain its 0.1% general partner interest and has not transferred its incentive distribution rights and there are no arrearages on common units.

 

 

 

 

 

 

 

 

 

 

 

Marginal Percentage Interest In

 

 

 

Total Quarterly

 

Distributions

 

 

 

Distribution Per Unit

 

Unitholders

 

General Partner

 

Minimum quarterly distribution

 

 

 

 

 

 

 

$

0.337500

 

99.9

%

0.1

%

First target distribution

 

above

 

$

0.337500

 

up to

 

$

0.388125

 

99.9

%

0.1

%

Second target distribution

 

above

 

$

0.388125

 

up to

 

$

0.421875

 

86.9

%

13.1

%

Third target distribution

 

above

 

$

0.421875

 

up to

 

$

0.506250

 

76.9

%

23.1

%

Thereafter

 

above

 

$

0.506250

 

 

 

 

 

51.9

%

48.1

%

 

During the three months ended June 30, 2014, we distributed a total of $49.5 million ($0.5513 per common, subordinated, and general partner notional unit) to our unitholders of record on May 5, 2014. This included an incentive distribution of $5.8 million to the general partner. In July 2014, we declared a distribution of $0.5888 per common unit, to be paid on August 14, 2014 to unitholders of record on August 4, 2014. This distribution is expected to be $61.5 million, including amounts to be paid on common, subordinated, and general partner notional units and the amount to be paid on incentive distribution rights.

 

Equity-Based Incentive Compensation

 

Our general partner has adopted a long-term incentive plan (“LTIP”), which allows for the issuance of equity-based compensation to employees and directors. Our general partner has granted certain restricted units to employees and directors, which will vest in tranches, subject to the continued service of the recipients. The awards may also vest in the event of a change in control, at the discretion of the board of directors. No distributions will accrue to or be paid on the restricted units during the vesting period.

 

The following table summarizes the restricted unit activity during the three months ended June 30, 2014:

 

Unvested restricted units at March 31, 2014

 

1,311,100

 

Units granted

 

63,000

 

Units vested and issued

 

(6,612

)

Units withheld for employee taxes

 

(3,388

)

Units forfeited

 

(70,000

)

Unvested restricted units at June 30, 2014

 

1,294,100

 

 

The scheduled vesting of the awards is summarized below:

 

25



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NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements - Continued

At June 30, 2014 and March 31, 2014, and for the

Three Months Ended June 30, 2014 and 2013

 

Vesting Date

 

Number of Awards

 

July 1, 2014

 

407,800

 

July 1, 2015

 

344,300

 

July 1, 2016

 

323,500

 

July 1, 2017

 

191,500

 

July 1, 2018

 

27,000

 

Total unvested units at June 30, 2014

 

1,294,100

 

 

During July 2014, 407,800 of the awards vested. We issued 268,822 common units to the recipients and we withheld 138,978 common units, in return for which we paid withholding taxes on behalf of the recipients.

 

We record the expense for the first tranche of each award on a straight-line basis over the period beginning with the grant date of the awards and ending with the vesting date of the tranche. We record the expense for succeeding tranches over the period beginning with the vesting date of the previous tranche and ending with the vesting date of the tranche.

 

At each balance sheet date, we adjust the cumulative expense recorded using the estimated fair value of the awards at the balance sheet date. We calculate the fair value of the awards using the closing price of our common units on the New York Stock Exchange on the balance sheet date, adjusted to reflect the fact that the holders of the unvested units are not entitled to distributions during the vesting period. We estimate the impact of the lack of distribution rights during the vesting period using the value of the most recent distribution and assumptions that a market participant might make about future distribution growth.

 

We recorded expense related to restricted unit awards of $7.9 million and $7.1 million during the three months ended June 30, 2014 and 2013, respectively. We estimate that the future expense we will record on the unvested awards at June 30, 2014 will be as follows (in thousands), after taking into consideration an estimate of forfeitures of approximately 80,000 units. For purposes of this calculation, we used the closing price of our common units on June 30, 2014, which was $43.34.

 

Year Ending March 31,

 

 

 

2015 (nine months)

 

$

10,632

 

2016

 

13,008

 

2017

 

8,446

 

2018

 

2,583

 

2019

 

272

 

Total

 

$

34,941

 

 

Following is a rollforward of the liability related to equity-based compensation, which is reported within accrued expenses and other payables on our condensed consolidated balance sheets (in thousands):

 

Balance at March 31, 2014

 

$

10,012

 

Expense recorded

 

7,914

 

Value of units vested and issued

 

(282

)

Taxes paid on behalf of participants

 

(145

)

Balance at June 30, 2014

 

$

17,499

 

 

The weighted-average fair value of the awards at June 30, 2014 was $40.12 per common unit, which was calculated as the closing price of the common units on June 30, 2014, adjusted to reflect the fact that the restricted units are not entitled to distributions during the vesting period. The impact of the lack of distribution rights during the vesting period was estimated using the value of the most recent distribution and assumptions that a market participant might make about future distribution growth.

 

The number of common units that may be delivered pursuant to awards under the LTIP is limited to 10% of the issued and outstanding common and subordinated units. The maximum number of units deliverable under the plan automatically increases to 10% of the issued and outstanding common and subordinated units immediately after each issuance of common units, unless the plan administrator determines to increase the maximum number of units deliverable by a lesser amount. Units withheld to satisfy tax withholding obligations will not be considered to be delivered under the LTIP. In addition, if an award is forfeited, canceled, exercised, paid or otherwise terminates or expires without the delivery of units, the units subject to such award are again available for new awards under the LTIP. At June 30, 2014, 7.0 million units remain available for issuance under the LTIP.

 

26



Table of Contents

 

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements - Continued

At June 30, 2014 and March 31, 2014, and for the

Three Months Ended June 30, 2014 and 2013

 

In addition to the grants described above, we granted 196,000 restricted units in July 2014 to certain employees as a discretionary bonus. These units will vest in August 2014, and we estimate that we will record $8.5 million of expense during the three months ending September 30, 2014 related to these units (using the June 30, 2014 closing price of our common units).

 

Note 11 — Fair Value of Financial Instruments

 

Our cash and cash equivalents, accounts receivable, accounts payable, accrued expenses, and other current liabilities (excluding derivative instruments) are carried at amounts which reasonably approximate their fair values due to their short-term nature.

 

Commodity Derivatives

 

The following table summarizes the estimated fair values of the commodity derivative assets (liabilities) reported on the consolidated balance sheet at June 30, 2014:

 

 

 

Derivative

 

Derivative

 

 

 

Assets

 

Liabilities

 

 

 

(in thousands)

 

Level 1 measurements

 

$

805

 

$

(3,397

)

Level 2 measurements

 

18,318

 

(18,946

)

 

 

19,123

 

(22,343

)

 

 

 

 

 

 

Netting of counterparty contracts (1)

 

(3,609

)

3,609

 

Cash collateral provided or held

 

 

4,192

 

Commodity contracts reported on consolidated balance sheet

 

$

15,514

 

$

(14,542

)

 


(1)         Relates to derivative assets and liabilities that are expected to be net settled on an exchange or through a master netting arrangement with the counterparty.

 

The following table summarizes the estimated fair values of the commodity derivative assets (liabilities) reported on the consolidated balance sheet at March 31, 2014:

 

 

 

Derivative

 

Derivative

 

 

 

Assets

 

Liabilities

 

 

 

(in thousands)

 

Level 1 measurements

 

$

4,990

 

$

(3,258

)

Level 2 measurements

 

49,605

 

(43,303

)

 

 

54,595

 

(46,561

)

 

 

 

 

 

 

Netting of counterparty contracts (1)

 

(4,347

)

4,347

 

Cash collateral provided or held

 

456

 

 

Commodity contracts reported on consolidated balance sheet

 

$

50,704

 

$

(42,214

)

 


(1)         Relates to derivative assets and liabilities that are expected to be net settled on an exchange or through a master netting arrangement with the counterparty.

 

The commodity derivative assets (liabilities) are reported in the following accounts on the consolidated balance sheets:

 

27



Table of Contents

 

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements - Continued

At June 30, 2014 and March 31, 2014, and for the

Three Months Ended June 30, 2014 and 2013

 

 

 

June 30,

 

March 31,

 

 

 

2014

 

2014

 

 

 

(in thousands)

 

Prepaid expenses and other current assets

 

$

15,514

 

$

50,704

 

Accrued expenses and other payables

 

(14,371

)

(42,214

)

Other noncurrent liabilities

 

(171

)

 

Net asset

 

$

972

 

$

8,490

 

 

The following table sets forth our open commodity derivative contract positions at June 30, 2014 and March 31, 2014. We do not account for these derivatives as hedges.

 

 

 

 

 

Total

 

Fair Value

 

 

 

 

 

Notional

 

of

 

 

 

 

 

Units

 

Net Assets

 

Contracts

 

Settlement Period

 

(Barrels)

 

(Liabilities)

 

 

 

 

 

(in thousands)

 

At June 30, 2014 -

 

 

 

 

 

 

 

Cross-commodity (1)

 

July 2014 - March 2015

 

(196

)

$

(3,088

)

Crude oil fixed-price (2)

 

July 2014 - September 2015

 

(2,180

)

(7,552

)

Crude oil index (3)

 

July 2014 - February 2015

 

3,050

 

4,686

 

Propane fixed-price (4)

 

July 2014 - January 2015

 

950

 

1,734

 

Refined products fixed-price (5)

 

July 2014 - December 2014

 

(176

)

(395

)

Renewable products fixed-price (6)

 

July 2014 - April 2015

 

(2,222

)

1,395

 

 

 

 

 

 

 

(3,220

)

Net cash collateral provided

 

 

 

 

 

4,192

 

Net value of commodity derivatives on consolidated balance sheet

 

 

 

 

 

$

972

 

 

 

 

 

 

 

 

 

At March 31, 2014 -

 

 

 

 

 

 

 

Cross-commodity (1)

 

April 2014 - March 2015

 

140

 

$

(1,876

)

Crude oil fixed-price (2)

 

April 2014 - March 2015

 

(1,600

)

(2,796

)

Crude oil index (3)

 

April 2014 - December 2015

 

3,598

 

6,099

 

Propane fixed-price (4)

 

April 2014 - March 2015

 

60

 

1,753

 

Refined products fixed-price (5)

 

April 2014 - July 2014

 

732

 

560

 

Renewable products fixed-price (6)

 

April 2014 - July 2014

 

106

 

4,084

 

Other

 

April 2014

 

 

210

 

 

 

 

 

 

 

8,034

 

Net cash collateral provided

 

 

 

 

 

456

 

Net value of commodity derivatives on consolidated balance sheet

 

 

 

 

 

$

8,490

 

 


(1)         Cross-commodity — Our operating segments may purchase or sell a physical commodity where the underlying contract pricing mechanisms are tied to different commodity price indices. The contracts listed in this table as “Cross-commodity” represent derivatives we have entered into as economic hedges against the risk of one commodity price moving relative to another commodity price.

 

(2)         Crude oil fixed-price — Our crude oil logistics segment routinely purchases crude oil inventory to enable us to fulfill future orders expected to be placed by our customers. The contracts listed in this table as “Crude oil fixed-price” represent derivatives we have entered into as an economic hedge against the risk that crude oil prices will decline while we are holding the inventory.

 

28



Table of Contents

 

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements - Continued

At June 30, 2014 and March 31, 2014, and for the

Three Months Ended June 30, 2014 and 2013

 

(3)         Crude oil index — Our crude oil logistics segment may purchase or sell crude oil where the underlying contract pricing mechanisms are tied to different crude oil indices. These indices may vary in the type or location of crude oil, or in the timing of delivery within a given month. The contracts listed in this table as “Crude oil index” represent derivatives we have entered into as an economic hedge against the risk of one crude oil index moving relative to another crude oil index.

 

(4)         Propane fixed-price — Our liquids segment routinely purchases inventory during the warmer months and stores the inventory for sale in the colder months. The contracts listed in this table as “Propane fixed-price” represent derivatives we have entered into as an economic hedge against the risk that propane prices will decline while we are holding the inventory.

 

(5)         Refined products fixed-price — Our refined products segment routinely purchases refined products inventory to enable us to fulfill future orders expected to be placed by our customers. The contracts listed in this table as “Refined products fixed-price” represent derivatives we have entered into as an economic hedge against the risk that refined product prices will decline while we are holding the inventory.

 

(6)         Renewable products fixed-price — Our renewables segment routinely purchases biodiesel and ethanol inventory to enable us to fulfill future orders expected to be placed by our customers. The contracts listed in this table as “Renewable products fixed-price” represent derivatives we have entered into as an economic hedge against the risk that biodiesel or ethanol prices will decline while we are holding the inventory.

 

We recorded the following net gains (losses) from our commodity derivatives to cost of sales:

 

Three Months Ended June 30,

 

 

 

2014

 

$

(17,485

)

2013

 

(7,209

)

 

Credit Risk

 

We maintain credit policies with regard to our counterparties on the derivative financial instruments that we believe minimize our overall credit risk, including an evaluation of potential counterparties’ financial condition (including credit ratings), collateral requirements under certain circumstances and the use of standardized agreements, which allow for netting of positive and negative exposure associated with a single counterparty.

 

We may enter into industry standard master netting agreements and may enter into cash collateral agreements requiring the counterparty to deposit funds into a brokerage margin account. The netting agreements reduce our credit risk by providing for net settlement of any offsetting positive and negative exposures with counterparties. The cash collateral agreements reduce the level of our net counterparty credit risk because the amount of collateral represents additional funds that we may access to net settle positions due us, and the amount of collateral adjusts each day in response to changes in the market value of counterparty derivatives.

 

Our counterparties consist primarily of financial institutions and energy companies. This concentration of counterparties may impact our overall exposure to credit risk, either positively or negatively, in that the counterparties may be similarly affected by changes in economic, regulatory or other conditions.

 

As is customary in the crude oil industry, we generally receive payment from customers for sales of crude oil on a monthly basis. As a result, receivables from individual customers in our crude oil logistics segment are generally higher than the receivables from customers in our other segments.

 

Failure of a counterparty to perform on a contract could result in our inability to realize amounts that have been recorded on our condensed consolidated balance sheets and recognized in our net income.

 

Interest Rate Risk

 

Our Revolving Credit Facility is variable-rate debt with interest rates that are generally indexed to bank prime or LIBOR interest rates. At June 30, 2014, we have $735.5 million of outstanding borrowings under our Revolving Credit Facility at a rate of

 

29



Table of Contents

 

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements - Continued

At June 30, 2014 and March 31, 2014, and for the

Three Months Ended June 30, 2014 and 2013

 

2.16%. A change in interest rates of 0.125% would result in an increase or decrease of our annual interest expense of $0.9 million on the $735.5 million of outstanding borrowings under the Revolving Credit Facility at June 30, 2014.

 

Note 12 — Segments

 

Our reportable segments are based on the way in which our management structure is organized. Certain financial data related to our segments is shown below. Transactions between segments are recorded based on prices negotiated between the segments.

 

Our crude oil logistics segment sells crude oil and provides crude oil transportation services to wholesalers, refiners, and producers. Our water solutions segment provides services for the treatment and disposal of wastewater generated from crude oil and natural gas production operations, and generates revenue from the sale of recycled water and recovered hydrocarbons. Our liquids segment supplies propane, butane, and other products, and provides natural gas liquids transportation, terminaling, and storage services to retailers, wholesalers, and refiners. Our retail propane segment sells propane and distillates to end users consisting of residential, agricultural, commercial, and industrial customers, and to certain re-sellers. Our retail propane segment consists of two divisions, which are organized based on the location of the operations.

 

We also operate a refined products marketing business, which purchases gasoline and diesel fuel from suppliers and typically sells these products in back-to-back contracts to customers at a nationwide network of third-party owned terminaling and storage facilities. We also operate a renewables business, which purchases ethanol primarily at production facilities and transports the ethanol for sale at various locations to refiners and blenders, and purchases biodiesel from production facilities in the Midwest and in Houston, Texas, and transports the product using leased railcars for sale to refiners and blenders. These businesses were acquired in our December 2013 acquisition of Gavilon Energy.

 

Items labeled “corporate and other” in the table below include the operations of a compressor leasing business that we acquired in our June 2012 merger with High Sierra and sold in February 2014, and the natural gas marketing operations that we acquired in our December 2013 acquisition of Gavilon Energy and wound down during fiscal year 2014. The “corporate and other” category also includes certain corporate expenses that are incurred and are not allocated to the reportable segments. This data is included to reconcile the data for the reportable segments to data in our condensed consolidated financial statements.

 

30



Table of Contents

 

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements - Continued

At June 30, 2014 and March 31, 2014, and for the

Three Months Ended June 30, 2014 and 2013

 

 

 

Three Months Ended June 30,

 

 

 

2014

 

2013

 

 

 

(in thousands)

 

Revenues:

 

 

 

 

 

Crude oil logistics -

 

 

 

 

 

Crude oil sales

 

$

1,926,944

 

$

928,534

 

Crude oil transportation and other

 

12,114

 

9,935

 

Water solutions -

 

 

 

 

 

Water treatment and disposal

 

41,716

 

18,688

 

Water transportation

 

5,598

 

1,825

 

Liquids -

 

 

 

 

 

Propane sales

 

222,446

 

123,837

 

Other product sales

 

288,359

 

249,853

 

Other revenues

 

5,716

 

8,864

 

Retail propane -

 

 

 

 

 

Propane sales

 

52,026

 

46,691

 

Distillate sales

 

18,695

 

17,869

 

Other revenues

 

7,181

 

7,700

 

Refined products

 

986,223

 

 

Renewables

 

131,274

 

 

Corporate and other

 

1,461

 

1,474

 

Elimination of intersegment sales

 

(51,139

)

(29,313

)

Total revenues

 

$

3,648,614

 

$

1,385,957

 

 

 

 

 

 

 

Depreciation and Amortization:

 

 

 

 

 

Crude oil logistics

 

$

9,731

 

$

4,684

 

Water solutions

 

17,092

 

7,356

 

Liquids

 

3,201

 

2,704

 

Retail propane

 

7,571

 

7,240

 

Refined products

 

382

 

 

Renewables

 

462

 

 

Corporate and other

 

936

 

740

 

Total depreciation and amortization

 

$

39,375

 

$

22,724

 

 

 

 

 

 

 

Operating income (loss):

 

 

 

 

 

Crude oil logistics

 

$

1,463

 

$

6,609

 

Water solutions

 

(907

)

3,043

 

Liquids

 

(913

)

(2,115

)

Retail propane

 

(1,586

)

(1,504

)

Refined products

 

447

 

 

Renewables

 

(1,702

)

 

Corporate and other

 

(17,357

)

(13,375

)

Total operating income

 

$

(20,555

)

$

(7,342

)

 

The following table shows additions to property, plant and equipment for each segment. This information has been prepared on the accrual basis, and includes property, plant and equipment acquired in acquisitions.

 

31



Table of Contents

 

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements - Continued

At June 30, 2014 and March 31, 2014, and for the

Three Months Ended June 30, 2014 and 2013

 

 

 

Three Months Ended June 30,

 

 

 

2014

 

2013

 

 

 

(in thousands)

 

Additions to property, plant and equipment:

 

 

 

 

 

Crude oil logistics

 

$

41,949

 

$

4,126

 

Water solutions

 

7,462

 

7,709

 

Liquids

 

1,159

 

15,107

 

Retail propane

 

2,844

 

6,946

 

Corporate and other

 

1,453

 

629

 

Total

 

$

54,867

 

$

34,517

 

 

The following tables show long-lived assets (consisting of net property, plant and equipment, net intangible assets, and goodwill) and total assets by segment:

 

 

 

June 30,

 

March 31,

 

 

 

2014

 

2014

 

 

 

(in thousands)

 

Total assets:

 

 

 

 

 

Crude oil logistics

 

$

1,938,653

 

$

1,723,812

 

Water solutions

 

882,791

 

875,714

 

Liquids

 

596,644

 

577,795

 

Retail propane

 

505,910

 

541,832

 

Refined products

 

136,325

 

157,581

 

Renewables

 

111,812

 

145,649

 

Corporate and other

 

93,367

 

144,840

 

Total

 

$

4,265,502

 

$

4,167,223

 

 

 

 

 

 

 

Long-lived assets, net:

 

 

 

 

 

Crude oil logistics

 

$

1,011,990

 

$

980,978

 

Water solutions

 

839,024

 

848,479

 

Liquids

 

272,505

 

274,846

 

Retail propane

 

433,859

 

438,324

 

Refined products

 

26,640

 

27,017

 

Renewables

 

32,941

 

33,703

 

Corporate and other

 

47,284

 

47,961

 

Total

 

$

2,664,243

 

$

2,651,308

 

 

Note 13 — Transactions with Affiliates

 

SemGroup Corporation (“SemGroup”) holds ownership interests in us and in our general partner. We sell product to and purchase product from SemGroup, and these transactions are included within revenues and cost of sales in our condensed consolidated statements of operations. We also lease crude oil storage from SemGroup.

 

We purchase ethanol from one of our equity method investees.  These transactions are reported within cost of sales in our condensed consolidated statements of operations.

 

Certain members of our management own interests in entities with which we have purchased products and services from and have sold products and services to. The majority of these purchases represented crude oil purchases and are reported within cost of sales in our condensed consolidated statements of operations, although $2.9 million of these transactions during the three months ended June 30, 2014 represented capital expenditures and were recorded as increases to property, plant and equipment. The majority of these sales represented sales of crude oil and are reported within revenues in our condensed consolidated statements of operations.

 

These transactions are summarized in the following table:

 

32



Table of Contents

 

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements - Continued

At June 30, 2014 and March 31, 2014, and for the

Three Months Ended June 30, 2014 and 2013

 

 

 

Three Months Ended June 30,

 

 

 

2014

 

2013

 

 

 

(in thousands)

 

Sales to SemGroup

 

$

73,806

 

$

 

Purchases from SemGroup

 

73,267

 

19,539

 

Purchases from equity method investees

 

36,276

 

 

Sales to entities affiliated with management

 

148

 

51,103

 

Purchases from entities affiliated with management

 

3,139

 

7,824

 

 

Receivables from affiliates consist of the following:

 

 

 

June 30,

 

March 31,

 

 

 

2014

 

2014

 

 

 

(in thousands)

 

Receivables from SemGroup

 

$

674

 

$

7,303

 

Receivables from entities affiliated with management

 

436

 

142

 

 

 

$

1,110

 

$

7,445

 

 

Payables to affiliates consist of the following:

 

 

 

June 30,

 

March 31,

 

 

 

2014

 

2014

 

 

 

(in thousands)

 

Payables to SemGroup

 

$

8,308

 

$

27,738

 

Payables to equity method investees

 

29,170

 

48,454

 

Payables to entities affiliated with management

 

228

 

654

 

 

 

$

37,706

 

$

76,846

 

 

Note 14 — Condensed Consolidating Guarantor and Non-Guarantor Financial Information

 

Certain of our wholly-owned subsidiaries have, jointly and severally, fully and unconditionally guaranteed the 2019 Notes and the 2021 Notes (described in Note 7). Pursuant to Rule 3-10 of Regulation S-X, we have presented in columnar format the condensed consolidating financial information for NGL Energy Partners LP, NGL Energy Finance Corp. (which, along with NGL Energy Partners LP, is a co-issuer of the 2021 Notes), the guarantor subsidiaries on a combined basis, and the non-guarantor subsidiaries on a combined basis in the tables below.

 

During the periods presented in the tables below, the status of certain subsidiaries changed, in that they either became guarantors of or ceased to be guarantors of the 2021 Notes. Such changes have been given retrospective application in the tables below.

 

There are no significant restrictions upon the ability of the parent or any of the guarantor subsidiaries to obtain funds from their respective subsidiaries by dividend or loan. None of the assets of the guarantor subsidiaries represent restricted net assets pursuant to Rule 4-08(e)(3) of Regulation S-X under the Securities Act.

 

For purposes of the tables below, (i) the condensed consolidating financial information is presented on a legal entity basis, not a business segment basis, (ii) investments in consolidated subsidiaries are accounted for as equity method investments, and (iii) contributions, distributions, and advances to or from consolidated entities are reported on a net basis within net changes in advances with consolidated entities in the condensed consolidating cash flow tables below.

 

33



Table of Contents

 

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements - Continued

At June 30, 2014 and March 31, 2014, and for the

Three Months Ended June 30, 2014 and 2013

 

NGL ENERGY PARTNERS LP

Condensed Consolidating Balance Sheet

(U.S. Dollars in Thousands)

 

 

 

June 30, 2014

 

 

 

NGL Energy

 

 

 

 

 

 

 

 

 

 

 

 

 

Partners LP

 

NGL Energy

 

Guarantor

 

Non-Guarantor

 

Consolidating

 

 

 

 

 

(Parent) (1)

 

Finance Corp.

 

Subsidiaries

 

Subsidiaries

 

Adjustments

 

Consolidated

 

ASSETS

 

 

 

 

 

 

 

 

 

 

 

 

 

CURRENT ASSETS:

 

 

 

 

 

 

 

 

 

 

 

 

 

Cash and cash equivalents

 

$

31,399

 

$

 

$

7,589

 

$

691

 

$

 

$

39,679

 

Accounts receivable - trade, net of allowance for doubtful accounts

 

 

 

898,987

 

4,024

 

 

903,011

 

Accounts receivable - affiliates

 

 

 

1,110

 

 

 

1,110

 

Inventories

 

 

 

373,389

 

244

 

 

373,633

 

Prepaid expenses and other current assets

 

 

 

58,585

 

28

 

 

58,613

 

Total current assets

 

31,399

 

 

1,339,660

 

4,987

 

 

1,376,046

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

PROPERTY, PLANT AND EQUIPMENT, net of accumulated depreciation

 

 

 

798,446

 

65,011

 

 

863,457

 

GOODWILL

 

 

 

1,099,473

 

1,998

 

 

1,101,471

 

INTANGIBLE ASSETS, net of accumulated amortization

 

1,347

 

11,451

 

684,973

 

1,544

 

 

699,315

 

INVESTMENTS IN UNCONSOLIDATED ENTITIES

 

 

 

211,480

 

 

 

211,480

 

NET INTERCOMPANY RECEIVABLES (PAYABLES)

 

267,321

 

444,020

 

(654,939

)

(56,402

)

 

 

INVESTMENTS IN CONSOLIDATED SUBSIDIARIES

 

1,726,452

 

 

3,845

 

 

(1,730,297

)

 

OTHER NONCURRENT ASSETS

 

 

 

13,733

 

 

 

13,733

 

Total assets

 

$

2,026,519

 

$

455,471

 

$

3,496,671

 

$

17,138

 

$

(1,730,297

)

$

4,265,502

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

LIABILITIES AND EQUITY

 

 

 

 

 

 

 

 

 

 

 

 

 

CURRENT LIABILITIES:

 

 

 

 

 

 

 

 

 

 

 

 

 

Accounts payable - trade

 

$

 

$

 

$

804,052

 

$

6,097

 

$

 

$

810,149

 

Accounts payable - affiliates

 

 

 

37,706

 

 

 

37,706

 

Accrued expenses and other payables

 

554

 

6,617

 

115,138

 

1,630

 

 

123,939

 

Advance payments received from customers

 

 

 

56,295

 

78

 

 

56,373

 

Current maturities of long-term debt

 

 

 

6,148

 

20

 

 

6,168

 

Total current liabilities

 

554

 

6,617

 

1,019,339

 

7,825

 

 

1,034,335

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

LONG-TERM DEBT, net of current maturities

 

250,000

 

450,000

 

741,815

 

60

 

 

1,441,875

 

OTHER NONCURRENT LIABILITIES

 

 

 

7,919

 

81

 

 

8,000

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

EQUITY

 

 

 

 

 

 

 

 

 

 

 

 

 

Partners’ equity (deficit)

 

1,775,965

 

(1,146

)

1,727,598

 

9,223

 

(1,735,624

)

1,776,016

 

Accumulated other comprehensive loss

 

 

 

 

(51

)

 

(51

)

Noncontrolling interests

 

 

 

 

 

5,327

 

5,327

 

Total equity (deficit)

 

1,775,965

 

(1,146

)

1,727,598

 

9,172

 

(1,730,297

)

1,781,292

 

Total liabilities and equity

 

$

2,026,519

 

$

455,471

 

$

3,496,671

 

$

17,138

 

$

(1,730,297

)

$

4,265,502

 

 


(1)         The parent is a co-issuer of the 2021 Notes that are included in the NGL Energy Finance Corp. column.

 

34



Table of Contents

 

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements - Continued

At June 30, 2014 and March 31, 2014, and for the

Three Months Ended June 30, 2014 and 2013

 

NGL ENERGY PARTNERS LP

Condensed Consolidating Balance Sheet

(U.S. Dollars in Thousands)

 

 

 

March 31, 2014

 

 

 

NGL Energy

 

 

 

 

 

 

 

 

 

 

 

 

 

Partners LP

 

NGL Energy

 

Guarantor

 

Non-Guarantor

 

Consolidating

 

 

 

 

 

(Parent) (1)

 

Finance Corp.

 

Subsidiaries

 

Subsidiaries

 

Adjustments

 

Consolidated

 

ASSETS

 

 

 

 

 

 

 

 

 

 

 

 

 

CURRENT ASSETS:

 

 

 

 

 

 

 

 

 

 

 

 

 

Cash and cash equivalents

 

$

1,181

 

$

 

$

8,728

 

$

531

 

$

 

$

10,440

 

Accounts receivable - trade, net of allowance for doubtful accounts

 

 

 

887,789

 

13,115

 

 

900,904

 

Accounts receivable - affiliates

 

 

 

7,445

 

 

 

7,445

 

Inventories

 

 

 

306,434

 

3,726

 

 

310,160

 

Prepaid expenses and other current assets

 

 

 

80,294

 

56

 

 

80,350

 

Total current assets

 

1,181

 

 

1,290,690

 

17,428

 

 

1,309,299

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

PROPERTY, PLANT AND EQUIPMENT, net of accumulated depreciation

 

 

 

764,014

 

65,332

 

 

829,346

 

GOODWILL

 

 

 

1,105,008

 

1,998

 

 

1,107,006

 

INTANGIBLE ASSETS, net of accumulated amortization

 

1,169

 

11,552

 

700,603

 

1,632

 

 

714,956

 

INVESTMENTS IN UNCONSOLIDATED ENTITIES

 

 

 

189,821

 

 

 

189,821

 

NET INTERCOMPANY RECEIVABLES (PAYABLES)

 

327,281

 

437,714

 

(720,737

)

(44,258

)

 

 

INVESTMENTS IN CONSOLIDATED SUBSIDIARIES

 

1,447,502

 

 

17,673

 

 

(1,465,175

)

 

OTHER NONCURRENT ASSETS

 

 

 

16,674

 

121

 

 

16,795

 

Total assets

 

$

1,777,133

 

$

449,266

 

$

3,363,746

 

$

42,253

 

$

(1,465,175

)

$

4,167,223

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

LIABILITIES AND EQUITY

 

 

 

 

 

 

 

 

 

 

 

 

 

CURRENT LIABILITIES:

 

 

 

 

 

 

 

 

 

 

 

 

 

Accounts payable - trade

 

$

 

$

 

$

726,252

 

$

13,959

 

$

 

$

740,211

 

Accounts payable - affiliates

 

 

 

73,703

 

3,143

 

 

76,846

 

Accrued expenses and other payables

 

554

 

14,266

 

124,923

 

1,947

 

 

141,690

 

Advance payments received from customers

 

 

 

29,891

 

74

 

 

29,965

 

Current maturities of long-term debt

 

 

 

7,058

 

22

 

 

7,080

 

Total current liabilities

 

554

 

14,266

 

961,827

 

19,145

 

 

995,792

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

LONG-TERM DEBT, net of current maturities

 

250,000

 

450,000

 

929,754

 

80

 

 

1,629,834

 

OTHER NONCURRENT LIABILITIES

 

 

 

9,663

 

81

 

 

9,744

 

EQUITY

 

 

 

 

 

 

 

 

 

 

 

 

 

Partners’ equity (deficit)

 

1,526,579

 

(15,000

)

1,462,691

 

22,994

 

(1,470,449

)

1,526,815

 

Accumulated other comprehensive loss

 

 

 

(189

)

(47

)

 

(236

)

Noncontrolling interests

 

 

 

 

 

5,274

 

5,274

 

Total equity (deficit)

 

1,526,579

 

(15,000

)

1,462,502

 

22,947

 

(1,465,175

)

1,531,853

 

Total liabilities and equity

 

$

1,777,133

 

$

449,266

 

$

3,363,746

 

$

42,253

 

$

(1,465,175

)

$

4,167,223

 

 


(1)         The parent is a co-issuer of the 2021 Notes that are included in the NGL Energy Finance Corp. column.

 

35



Table of Contents

 

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements - Continued

At June 30, 2014 and March 31, 2014, and for the

Three Months Ended June 30, 2014 and 2013

 

NGL ENERGY PARTNERS LP

Condensed Consolidating Statement of Operations

(U.S. Dollars in Thousands)

 

 

 

Three Months Ended June 30, 2014

 

 

 

NGL Energy

 

 

 

 

 

 

 

 

 

 

 

 

 

Partners LP

 

NGL Energy

 

Guarantor

 

Non-Guarantor

 

Consolidating

 

 

 

 

 

(Parent) (1)

 

Finance Corp.

 

Subsidiaries

 

Subsidiaries

 

Adjustments

 

Consolidated

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

REVENUES

 

$

 

$

 

$

3,627,586

 

$

21,057

 

$

(29

)

$

3,648,614

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

COST OF SALES

 

 

 

3,514,946

 

19,136

 

(29

)

3,534,053

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

OPERATING COSTS AND EXPENSES:

 

 

 

 

 

 

 

 

 

 

 

 

 

Operating

 

 

 

66,619

 

1,249

 

 

67,868

 

General and administrative

 

 

 

27,764

 

109

 

 

27,873

 

Depreciation and amortization

 

 

 

38,546

 

829

 

 

39,375

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Operating Loss

 

 

 

(20,289

)

(266

)

 

(20,555

)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

OTHER INCOME (EXPENSE):

 

 

 

 

 

 

 

 

 

 

 

 

 

Earnings of unconsolidated entities

 

 

 

2,565

 

 

 

2,565

 

Interest expense

 

(4,246

)

(8,146

)

(8,102

)

(11

)

11

 

(20,494

)

Other, net

 

 

 

(532

)

152

 

(11

)

(391

)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Loss Before Income Taxes

 

(4,246

)

(8,146

)

(26,358

)

(125

)

 

(38,875

)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

INCOME TAX PROVISION

 

 

 

(958

)

(77

)

 

(1,035

)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

EQUITY IN NET LOSS OF CONSOLIDATED SUBSIDIARIES

 

(35,729

)

 

(267

)

 

35,996

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Net Loss

 

(39,975

)

(8,146

)

(27,583

)

(202

)

35,996

 

(39,910

)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

NET INCOME ALLOCATED TO GENERAL PARTNER

 

 

 

 

 

 

 

 

 

(9,381

)

(9,381

)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS

 

 

 

 

 

 

 

 

 

(65

)

(65

)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

NET LOSS ALLOCATED TO LIMITED PARTNERS

 

$

(39,975

)

$

(8,146

)

$

(27,583

)

$

(202

)

$

26,550

 

$

(49,356

)

 


(1)         The parent is a co-issuer of the 2021 Notes.

 

36



Table of Contents

 

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements - Continued

At June 30, 2014 and March 31, 2014, and for the

Three Months Ended June 30, 2014 and 2013

 

NGL ENERGY PARTNERS LP

Condensed Consolidating Statement of Operations

(U.S. Dollars in Thousands)

 

 

 

Three Months Ended June 30, 2013

 

 

 

NGL Energy

 

 

 

 

 

 

 

 

 

 

 

Partners LP

 

Guarantor

 

Non-Guarantor

 

Consolidating

 

 

 

 

 

(Parent)

 

Subsidiaries

 

Subsidiaries

 

Adjustments

 

Consolidated

 

 

 

 

 

 

 

 

 

 

 

 

 

REVENUES

 

$

 

$

1,368,305

 

$

17,686

 

$

(34

)

$

1,385,957

 

 

 

 

 

 

 

 

 

 

 

 

 

COST OF SALES

 

 

1,290,448

 

12,662

 

(34

)

1,303,076

 

 

 

 

 

 

 

 

 

 

 

 

 

OPERATING COSTS AND EXPENSES:

 

 

 

 

 

 

 

 

 

 

 

Operating

 

 

46,731

 

2,314

 

 

49,045

 

General and administrative

 

 

18,208

 

246

 

 

18,454

 

Depreciation and amortization

 

 

22,030

 

694

 

 

22,724

 

 

 

 

 

 

 

 

 

 

 

 

 

Operating Income (Loss)

 

 

(9,112

)

1,770

 

 

(7,342

)

 

 

 

 

 

 

 

 

 

 

 

 

OTHER INCOME (EXPENSE):

 

 

 

 

 

 

 

 

 

 

 

Interest expense

 

(4,189

)

(6,429

)

(15

)

11

 

(10,622

)

Other, net

 

 

99

 

(38

)

(11

)

50

 

 

 

 

 

 

 

 

 

 

 

 

 

Income (Loss) Before Income Taxes

 

(4,189

)

(15,442

)

1,717

 

 

(17,914

)

 

 

 

 

 

 

 

 

 

 

 

 

INCOME TAX BENEFIT

 

 

406

 

 

 

406

 

 

 

 

 

 

 

 

 

 

 

 

 

EQUITY IN NET INCOME (LOSS) OF CONSOLIDATED SUBSIDIARIES

 

(13,444

)

1,592

 

 

11,852

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Net Income (Loss)

 

(17,633

)

(13,444

)

1,717

 

11,852

 

(17,508

)

 

 

 

 

 

 

 

 

 

 

 

 

NET INCOME ALLOCATED TO GENERAL PARTNER

 

 

 

 

 

 

 

(1,688

)

(1,688

)

 

 

 

 

 

 

 

 

 

 

 

 

NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS

 

 

 

 

 

 

 

(125

)

(125

)

 

 

 

 

 

 

 

 

 

 

 

 

NET INCOME (LOSS) ALLOCATED TO LIMITED PARTNERS

 

$

(17,633

)

$

(13,444

)

$

1,717

 

$

10,039

 

$

(19,321

)

 

37



Table of Contents

 

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements - Continued

At June 30, 2014 and March 31, 2014, and for the

Three Months Ended June 30, 2014 and 2013

 

NGL ENERGY PARTNERS LP

Condensed Consolidating Statements of Comprehensive Income (Loss)

(U.S. Dollars in Thousands)

 

 

 

Three Months Ended June 30, 2014

 

 

 

NGL Energy

 

 

 

 

 

 

 

 

 

 

 

 

 

Partners LP

 

NGL Energy

 

Guarantor

 

Non-Guarantor

 

Consolidating

 

 

 

 

 

(Parent) (1)

 

Finance Corp.

 

Subsidiaries

 

Subsidiaries

 

Adjustments

 

Consolidated

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Net loss

 

$

(39,975

)

$

(8,146

)

$

(27,583

)

$

(202

)

$

35,996

 

$

(39,910

)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Other comprehensive income

 

 

 

185

 

 

 

185

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Comprehensive loss

 

$

(39,975

)

$

(8,146

)

$

(27,398

)

$

(202

)

$

35,996

 

$

(39,725

)

 


(1)  The parent is a co-issuer of the 2021 Notes.

 

 

 

Three Months Ended June 30, 2013

 

 

 

 

 

NGL Energy

 

 

 

 

 

 

 

 

 

 

 

 

 

Partners LP

 

Guarantor

 

Non-Guarantor

 

Consolidating

 

 

 

 

 

 

 

(Parent)

 

Subsidiaries

 

Subsidiaries

 

Adjustments

 

Consolidated

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Net income (loss)

 

$

(17,633

)

$

(13,444

)

$

1,717

 

$

11,852

 

$

(17,508

)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Other comprehensive loss

 

 

 

(25

)

 

(25

)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Comprehensive income (loss)

 

$

(17,633

)

$

(13,444

)

$

1,692

 

$

11,852

 

$

(17,533

)

 

 

 

38



Table of Contents

 

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements - Continued

At June 30, 2014 and March 31, 2014, and for the

Three Months Ended June 30, 2014 and 2013

 

NGL ENERGY PARTNERS LP

Condensed Consolidating Statement of Cash Flows

(U.S. Dollars in Thousands)

 

 

 

Three Months Ended June 30, 2014

 

 

 

NGL Energy

 

 

 

 

 

 

 

 

 

 

 

Partners LP

 

NGL Energy

 

Guarantor

 

Non-Guarantor

 

 

 

 

 

(Parent) (1)

 

Finance Corp.

 

Subsidiaries

 

Subsidiaries

 

Consolidated

 

OPERATING ACTIVITIES:

 

 

 

 

 

 

 

 

 

 

 

Net cash provided by (used in) operating activities

 

$

(4,156

)

$

(15,384

)

$

26,650

 

$

2,096

 

$

9,206

 

 

 

 

 

 

 

 

 

 

 

 

 

INVESTING ACTIVITIES:

 

 

 

 

 

 

 

 

 

 

 

Purchases of long-lived assets

 

 

 

(48,608

)

(259

)

(48,867

)

Acquisitions of businesses, including acquired working capital, net of cash acquired

 

 

 

(15,619

)

(250

)

(15,869

)

Cash flows from commodity derivatives

 

 

 

(9,967

)

 

(9,967

)

Proceeds from sales of assets

 

 

 

989

 

 

989

 

Investments in unconsolidated entities

 

 

 

(4,094

)

 

(4,094

)

Net cash used in investing activities

 

 

 

(77,299

)

(509

)

(77,808

)

 

 

 

 

 

 

 

 

 

 

 

 

FINANCING ACTIVITIES:

 

 

 

 

 

 

 

 

 

 

 

Proceeds from borrowings under revolving credit facility

 

 

 

494,500

 

 

494,500

 

Payments on revolving credit facility

 

 

 

(681,000

)

 

(681,000

)

Payments on other long-term debt

 

 

 

(2,345

)

(2

)

(2,347

)

Debt issuance costs

 

(266

)

(310

)

(1,618

)

 

(2,194

)

Contributions

 

352

 

 

 

 

352

 

Distributions

 

(49,491

)

 

 

(12

)

(49,503

)

Proceeds from sale of common units, net of offering costs

 

338,033

 

 

 

 

338,033

 

Net changes in advances with consolidated entities

 

(254,254

)

15,694

 

239,973

 

(1,413

)

 

Net cash provided by (used in) financing activities

 

34,374

 

15,384

 

49,510

 

(1,427

)

97,841

 

Net increase (decrease) in cash and cash equivalents

 

30,218

 

 

(1,139

)

160

 

29,239

 

Cash and cash equivalents, beginning of period

 

1,181

 

 

8,728

 

531

 

10,440

 

Cash and cash equivalents, end of period

 

$

31,399

 

$

 

$

7,589

 

$

691

 

$

39,679

 

 


(1)  The parent is a co-issuer of the 2021 Notes.

 

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NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements - Continued

At June 30, 2014 and March 31, 2014, and for the

Three Months Ended June 30, 2014 and 2013

 

NGL ENERGY PARTNERS LP

Condensed Consolidating Statement of Cash Flows

(U.S. Dollars in Thousands)

 

 

 

Three Months Ended June 30, 2013

 

 

 

NGL Energy

 

 

 

 

 

 

 

 

 

Partners LP

 

Guarantor

 

Non-Guarantor

 

 

 

 

 

(Parent)

 

Subsidiaries

 

Subsidiaries

 

Consolidated

 

OPERATING ACTIVITIES:

 

 

 

 

 

 

 

 

 

Net cash provided by (used in) operating activities

 

$

(4,154

)

$

30,924

 

$

(1,237

)

$

25,533

 

 

 

 

 

 

 

 

 

 

 

INVESTING ACTIVITIES:

 

 

 

 

 

 

 

 

 

Purchases of long-lived assets

 

 

(14,925

)

(15,267

)

(30,192

)

Acquisitions of businesses, including acquired working capital, net of cash acquired

 

 

(2,676

)

(2,283

)

(4,959

)

Cash flows from commodity derivatives

 

 

(11,054

)

 

(11,054

)

Proceeds from sales of assets

 

 

1,088

 

 

1,088

 

Net cash used in investing activities

 

 

(27,567

)

(17,550

)

(45,117

)

 

 

 

 

 

 

 

 

 

 

FINANCING ACTIVITIES:

 

 

 

 

 

 

 

 

 

Proceeds from borrowings under revolving credit facility

 

 

255,000

 

 

255,000

 

Payments on revolving credit facility

 

 

(212,000

)

 

(212,000

)

Proceeds from borrowings on other long-term debt

 

 

780

 

100

 

880

 

Payments on other long-term debt

 

 

(2,880

)

(4

)

(2,884

)

Debt issuance costs

 

(133

)

(2,078

)

 

(2,211

)

Contributions

 

 

 

1,000

 

1,000

 

Distributions

 

(26,794

)

 

(365

)

(27,159

)

Net changes in advances with consolidated entities

 

32,357

 

(50,393

)

18,036

 

 

Net cash provided by (used in) financing activities

 

5,430

 

(11,571

)

18,767

 

12,626

 

Net increase (decrease) in cash and cash equivalents

 

1,276

 

(8,214

)

(20

)

(6,958

)

Cash and cash equivalents, beginning of period

 

 

11,206

 

355

 

11,561

 

Cash and cash equivalents, end of period

 

$

1,276

 

$

2,992

 

$

335

 

$

4,603

 

 

Note 15 Subsequent Events

 

Acquisitions Subsequent to June 30, 2014

 

TransMontaigne Inc.

 

On July 1, 2014, we acquired TransMontaigne Inc. (“TransMontaigne”) for $173.8 million of cash, net of cash acquired. As part of this transaction, we also purchased $346.9 million of inventory from the previous owner of TransMontaigne. The operations of TransMontaigne include the marketing of refined products and crude oil. As part of this transaction, we acquired the general partner interest and a 19.7% limited partner interest in TransMontaigne Partners L.P. (“TLP”), a publicly-traded partnership that conducts refined product and crude oil transportation and terminaling operations.

 

On July 10, 2014, we submitted a non-binding proposal to the conflicts committee of the board of directors of TLP’s general partner. Under this proposal, each outstanding unit of TLP would be exchanged for one of our common units. This proposed transaction is subject to the negotiation and execution of a definitive agreement, the approval of the conflicts committee of the board of directors of TLP’s general partner, and any requisite unitholder approval under applicable law.

 

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NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements - Continued

At June 30, 2014 and March 31, 2014, and for the

Three Months Ended June 30, 2014 and 2013

 

Water Solutions Facilities

 

As described in Note 4, we are party to a development agreement that provides us a first right of refusal to purchase water disposal facilities developed by the other party to the agreement. During July 2014, we purchased four facilities under this development agreement. We also purchased one additional facility in July 2014 from a different seller. On a combined basis, we paid $82.8 million of cash for these five facilities.

 

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Table of Contents

 

Item 2.         Management’s Discussion and Analysis of Financial Condition and Results of Operations

 

The following is a discussion of our financial condition and results of operations as of and for the three months ended June 30, 2014. The discussion should be read in conjunction with Management’s Discussion and Analysis of Financial Condition and Results of Operations and the historical consolidated financial statements and notes thereto included in our Annual Report on Form 10-K for the fiscal year ended March 31, 2014.

 

Overview

 

We are a Delaware limited partnership formed in September 2010. NGL Energy Holdings LLC serves as our general partner. At June 30, 2014, our primary operations include:

 

·                  Our crude oil logistics business, the assets of which include owned and leased crude oil storage terminals, pipeline injection stations, a fleet of trucks, a fleet of leased and owned railcars, and a fleet of barges and towboats, and a 50% interest in a crude oil pipeline. Our crude oil logistics business purchases crude oil from producers and transports it for resale at owned and leased pipeline injection points, storage terminals, barge loading facilities, rail facilities, refineries, and other trade hubs.

 

·                  Our water solutions business, the assets of which include water treatment and disposal facilities and a 27.5% interest in a water supply company. Our water solutions business generates revenues from the treatment and disposal of wastewater generated from crude oil and natural gas production operations, and from the sale of recycled water and recovered hydrocarbons.

 

·                  Our liquids business, which supplies natural gas liquids to retailers, wholesalers, refiners, and petrochemical plants throughout the United States and in Canada, and which provides natural gas liquids terminaling services through its 22 terminals throughout the United States and railcar transportation services through its fleet of leased and owned railcars. Our liquids business purchases propane, butane, and other products from refiners, processing plants, producers, and other parties, and sells the product to retailers, refiners, and other participants in the wholesale markets.

 

·                  Our retail propane business, which sells propane, distillates, and equipment and supplies to end users consisting of residential, agricultural, commercial, and industrial customers and to certain re-sellers in more than 20 states.

 

·                  Our refined products and renewables marketing business, which purchases gasoline and diesel fuel from suppliers and typically sells these products in back-to-back contracts to customers at a nationwide network of third-party owned terminaling and storage facilities, and which purchases ethanol primarily at production facilities and transports the ethanol to refiners and blenders at various locations. We also purchase biodiesel from production facilities located in the Midwest and Houston, Texas, and transport the biodiesel via railcars for sale to refiners and blenders. We also own an 11% interest in an ethanol production facility in Nebraska.

 

Crude Oil Logistics

 

Our crude oil logistics business purchases crude oil from producers and transports it for resale at pipeline injection points, storage terminals, barge loading facilities, rail facilities, refineries, and other trade hubs. We attempt to reduce our exposure to price fluctuations by using back-to-back contracts whenever possible. In addition, we enter into forward contracts, financial swaps, and commodity spread trades as economic hedges of our physical forward sales and purchase contracts with our customers and suppliers.

 

Most of our contracts to purchase or sell crude oil are at floating prices that are indexed to published rates in active markets, such as Cushing, Oklahoma. We seek to manage price risk by entering into purchase and sale contracts of similar volumes based on similar indexes and by entering into financial derivatives. We utilize our transportation assets to move crude oil from the wellhead to the highest value market. The spread between crude oil prices in different markets can fluctuate widely, which may expand or limit our opportunity to generate margins by transporting crude oil to different markets. We also seek to maximize margins by blending crude oil of varying properties.

 

The range of low and high spot prices per barrel of NYMEX West Texas Intermediate Crude Oil at Cushing, Oklahoma and the prices at period end were as follows:

 

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Spot Price Per Barrel

 

Three Months Ended June 30,

 

Low

 

High

 

At Period End

 

2014

 

$

99.42

 

$

107.26

 

$

105.37

 

2013

 

86.68

 

98.44

 

96.56

 

 

We believe volatility in commodity prices will continue, and our ability to adjust to and manage this volatility may impact our financial results.

 

Water Solutions

 

Our water solutions business generates revenues from the treatment and disposal of wastewater generated from oil and natural gas production operations, and from the sale of recycled water and recovered hydrocarbons. Our water processing facilities are strategically located near areas of high crude oil and natural gas production. A significant factor affecting the profitability of our water solutions segment is the extent of exploration and production in the areas near our facilities, which is based upon producers’ expectations about the profitability of drilling new wells. The primary customers of our facility in Wyoming have committed to deliver a specified minimum volume of water to our facility under long-term contracts. The primary customers of our facilities in Colorado have committed to deliver to our facilities all wastewater produced at wells in a designated area. Most of the customers at our other facilities in Texas are not under volume commitments, other than one customer that has committed to deliver 50,000 barrels per day to our facilities.

 

Liquids

 

Our liquids business purchases propane, butane, and other products from refiners, processing plants, producers, and other parties, and sells the product to retailers, refiners, petrochemical plants, and other participants in the wholesale markets. Our liquids segment owns 22 terminals, operates a fleet of owned and leased railcars, and leases underground storage capacity. We attempt to reduce our exposure to the impact of price fluctuations by using back-to-back contracts and pre-sale agreements that allow us to lock in a margin on a percentage of our winter volumes. We also attempt to reduce our exposure to the impact of price fluctuations by entering into swap agreements whereby we agree to pay a floating rate and receive a fixed rate on a specified notional amount of product. We enter into these agreements as economic hedges against the potential decline in the value of a portion of our inventory.

 

Our wholesale business is a “cost-plus” business that is affected both by price fluctuations and volume variations. We establish our selling price based on a pass-through of our product supply, transportation, handling, storage and capital costs plus an acceptable margin. The margins we realize in our wholesale business are substantially less on a per gallon basis than our retail propane business.

 

Weather conditions and gasoline blending have a significant impact on the demand for propane and butane, and sales volumes and prices are typically higher during the colder months of the year. Consequently, our revenues, operating profits, and operating cash flows are typically lower in the first and second quarters of each fiscal year.

 

The range of low and high spot propane prices per gallon at Conway, Kansas and Mt. Belvieu, Texas, two of our main pricing hubs, and the prices at period end were as follows:

 

 

 

Conway, Kansas

 

Mt. Belvieu, Texas

 

 

 

Spot Price Per Gallon

 

Spot Price Per Gallon

 

Three Months Ended June 30,

 

Low

 

High

 

At Period End

 

Low

 

High

 

At Period End

 

2014

 

$

0.96

 

$

1.13

 

$

1.07

 

$

0.99

 

$

1.13

 

$

1.06

 

2013

 

 

0.77

 

 

0.91

 

 

0.80

 

 

0.81

 

 

0.97

 

 

0.85

 

 

The range of low and high spot butane prices per gallon at Mt. Belvieu, Texas and the prices at period end were as follows:

 

 

 

Spot Price Per Gallon

 

Three Months Ended June 30,

 

Low

 

High

 

At Period End

 

2014

 

$

1.20

 

$

1.30

 

$

1.30

 

2013

 

1.08

 

1.41

 

1.18

 

 

We believe volatility in commodity prices will continue, and our ability to adjust to and manage this volatility may impact our financial results.

 

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Retail Propane

 

Our retail propane segment sells propane, distillates, and equipment and supplies to residential, agricultural, commercial, and industrial end users. Our retail propane segment purchases the majority of its propane from our liquids segment. Our retail propane segment generates margins based on the difference between the wholesale cost of product and the selling price of the product in the retail markets. These margins fluctuate over time due to supply and demand conditions. Weather conditions have a significant impact on our sales volumes and prices, as a significant portion of our sales are to residential customers who purchase propane and distillates for home heating purposes.

 

A significant factor affecting the profitability of our retail propane segment is our ability to maintain our realized product margin on a cents per gallon basis. Product margin is the differential between our sales prices and our total product costs, including transportation and storage. Historically, we have been successful in passing on price increases to our customers. We monitor propane prices daily and adjust our retail prices to maintain expected margins by passing on the wholesale costs to our customers. We believe that volatility in commodity prices will continue, and our ability to adjust to and manage this volatility may impact our financial results.

 

In periods of significant propane price increases we have experienced, and expect to continue to experience, conservation of propane used by our customers, which could result in a decline in our sales volumes, revenues and product margins. In periods of decreasing propane costs, we have typically experienced an increase in our product margin. The retail propane business is weather-sensitive and subject to seasonal volume variations due to propane’s primary use as a heating source in residential and commercial buildings and for agricultural purposes. Typically, over 70% of our retail volume is sold during the peak heating season from October through March. Consequently, our revenues, operating profits, and operating cash flows are typically lower in the first and second quarters of each fiscal year.

 

Refined Products and Renewables

 

Our refined product marketing business purchases gasoline and diesel fuel primarily from eight suppliers and sells these products to over 300 customers. We purchase and sell these products at a nationwide network of third-party owned terminaling and storage facilities. We typically sell these products at the same time we purchase them in back-to-back transactions. This business was acquired as part of our purchase of Gavilon Energy.

 

Our ethanol marketing business purchases ethanol primarily at production facilities and transports the ethanol for sale at various locations to refiners and blenders. We also transport and market ethanol owned by other unaffiliated entities in exchange for a service fee.

 

Our biodiesel marketing business purchases biodiesel from production facilities located in the Midwest and in Houston, Texas, and transports the product on leased railcars for sale to refiners and blenders. We lease biodiesel storage at facilities located in Phoenix, Arizona and Deer Park, Texas.

 

Recent Developments

 

We have continued to expand our operations through a number of business combinations, as summarized below.

 

TransMontaigne Inc.

 

On July 1, 2014, we acquired TransMontaigne Inc. (“TransMontaigne”) for $173.8 million of cash, net of cash acquired. As part of this transaction, we also purchased $346.9 million of inventory from the previous owner of TransMontaigne. The operations of TransMontaigne include the marketing of refined products and crude oil. As part of this transaction, we acquired the general partner interest and a 19.7% limited partner interest in TransMontaigne Partners L.P. (“TLP”), a publicly-traded partnership that conducts refined product and crude oil transportation and terminaling operations.

 

On July 10, 2014, we submitted a non-binding proposal to the conflicts committee of the board of directors of TLP’s general partner. Under this proposal, each outstanding unit of TLP would be exchanged for one of our common units. This proposed

 

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transaction is subject to the negotiation and execution of a definitive agreement, the approval of the conflicts committee of the board of directors of TLP’s general partner, and any requisite unitholder approval under applicable law.

 

Investment in Grassland Water Solutions LLC

 

In June 2014, we acquired a 27.5% interest in a water supply company that expands our water solutions business in the DJ Basin in Colorado.

 

Gavilon, LLC

 

In December 2013, we acquired the ownership interests of Gavilon, LLC (“Gavilon Energy”). Gavilon Energy’s assets include crude oil terminals in Oklahoma, Texas and Louisiana, a 50% ownership interest in Glass Mountain Pipeline, LLC (“Glass Mountain”), which owns a crude oil pipeline that originates in western Oklahoma and terminates in Cushing, Oklahoma, and an 11% interest in an ethanol production facility in Nebraska. Other operations of Gavilon Energy include the marketing of crude oil, refined products, ethanol, biodiesel, and natural gas liquids and owned and leased crude oil storage in Cushing, Oklahoma.

 

Coastal Plains Disposal #1, LLC (“Coastal”)

 

In September 2013, we acquired the ownership interests in three water disposal facilities in the Eagle Ford Basin in Texas, and an option to acquire an additional facility which we exercised in March 2014.

 

Oilfield Water Lines LP (“OWL”)

 

In August 2013, we acquired the ownership interests in four water disposal facilities and a fleet of approximately 55 water transportation vehicles located in the Eagle Ford Basin in Texas.

 

High Roller Wells Big Lake SWD No. 1 Ltd. (“Big Lake”)

 

In July 2013, we acquired a water disposal facility located in the Permian Basin in Texas. As part of this transaction, we entered into a five-year development agreement that provides us with the option to operate and then purchase additional disposal facilities that may be constructed by the sellers.

 

Crescent Terminals, LLC and Cierra Marine, LP

 

In July 2013, we acquired the operating assets of Crescent Terminals, LLC (“Crescent”), which operates a leased crude oil storage and dock facility in Port Aransas, Texas. In addition, we also purchased the ownership interests of Cierra Marine, LP (“Cierra Marine”), whereby we acquired a fleet of four towboats and seven crude oil barges operating in the intercoastal waterways of Texas.

 

Summary Discussion of Operating Results for the Three Months ended June 30, 2014

 

During the three months ended June 30, 2014, we generated an operating loss of $20.6 million, compared to an operating loss of $7.3 million during the three months ended June 30, 2013.

 

Our crude oil logistics business generated operating income of $1.5 million during the three months ended June 30, 2014, compared to operating income of $6.6 million during the three months ended June 30, 2013. Spreads between the price of crude oil in different markets remained narrow, which reduced our opportunity to generate increased margins by transporting crude oil from lower-price markets to higher-price markets.

 

Our water solutions business generated an operating loss of $0.9 million during the three months ended June 30, 2014. compared to operating income of $3.0 million during the three months ended June 30, 2013. Operating income during the three months ended June 30, 2014 was reduced by $6.2 million of unrealized losses on derivatives. During the three months ended June 30, 2013, operating income was increased by $0.6 million of unrealized gains on derivatives.

 

Our liquids business generated an operating loss of $0.9 million during the three months ended June 30, 2014, compared to an operating loss of $2.1 million during the three months ended June 30, 2013. Due to the seasonal nature of demand for natural gas liquids, sales volumes of our liquids segment are typically lower during the first and second quarters of the fiscal year than during the third and fourth quarters of the fiscal year.

 

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Table of Contents

 

Our retail propane business generated an operating loss of $1.6 million during the three months ended June 30, 2014, compared to an operating loss of $1.5 million during the three months ended June 30, 2013. Due to the seasonal nature of demand for propane, sales volumes of our retail propane business typically are lower during the first and second quarters of the fiscal year than during the third and fourth quarters of the fiscal year.

 

Our refined products business generated operating income of $0.4 million during the three months ended June 30, 2014. Our refined products segment began when we acquired Gavilon Energy in December 2013.

 

Our renewables business generated an operating loss of $1.7 million during the three months ended June 30, 2014. Our renewables segment began when we acquired Gavilon Energy in December 2013. Ethanol prices decreased during May and June 2014, which had an unfavorable impact on product margins. Demand for biodiesel has been impacted by uncertainty regarding the requirements for biodiesel usage, as the United States Environmental Protection Agency (the “EPA”) has not yet issued its final mandate for 2014 usage. The low demand had an unfavorable impact on our biodiesel volumes and product margins during the three months ended June 30, 2014.

 

We recorded $2.6 million of earnings from our equity method investments, which were acquired in our December 2013 acquisition of Gavilon Energy.

 

We incurred interest expense of $20.5 million during the three months ended June 30, 2014. This was higher than interest expense of $10.6 million during the three months ended June 30, 2013, due primarily to borrowings to finance acquisitions.

 

Consolidated Results of Operations

 

The following table summarizes our historical unaudited condensed consolidated statements of operations for the periods indicated:

 

 

 

Three Months Ended June 30,

 

 

 

2014

 

2013

 

 

 

(in thousands)

 

Total revenues

 

$

3,648,614

 

$

1,385,957

 

Total cost of sales

 

3,534,053

 

1,303,076

 

Operating and general and administrative expenses

 

95,741

 

67,499

 

Depreciation and amortization

 

39,375

 

22,724

 

Operating loss

 

(20,555

)

(7,342

)

Earnings of unconsolidated entities

 

2,565

 

 

Interest expense

 

(20,494

)

(10,622

)

Other, net

 

(391

)

50

 

Loss before income taxes

 

(38,875

)

(17,914

)

Income tax (provision) benefit

 

(1,035

)

406

 

Net loss

 

(39,910

)

(17,508

)

Net income allocated to general partner

 

(9,381

)

(1,688

)

Net income attributable to noncontrolling interests

 

(65

)

(125

)

Net loss allocated to limited partners

 

$

(49,356

)

$

(19,321

)

 

See the detailed discussion of revenues, cost of sales, operating expenses, general and administrative expenses, depreciation and amortization expense and operating income by segment below. The business combination with Gavilon Energy and the acquisitions of crude oil logistics and water solutions businesses described above had a significant impact on the comparability of our results of operations during the three months ended June 30, 2014 and 2013.

 

Non-GAAP Financial Measures

 

The following table reconciles net loss attributable to parent equity to our EBITDA and Adjusted EBITDA, each of which are non-GAAP financial measures:

 

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Table of Contents

 

 

 

Three Months Ended June 30,

 

 

 

2014

 

2013

 

 

 

(in thousands)

 

Net loss attributable to parent equity

 

$

(39,975

)

$

(17,633

)

Income tax provision (benefit)

 

1,035

 

(406

)

Interest expense

 

20,517

 

10,622

 

Depreciation and amortization

 

44,350

 

23,195

 

EBITDA

 

$

25,927

 

$

15,778

 

Net unrealized losses on derivative contracts

 

5,010

 

3,578

 

Loss on disposal or impairment of assets

 

458

 

373

 

Equity-based compensation expense

 

7,914

 

7,075

 

Adjusted EBITDA

 

$

39,309

 

$

26,804

 

 

We define EBITDA as net income (loss) attributable to parent equity, plus interest expense, income taxes, and depreciation and amortization expense. We define Adjusted EBITDA as EBITDA excluding the unrealized gain or loss on derivative contracts, the gain or loss on the disposal or impairment of assets, and equity-based compensation expense. EBITDA and Adjusted EBITDA should not be considered an alternative to net income, income before income taxes, cash flows from operating activities, or any other measure of financial performance calculated in accordance with accounting principles generally accepted in the United States (“GAAP”) as those items are used to measure operating performance, liquidity or the ability to service debt obligations. We believe that EBITDA provides additional information to investors for evaluating our ability to make quarterly distributions to our unitholders and is presented solely as a supplemental measure. We believe that Adjusted EBITDA provides additional information for evaluating our financial performance without regard to our financing methods, capital structure and historical cost basis. Further, EBITDA and Adjusted EBITDA, as we define them, may not be comparable to EBITDA and Adjusted EBITDA or similarly titled measures used by other entities.

 

For purposes of our Adjusted EBITDA calculation, we make a distinction between unrealized gains and losses on derivatives and realized gains and losses on derivatives. During the period when a derivative contract is open, we record changes in the fair value of the derivative as an unrealized gain or loss. When a derivative contract is settled, we reverse the previously-recorded unrealized gain or loss and record a realized gain or loss. The realized gain or loss is equal to the amount received or paid on the contract. We acquired Gavilon Energy in December 2013. We are still in the process of developing procedures to calculate realized and unrealized gains and losses for the Gavilon Energy operations in the same way we calculate them for our other operations. Accordingly, the net unrealized losses in the table above exclude any unrealized gains and losses related to Gavilon Energy.

 

The tables below reconcile depreciation and amortization amounts per the EBITDA table above to depreciation and amortization amounts reported in our condensed consolidated statements of operations and condensed consolidated statements of cash flows:

 

 

 

Three Months Ended June 30,

 

 

 

2014

 

2013

 

 

 

(in thousands)

 

Reconciliation to condensed consolidated statements of operations:

 

 

 

 

 

Depreciation and amortization per EBITDA table

 

$

44,350

 

$

23,195

 

Intangible asset amortization recorded to cost of sales

 

(2,137

)

(625

)

Depreciation and amortization of unconsolidated entities

 

(2,945

)

 

Depreciation and amortization attributable to noncontrolling interests

 

107

 

154

 

Depreciation and amortization per condensed consolidated statements of operations

 

$

39,375

 

$

22,724

 

 

 

 

 

 

 

Reconciliation to condensed consolidated statements of cash flows:

 

 

 

 

 

Depreciation and amortization per EBITDA table

 

$

44,350

 

$

23,195

 

Amortization of debt issuance costs recorded to interest expense

 

1,912

 

1,397

 

Depreciation and amortization of unconsolidated entities

 

(2,945

)

 

Depreciation and amortization attributable to noncontrolling interests

 

107

 

154

 

Depreciation and amortization per condensed consolidated statements of cash flows

 

$

43,424

 

$

24,746

 

 

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Segment Operating Results for the Three Months Ended June 30, 2014 and 2013

 

Items Impacting the Comparability of Our Financial Results

 

Our current and future results of operations may not be comparable to our historical results of operations for the periods presented, due to business combinations. We expanded our crude oil logistics business through a number of acquisitions, including our acquisitions of Crescent and Cierra Marine in July 2013 and Gavilon Energy in December 2013. We expanded our water solutions business through several acquisitions of water disposal and transportation businesses, including Big Lake in July 2013, OWL in August 2013, and Coastal in September 2013. Our refined products and renewables businesses began with our December 2013 acquisition of Gavilon Energy. The results of operations of our liquids and retail propane segments are impacted by seasonality, primarily due to the increase in volumes sold during the peak heating season of October through March. In addition, product price fluctuations can have a significant impact on our sales volumes and revenues. For these and other reasons, our results of operations for the three months ended June 30, 2014 are not necessarily indicative of the results to be expected for the full fiscal year.

 

Volumes

 

The following table summarizes the volume of product sold and water delivered during the three months ended June 30, 2014 and 2013. Volumes shown in the following table include intersegment sales.

 

 

 

Three Months Ended June 30,

 

 

 

Segment

 

2014

 

2013

 

Change

 

 

 

(in thousands)

 

Crude oil logistics

 

 

 

 

 

 

 

Crude oil sold (barrels)

 

19,257

 

9,255

 

10,002

 

 

 

 

 

 

 

 

 

Water solutions

 

 

 

 

 

 

 

Water delivered (barrels)

 

20,935

 

10,039

 

10,896

 

 

 

 

 

 

 

 

 

Liquids

 

 

 

 

 

 

 

Propane sold (gallons)

 

199,801

 

127,419

 

72,382

 

Other products sold (gallons)

 

198,706

 

178,430

 

20,276

 

 

 

 

 

 

 

 

 

Retail propane

 

 

 

 

 

 

 

Propane sold (gallons)

 

23,591

 

23,393

 

198

 

Distillates sold (gallons)

 

5,278

 

5,104

 

174

 

 

 

 

 

 

 

 

 

Refined products

 

 

 

 

 

 

 

Refined products sold (gallons)

 

331,808

 

 

331,808

 

 

Operating Income (Loss) by Segment

 

Our operating income (loss) by segment was as follows:

 

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Three Months Ended June 30,

 

 

 

Segment

 

2014

 

2013

 

Change

 

 

 

(in thousands)

 

Crude oil logistics

 

$

1,463

 

$

6,609

 

$

(5,146

)

Water solutions

 

(907

)

3,043

 

(3,950

)

Liquids

 

(913

)

(2,115

)

1,202

 

Retail propane

 

(1,586

)

(1,504

)

(82

)

Refined products

 

447

 

 

447

 

Renewables

 

(1,702

)

 

(1,702

)

Corporate and other

 

(17,357

)

(13,375

)

(3,982

)

Operating loss

 

$

(20,555

)

$

(7,342

)

$

(13,213

)

 

Crude Oil Logistics

 

The following table summarizes the operating results of our crude oil logistics segment for the periods indicated:

 

 

 

Three Months Ended June 30,

 

Change

 

 

 

2014

 

2013

 

Gavilon Energy

 

Other

 

 

 

(in thousands)

 

Revenues:

 

 

 

 

 

 

 

 

 

Crude oil sales

 

$

1,926,944

 

$

928,534

 

$

1,071,170

 

$

(72,760

)

Crude oil transportation and other

 

12,114

 

9,935

 

 

2,179

 

Total revenues (1)

 

1,939,058

 

938,469

 

1,071,170

 

(70,581

)

Expenses:

 

 

 

 

 

 

 

 

 

Cost of sales

 

1,907,414

 

916,894

 

1,053,885

 

(63,365

)

Operating expenses

 

15,985

 

9,415

 

4,284

 

2,286

 

General and administrative expenses

 

4,465

 

867

 

3,604

 

(6

)

Depreciation and amortization expense

 

9,731

 

4,684

 

2,021

 

3,026

 

Total expenses

 

1,937,595

 

931,860

 

1,063,794

 

(58,059

)

Segment operating income

 

$

1,463

 

$

6,609

 

$

7,376

 

$

(12,522

)

 


(1)         Revenues include $9.8 million and $7.7 million of intersegment sales during the three months ended June 30, 2014 and 2013, respectively, that are eliminated in our condensed consolidated statements of operations.

 

Revenues. The operations we acquired from Gavilon Energy generated $1.1 billion of revenues during the three months ended June 30, 2014, selling 10.6 million barrels at an average price of $100.85 per barrel. Exclusive of the operations of Gavilon Energy, our crude oil logistics segment generated $855.8 million of revenue from crude oil sales during the three months ended June 30, 2014, selling 8.6 million barrels at an average price of $99.09 per barrel. During the three months ended June 30, 2013, our crude oil logistics segment generated $928.5 million of revenue from crude oil sales, selling 9.3 million barrels at an average price of $100.33 per barrel.

 

Crude oil transportation and other revenues of our crude oil logistics segment were $12.1 million during the three months ended June 30, 2014, compared to $9.9 million of crude oil transportation and other revenues during the three months ended June 30, 2013. This increase was due primarily to the Crescent and Cierra Marine acquisition in July 2013.

 

Cost of Sales. The cost of crude oil sold of the operations we acquired from Gavilon Energy was $1.1 billion, as these operations sold 10.6 million barrels at an average cost of $99.23 per barrel. Exclusive of the operations of Gavilon Energy, our cost of crude oil sold was $853.5 million during the three months ended June 30, 2014, as we sold 8.6 million barrels at an average cost of $98.83 per barrel. Our cost of sales during the three months ended June 30, 2014 was decreased by $2.4 million of net unrealized gains on derivatives. During the three months ended June 30, 2013, our cost of crude oil sold was $916.9 million, as we sold 9.3 million barrels at an average cost of $99.07 per barrel. Our cost of sales during the three months ended June 30, 2013 was decreased by $4.6 million of net unrealized gains on derivatives.

 

The most significant driver of the increase in our volumes, revenues, and cost of sales was the acquisition of Gavilon Energy in December 2013. Exclusive of these acquired operations, our volumes, revenues, and cost of sales were lower during the three months ended June 30, 2014 than during the three months ended June 30, 2013. Spreads between the price of crude oil in different markets narrowed during the three months ended June 30, 2013 and remained narrow, which reduced our opportunity to generate increased margins by transporting crude oil from lower-price markets to higher-price markets.

 

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Operating Expenses. Our crude oil logistics segment incurred $16.0 million of operating expenses during the three months ended June 30, 2014, compared to $9.4 million during the three months ended June 30, 2013. Of this increase, $4.3 million related to the operations of Gavilon Energy that we acquired in December 2013.

 

General and Administrative Expenses. Our crude oil logistics segment incurred $4.5 million of general and administrative expenses during the three months ended June 30, 2014, compared to $0.9 million of general and administrative expenses during the three months ended June 30, 2013. This increase was due to the acquisition of Gavilon Energy in December 2013. General and administrative expenses during the three months ended June 30, 2014 were increased by $2.1 million of compensation expense related to bonuses that the previous owners of Gavilon Energy granted to employees, contingent upon successful completion of the sale of the business. These bonuses will be payable in December 2014, contingent upon the continued service of the employees.

 

Depreciation and Amortization Expense. Our crude oil logistics segment incurred $9.7 million of depreciation and amortization expense during the three months ended June 30, 2014, compared to $4.7 million of depreciation and amortization expense during the three months ended June 30, 2013. Of this increase, $2.0 million related to the operations of Gavilon Energy that we acquired in December 2013. The remaining increase related primarily to other acquisitions and capital expansions.

 

Operating Income. Our crude oil logistics segment generated operating income of $1.5 million during the three months ended June 30, 2014, compared to $6.6 million of operating income during the three months ended June 30, 2013. Spreads between the prices of crude oil in different markets narrowed beginning in the three months ended June 30, 2013 and remained narrow, which reduced our opportunity to generate increased margins by transporting crude oil from lower-price markets to higher-price markets.

 

Water Solutions

 

The following table summarizes the operating results of our water solutions segment for the periods indicated:

 

 

 

Three Months Ended June 30,

 

Change

 

 

 

2014

 

2013

 

Acquisitions (1)

 

Other

 

 

 

(in thousands)

 

Revenues:

 

 

 

 

 

 

 

 

 

Water treatment and disposal

 

$

41,716

 

$

18,688

 

$

14,600

 

$

8,428

 

Water transportation

 

5,598

 

1,825

 

5,598

 

(1,825

)

Total revenues

 

47,314

 

20,513

 

20,198

 

6,603

 

Expenses:

 

 

 

 

 

 

 

 

 

Cost of sales

 

10,573

 

583

 

3,944

 

6,046

 

Operating expenses

 

19,729

 

9,007

 

9,210

 

1,512

 

General and administrative expenses

 

827

 

524

 

81

 

222

 

Depreciation and amortization expense

 

17,092

 

7,356

 

8,634

 

1,102

 

Total expenses

 

48,221

 

17,470

 

21,869

 

8,882

 

Segment operating income (loss)

 

$

(907

)

$

3,043

 

$

(1,671

)

$

(2,279

)

 


(1)         Represents the change in revenues and expenses attributable to acquisitions subsequent to March 31, 2013. The cost of sales amount shown in this column does not include unrealized derivative gains and losses, as these cannot be attributed to specific facilities.

 

Revenues. The acquisitions subsequent to March 31, 2013 generated $14.6 million of treatment and disposal revenue during the three months ended June 30, 2014, taking delivery of 7.1 million barrels of wastewater at an average revenue of $2.07 per barrel. Exclusive of the acquisitions subsequent to March 31, 2013, our water solutions segment generated $27.1 million of treatment and disposal revenue during the three months ended June 30, 2014, taking delivery of 13.8 million barrels of wastewater at an average revenue of $1.96 per barrel. During the three months ended June 30, 2013, our water solutions segment generated $18.7 million of treatment and disposal revenue, taking delivery of 10.0 million barrels of wastewater at an average revenue of $1.86 per barrel. The primary reason for the increases in revenue and water delivered were acquisitions made subsequent to March 31, 2013, including our acquisitions of Big Lake, OWL and Coastal, and to an increase in water volumes processed due to higher demand from customers.

 

In our June 2012 merger with High Sierra Energy, LP, we acquired a water transportation business with operations in Kansas and Oklahoma. In our August 2013 acquisition of OWL, we acquired a water transportation business with operations in Texas. Our water solutions segment generated $5.6 million of transportation revenues during the three months ended June 30, 2014, compared to $1.8 million of transportation revenues during the

 

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three months ended June 30, 2013. This increase was due to the acquisition of OWL. During the year ended March 31, 2014, we wound down our water transportation operations in Oklahoma, transferring certain of the assets to our business in Texas and selling the remaining assets.

 

Cost of Sales. Our cost of sales for the acquisitions subsequent to March 31, 2013 was $3.9 million during the three months ended June 30, 2014. Exclusive of the acquisitions subsequent to March 31, 2013, our cost of sales was $6.7 million during the three months ended June 30, 2014, which included $6.2 million of net unrealized losses on derivatives. We enter into derivatives in our water solutions business to protect against the risk of a decline in the market price of the hydrocarbons we expect to recover, because a portion of our revenue is generated from the sale of recovered hydrocarbons. During the three months ended June 30, 2013, our cost of sales was $0.6 million, which was decreased by $0.6 million of net unrealized gains on derivatives. In the table above, the full impact of the change in unrealized derivative gains and losses during the three months ended June 30, 2014 as compared to the three months ended June 30, 2013 is reported in the “other” column, as it is not possible to attribute these gains and losses to individual water facilities.

 

Operating Expenses. Our water solutions segment incurred $19.7 million of operating expenses during the three months ended June 30, 2014, compared to $9.0 million of operating expenses during the three months ended June 30, 2013. Of this increase, $9.2 million related to the acquisitions subsequent to March 31, 2013.

 

General and Administrative Expenses. Our water solutions segment incurred $0.8 million of general and administrative expenses during the three months ended June 30, 2014, compared to $0.5 million of general and administrative expenses during the three months ended June 30, 2013.

 

Depreciation and Amortization Expense. Our water solutions segment incurred $17.1 million of depreciation and amortization expense during the three months ended June 30, 2014, compared to $7.4 million of depreciation and amortization expense during the three months ended June 30, 2013. Of this increase, $8.6 million related to the acquisitions subsequent to March 31, 2013, which included $0.5 million of amortization expense related to trade name intangible assets. Exclusive of the acquisitions subsequent to March 31, 2013, the increase is due in part to $0.6 million of amortization expense related to trade name intangible assets. During the year ended March 31, 2014, we ceased using certain trade names and began amortizing them as finite-lived defensive assets.

 

Operating Income (Loss). The acquisitions subsequent to March 31, 2013 generated an operating loss of $1.7 million during the three months ended June 30, 2014. Exclusive of the acquisitions subsequent to March 31, 2013, our water solutions segment generated operating income of $0.8 million during the three months ended June 30, 2014. Our water solutions segment generated operating income of $3.0 million during the three months ended June 30, 2013. Operating income during the three months ended June 30, 2014 was reduced by $6.2 million of net unrealized losses on derivatives. During the three months ended June 30, 2013, operating income was increased by $0.6 million of net unrealized gains on derivatives.

 

Liquids

 

The following table summarizes the operating results of our liquids segment for the periods indicated:

 

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Three Months Ended June 30,

 

 

 

 

 

2014

 

2013

 

Change

 

 

 

(in thousands)

 

Revenues:

 

 

 

 

 

 

 

Propane sales

 

$

222,446

 

$

123,837

 

$

98,609

 

Other product sales

 

288,359

 

249,853

 

38,506

 

Other revenues

 

5,716

 

8,864

 

(3,148

)

Total revenues (1)

 

516,521

 

382,554

 

133,967

 

 

 

 

 

 

 

 

 

Expenses:

 

 

 

 

 

 

 

Cost of sales - propane

 

218,907

 

117,543

 

101,364

 

Cost of sales - other products

 

281,262

 

248,935

 

32,327

 

Cost of sales - other

 

3,181

 

5,368

 

(2,187

)

Operating expenses

 

9,065

 

8,732

 

333

 

General and administrative expenses

 

1,818

 

1,387

 

431

 

Depreciation and amortization expense

 

3,201

 

2,704

 

497

 

Total expenses

 

517,434

 

384,669

 

132,765

 

Segment operating loss

 

$

(913

)

$

(2,115

)

$

1,202

 

 


(1)         Revenues include $41.3 million and $21.5 million of intersegment sales during the three months ended June 30, 2014 and 2013, respectively, that are eliminated in our condensed consolidated statements of operations.

 

Revenues. Our liquids segment generated $222.4 million of wholesale propane sales revenue during the three months ended June 30, 2014, selling 199.8 million gallons at an average price of $1.11 per gallon. During the three months ended June 30, 2013, our liquids segment generated $123.8 million of wholesale propane sales revenue, selling 127.4 million gallons at an average price of $0.97 per gallon. The increase in volume was due to higher market demand, due in part to colder weather conditions during the previous winter.

 

Our liquids segment generated $288.4 million of other wholesale products sales revenue during the three months ended June 30, 2014, selling 198.7 million gallons at an average price of $1.45 per gallon. During the three months ended June 30, 2013, our liquids segment generated $249.9 million of other wholesale products sales revenue, selling 178.4 million gallons at an average price of $1.40 per gallon. The increase in volume was due to several factors, including higher market demand for butane to be used in gasoline blending operations, the expansion of our customer base, and an increased focus on the opportunity to more fully utilize our terminals to market butane.

 

Cost of Sales. Our cost of wholesale propane sales was $219.0 million during the three months ended June 30, 2014, as we sold 199.8 million gallons at an average cost of $1.10 per gallon. Our cost of wholesale propane sales during the three months ended June 30, 2014 was reduced by $0.2 million of net unrealized gains on derivatives. During the three months ended June 30, 2013, our cost of wholesale propane sales was $117.5 million, as we sold 127.4 million gallons at an average cost of $0.92 per gallon. Our cost of wholesale propane sales during the three months ended June 30, 2013 was increased by $1.6 million of net unrealized losses on derivatives.

 

Product margins per gallon of propane sold were lower during the three months ended June 30, 2014 than during the three months ended June 30, 2013. Propane prices were high during the recent winter due to cold weather conditions, and prices declined during February and March 2014. We use a weighted-average inventory costing method for our wholesale propane inventory, with the costing pools segregated based on the location of the inventory. During periods of declining prices, our margins are reduced, as the weighted-average costing pool includes inventory that was purchased when prices were higher.

 

One of our business strategies is to purchase and store inventory during the warmer months for sale during the winter months. We seek to lock in a margin on inventory held in storage through back-to-back purchases and sales, fixed-price forward sale commitments, and financial derivatives. We also have contracts whereby we have committed to purchase ratable volumes each month at index prices. We seek to manage the price risk associated with these contracts primarily by selling the inventory immediately after it is received. When we sell product, we record the cost of the sale at the average cost of all inventory at that location, which may include inventory stored for sale in the future. During periods of rising prices, this can result in greater margins on these sales. During periods of falling prices, this can result in negative margins on these sales.

 

Our cost of sales of other products was $281.3 million during the three months ended June 30, 2014, as we sold 198.7 million gallons at an average cost of $1.42 per gallon. Our cost of sales of other products during the three months ended June 30, 2014 was increased by $1.5 million of net unrealized losses on derivatives. During the three months ended June 30, 2013, our cost of sales of other products was $248.9 million, as we sold 178.4 million gallons at an average cost of $1.40 per gallon. Our cost of sales of other products during the three months ended June 30, 2013 was increased by $7.2 million of net unrealized losses on derivatives.

 

Operating Expenses. Our liquids segment incurred $9.1 million of operating expenses during the three months ended June 30, 2014, compared to $8.7 million of operating expenses during the three months ended June 30, 2013. This increase was due primarily to expanded operations.

 

General and Administrative Expenses. Our liquids segment incurred $1.8 million of general and administrative expenses during the three months ended June 30, 2014, compared to $1.4 million of general and administrative expenses during the three months ended June 30, 2013. This increase was due primarily to expanded operations.

 

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Depreciation and Amortization Expense. Our liquids segment incurred $3.2 million of depreciation and amortization expense during the three months ended June 30, 2014, compared to $2.7 million of depreciation and amortization expense during the three months ended June 30, 2013.

 

Operating Loss. Our liquids segment generated an operating loss of $0.9 million during the three months ended June 30, 2014, compared to an operating loss of $2.1 million during the three months ended June 30, 2013. The wholesale natural gas liquids business is weather-sensitive and subject to seasonal volume variations due to propane’s primary use as a heating source and butane’s use in gasoline blending, and sales prices and volumes are typically higher during the colder months of the year. Consequently, our revenues, operating profits, and operating cash flows are typically lower in the first and second quarters of each fiscal year.

 

Retail Propane

 

The following table summarizes the operating results of our retail propane segment for the periods indicated:

 

 

 

Three Months Ended June 30,

 

 

 

 

 

2014

 

2013

 

Change

 

 

 

(in thousands)

 

Revenues:

 

 

 

 

 

 

 

Propane sales

 

$

52,026

 

$

46,691

 

$

5,335

 

Distillate sales

 

18,695

 

17,869

 

826

 

Other revenues

 

7,181

 

7,700

 

(519

)

Total revenues

 

77,902

 

72,260

 

5,642

 

Expenses:

 

 

 

 

 

 

 

Cost of sales - propane

 

29,287

 

25,179

 

4,108

 

Cost of sales - distillates

 

16,036

 

15,244

 

792

 

Cost of sales - other

 

2,201

 

2,643

 

(442

)

Operating expenses

 

21,482

 

20,842

 

640

 

General and administrative expenses

 

2,911

 

2,616

 

295

 

Depreciation and amortization expense

 

7,571

 

7,240

 

331

 

Total expenses

 

79,488

 

73,764

 

5,724

 

Segment operating loss

 

$

(1,586

)

$

(1,504

)

$

(82

)

 

Revenues. Our retail propane segment generated revenue of $52.0 million from propane sales during the three months ended June 30, 2014, selling 23.6 million gallons at an average price of $2.21 per gallon. During the three months ended June 30, 2013, our retail propane segment generated $46.7 million of revenue from propane sales, selling 23.4 million gallons at an average price of $2.00 per gallon. The increase in average sales prices during the three months ended June 30, 2014 compared to the three months ended June 30, 2013 was due primarily to higher market demand as a result of cold weather conditions during the recent winter.

 

Our retail propane segment generated revenue of $18.7 million from distillate sales during the three months ended June 30, 2014, selling 5.3 million gallons at an average price of $3.54 per gallon. During the three months ended June 30, 2013, our retail propane segment generated $17.9 million of revenue from distillate sales, selling 5.1 million gallons at an average price of $3.50 per gallon.

 

Cost of Sales. Our cost of retail propane sales was $29.3 million during the three months ended June 30, 2014, as we sold 23.6 million gallons at an average cost of $1.24 per gallon. During the three months ended June 30, 2013, our cost of retail propane sales was $25.2 million, as we sold 23.4 million gallons at an average cost of $1.08 per gallon.

 

Our cost of distillate sales was $16.0 million during the three months ended June 30, 2014, as we sold 5.3 million gallons at an average cost of $3.04 per gallon. During the three months ended June 30, 2013, our cost of distillate sales was $15.2 million, as we sold 5.1 million gallons at an average cost of $2.99 per gallon.

 

Operating Expenses. Our retail propane segment incurred $21.5 million of operating expenses during the three months ended June 30, 2014, compared to $20.8 million of operating expenses during the three months ended June 30, 2013.

 

General and Administrative Expenses. Our retail propane segment incurred $2.9 million of general and administrative expenses during the three months ended June 30, 2014, compared to $2.6 million of general and administrative expenses during the three months ended June 30, 2013.

 

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Depreciation and Amortization Expense. Our retail propane segment incurred $7.6 million of depreciation and amortization expense during the three months ended June 30, 2014, compared to $7.2 million of depreciation and amortization expense during the three months ended June 30, 2013.

 

Operating Loss. Our retail propane segment generated an operating loss of $1.6 million during the three months ended June 30, 2014, compared to an operating loss of $1.5 million during the three months ended June 30, 2013. The retail propane business is weather-sensitive and subject to seasonal volume variations due to propane’s primary use as a heating source in residential and commercial buildings and for agricultural purposes. Typically, over 70% of our retail volume is sold during the peak heating season from October through March. Consequently, our revenues, operating profits, and operating cash flows are typically lower in the first and second quarters of each fiscal year.

 

Refined Products

 

The following table summarizes the operating results of our refined products segment during the three months ended June 30, 2014 (in thousands). Our refined products segment began with our December 2013 acquisition of Gavilon Energy.

 

Revenues

 

$

986,223

 

Expenses:

 

 

 

Cost of sales

 

983,012

 

Operating expenses

 

1,357

 

General and administrative expenses

 

1,025

 

Depreciation and amortization expense

 

382

 

Total expenses

 

985,776

 

Segment operating income

 

$

447

 

 

Revenues. Our refined products segment generated $986.2 million of revenue during the three months ended June 30, 2014, selling 331.8 million gallons at an average price of $2.97 per gallon.

 

Cost of Sales. Our cost of sales was $983.0 million during the three months ended June 30, 2014, as we sold 331.8 million gallons at an average cost of $2.96 per gallon.

 

Operating Expenses. Our refined products segment incurred $1.4 million of operating expenses during the three months ended June 30, 2014.

 

General and Administrative Expenses. Our refined products segment incurred $1.0 million of general and administrative expenses during the three months ended June 30, 2014.

 

Depreciation and Amortization Expense. Our refined products segment incurred $0.4 million of depreciation and amortization expense during the three months ended June 30, 2014.

 

Operating Income. Our refined products segment generated $0.4 million of operating income during the three months ended June 30, 2014.

 

Renewables

 

The following table summarizes the operating results of our renewables segment during the three months ended June 30, 2014 (in thousands). Our renewables segment began with our December 2013 acquisition of Gavilon Energy.

 

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Revenues

 

$

131,274

 

Expenses:

 

 

 

Cost of sales

 

131,301

 

Operating expenses

 

267

 

General and administrative expenses

 

946

 

Depreciation and amortization expense

 

462

 

Total expenses

 

132,976

 

Segment operating loss

 

$

(1,702

)

 

Revenues and Cost of Sales. Our renewables segment generated $131.3 million of revenue and cost of sales during the three months ended June 30, 2014.

 

Ethanol prices decreased during May and June 2014, which had an unfavorable impact on product margins. We use a weighted-average inventory costing method for our ethanol inventory. During periods of declining prices, our margins are reduced, as the weighted-average costing pool includes inventory that was purchased when prices were higher.

 

Demand for biodiesel has been impacted by uncertainty regarding the requirements for biodiesel usage, as the EPA has not yet issued its final mandate for 2014 usage. The low demand had an unfavorable impact on biodiesel volumes and product margins during the three months ended June 30, 2014.

 

Operating Expenses. Our renewables segment incurred $0.3 million of operating expenses during the three months ended June 30, 2014.

 

General and Administrative Expenses. Our renewables segment incurred $0.9 million of general and administrative expenses during the three months ended June 30, 2014. General and administrative expenses during the three months ended June 30, 2014 were increased by $0.3 million of compensation expense related to bonuses that the previous owners of Gavilon Energy granted to employees, contingent upon successful completion of the sale of the business. These bonuses will be payable in December 2014, contingent upon the continued service of the employees.

 

Depreciation and Amortization Expense. Our renewables segment incurred $0.5 million of depreciation and amortization expense during the three months ended June 30, 2014.

 

Operating Loss. Our renewables segment generated an operating loss of $1.7 million during the three months ended June 30, 2014.

 

Corporate and Other

 

The operating loss within “corporate and other” includes the following components:

 

 

 

Three Months Ended June 30,

 

 

 

 

2014

 

2013

 

Change

 

 

 

(in thousands)

 

Compressor leasing business

 

$

49

 

$

(62

)

$

111

 

Natural gas business

 

(252

)

 

(252

)

Equity-based compensation expense

 

(7,914

)

(7,075

)

(839

)

Acquisition expenses

 

(1,098

)

(583

)

(515

)

Other corporate expenses

 

(8,142

)

(5,655

)

(2,487

)

 

 

$

(17,357

)

$

(13,375

)

$

(3,982

)

 

We acquired the natural gas business in our December 2013 acquisition of Gavilon Energy. We subsequently wound down the natural gas business and, as of March 31, 2014, this business has no revenue-generating activity.

 

The increase in equity-based compensation is due primarily to an increase in the market value of our common units. The life-to-date expense for unvested units is adjusted based on the market value of the common units on the reporting date, which was higher at June 30, 2014 than at June 30, 2013.

 

The increase in other corporate expenses is due primarily to increases in compensation expense, due to the addition of new corporate employees to provide general and administrative services in support of the growth of our business.

 

Operating loss during the three months ended June 30, 2014 was increased by $0.3 million of compensation expense related to bonuses that the previous owners of Gavilon Energy granted to employees, contingent upon successful completion of the sale of the

 

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business. These bonuses will be payable in December 2014, contingent upon the continued service of the employees. This amount is reported within “other corporate expenses” in the table above.

 

Interest Expense

 

The largest component of interest expense during the three months ended June 30, 2014 and 2013 has been interest on our Revolving Credit Facility, the 2021 Notes, and the 2022 Notes. See Note 7 to our condensed consolidated financial statements included in this Quarterly Report for additional information on our long-term debt. The change in interest expense during the periods presented is due primarily to fluctuations in the average outstanding debt balance and the applicable interest rates, as summarized below:

 

 

 

Revolving Credit Facility

 

2021 Notes

 

2022 Notes

 

 

 

Average

 

 

 

Average

 

 

 

Average

 

 

 

 

 

Balance

 

Average

 

Balance

 

 

 

Balance

 

 

 

 

 

Outstanding

 

Interest

 

Outstanding

 

Interest

 

Outstanding

 

Interest

 

Three Months Ended June 30,

 

(in thousands)

 

Rate

 

(in thousands)

 

Rate

 

(in thousands)

 

Rate

 

2014

 

$

948,011

 

2.27

%

$

450,000

 

6.88

%

$

250,000

 

6.65

%

2013

 

469,489

 

3.66

%

 

 

250,000

 

6.65

%

 

Interest expense also includes amortization of debt issuance costs, which represented $1.9 million and $1.4 million of expense during the three months ended June 30, 2014 and 2013, respectively. Interest expense also includes letter of credit fees, interest on equipment financing notes, and accretion of interest on noninterest bearing debt obligations assumed in business combinations.

 

The increased level of debt outstanding during the three months ended June 30, 2014 is due primarily to borrowings to finance acquisitions.

 

Income Tax Provision

 

We believe that we qualify as a partnership for income tax purposes. As such, we generally do not pay United States federal income tax. Rather, each owner reports his or her share of our income or loss on his or her individual tax return.

 

We have certain taxable corporate subsidiaries in the United States and in Canada. In addition, our operations in Texas are subject to a state franchise tax that is calculated based on revenues net of cost of sales.

 

Noncontrolling Interests

 

We have certain consolidated subsidiaries in which outside parties own interests. The noncontrolling interest shown in our condensed consolidated statements of operations represents the other owners’ share of the net income of these entities.

 

Seasonality

 

Seasonality impacts our liquids and retail propane segments. A large portion of our retail propane operation is in the residential market where propane is used primarily for heating. Consequently, for these two segments, revenues, operating profits and operating cash flows are generated mostly in the third and fourth quarters of each fiscal year. See “—Liquidity, Sources of Capital and Capital Resource Activities — Cash Flows.”

 

Liquidity, Sources of Capital and Capital Resource Activities

 

Our principal sources of liquidity and capital are the cash flows from our operations and borrowings under our Revolving Credit Facility. Our cash flows from operations are discussed below.

 

Our borrowing needs vary significantly during the year due to the seasonal nature of our business. Our greatest working capital borrowing needs generally occur during the period of June through December, when we are building our natural gas liquids inventories in anticipation of the heating season. Our working capital borrowing needs generally decline during the period of January through March, when the cash flows from our retail propane and liquids segments are the greatest.

 

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Our partnership agreement requires that, within 45 days after the end of each quarter we distribute all of our available cash (as defined in our partnership agreement) to unitholders as of the record date. Available cash for any quarter, generally consists of all cash on hand at the end of that quarter less the amount of cash reserves established by our general partner, to (i) provide for the proper conduct of our business, (ii) comply with applicable law, any of our debt instruments or other agreements, and (iii) provide funds for distributions to our unitholders and to our general partner for any one or more of the next four quarters.

 

We believe that our anticipated cash flows from operations and the borrowing capacity under our Credit Agreement are sufficient to meet our liquidity needs for the next 12 months. If our plans or assumptions change or are inaccurate, or if we make acquisitions, we may need to raise additional capital. Our ability to raise additional capital, if necessary, depends on various factors and conditions, including market conditions. We cannot give any assurances that we can raise additional capital to meet these needs. Commitments or expenditures, if any, we may make toward any acquisition projects are at our discretion.

 

We continue to pursue a strategy of growth through acquisitions. We expect to consider financing future acquisitions through a variety of sources, including the use of available capacity on our Revolving Credit Facility, the issuance of equity to sellers of the businesses we acquire, private placements of common units or debt securities, and public offerings of common units or debt securities. Our ability to raise additional capital through the issuance of debt or equity securities will have a significant impact on our ability to continue to pursue our growth strategy.

 

Credit Agreement

 

On June 19, 2012, we entered into a credit agreement (as amended, the “Credit Agreement”) with a syndicate of banks. The Credit Agreement includes a revolving credit facility to fund working capital needs (the “Working Capital Facility”) and a revolving credit facility to fund acquisitions and expansion projects (the “Expansion Capital Facility,” and together with the Working Capital Facility, the “Revolving Credit Facility”). On June 12, 2014, we executed the sixth amendment to the Credit Agreement, which increased our total borrowing capacity to $2.193 billion.

 

The Working Capital Facility had a total capacity of $1,335.0 million for cash borrowings and letters of credit at June 30, 2014. At that date, we had outstanding cash borrowings of $465.5 million and outstanding letters of credit of $220.3 million on the Working Capital Facility. The Expansion Capital Facility had a total capacity of $858.0 million for cash borrowings at June 30, 2014. At that date, we had outstanding cash borrowings of $270.0 million on the Expansion Capital Facility. The capacity available under the Working Capital Facility may be limited by a “borrowing base,” as defined in the Credit Agreement, which is calculated based on the value of certain working capital items at any point in time.

 

The commitments under the Credit Agreement expire on November 5, 2018. We have the right to prepay outstanding borrowings under the Credit Agreement without incurring any penalties, and prepayments of principal may be required if we enter into certain transactions to sell assets or obtain new borrowings.

 

All borrowings under the Credit Agreement bear interest, at our option, at (i) an alternate base rate plus a margin of 0.50% to 1.50% per annum or (ii) an adjusted LIBOR rate plus a margin of 1.50% to 2.50% per annum. The applicable margin is determined based on our consolidated leverage ratio, as defined in the Credit Agreement. At June 30, 2014, all borrowings under the Credit Agreement were LIBOR borrowings with an interest rate as of June 30, 2014 of 2.16%, calculated as the LIBOR rate of 0.16% plus a margin of 2.00%. At June 30, 2014, the interest rate in effect on letters of credit was 2.00%. Commitment fees are charged at a rate ranging from 0.38% to 0.50% on any unused credit. At June 30, 2014, our outstanding borrowings and interest rates under our Revolving Credit Facility were as follows (dollars in thousands):

 

 

 

Amount

 

Rate

 

Expansion Capital Facility —

 

 

 

 

 

LIBOR borrowings

 

$

270,000

 

2.16

%

Working Capital Facility —

 

 

 

 

 

LIBOR borrowings

 

465,500

 

2.16

%

 

The Credit Agreement is secured by substantially all of our assets. The Credit Agreement specifies that our leverage ratio, as defined in the Credit Agreement, cannot exceed 4.25 to 1 at any quarter end. At June 30, 2014, our leverage ratio was approximately 3 to 1. The Credit Agreement also specifies that our interest coverage ratio, as defined in the Credit Agreement, cannot be less than 2.75 to 1 as of the last day of any fiscal quarter. At June 30, 2014, our interest coverage ratio was approximately 6 to 1.

 

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The Credit Agreement contains various customary representations, warranties, and additional covenants, including, without limitation, limitations on fundamental changes and limitations on indebtedness and liens. Our obligations under the Credit Agreement may be accelerated following certain events of default (subject to applicable cure periods), including, without limitation, (i) the failure to pay principal or interest when due, (ii) a breach by the Partnership or its subsidiaries of any material representation or warranty or any covenant made in the Credit Agreement, or (iii) certain events of bankruptcy or insolvency.

 

At June 30, 2014, we were in compliance with the covenants under the Credit Agreement.

 

2019 Notes

 

On July 9, 2014, we issued $400.0 million of 5.125% Senior Notes Due 2019 (the “2019 Notes”) in a private placement exempt from registration under the Securities Act of 1933, as amended (the “Securities Act”), pursuant to Rule 144A and Regulation S under the Securities Act. We received net proceeds of $393.5 million, after the initial purchasers’ discount of $6.0 million and estimated offering costs of $0.5 million. We used the net proceeds to reduce the outstanding balance on our Revolving Credit Facility.

 

The 2019 Notes mature on July 15, 2019. Interest is payable on January 15 and July 15 of each year. We have the right to redeem the 2019 Notes prior to the maturity date, although we would be required to pay a premium price for early redemption.

 

The Partnership and NGL Energy Finance Corp. are co-issuers of the 2019 Notes, and the obligations under the 2019 Notes are guaranteed by certain of our existing and future restricted subsidiaries that incur or guarantee indebtedness under certain of our other indebtedness, including the Revolving Credit Facility. The purchase agreement and the indenture governing the 2019 Notes contain various customary representations, warranties, and additional covenants, including, without limitation, limitations on fundamental changes and limitations on indebtedness and liens. Our obligations under the purchase agreement and the indenture may be accelerated following certain events of default (subject to applicable cure periods), including, without limitation, (i) the failure to pay principal or interest when due, (ii) experiencing an event of default on certain other debt agreements, or (iii) certain events of bankruptcy or insolvency.

 

We also entered into a registration rights agreement whereby we have committed to exchange the 2019 Notes for a new issue of notes registered under the Securities Act that has substantially identical terms to the 2019 Notes on or before July 9, 2015. If we are unable to fulfill this obligation, we would be required to pay liquidated damages to the holders of the 2019 Notes.

 

2021 Notes

 

On October 16, 2013, we issued $450.0 million of 6.875% Senior Notes Due 2021 (the “2021 Notes”) in a private placement exempt from registration under the Securities Act, pursuant to Rule 144A and Regulation S under the Securities Act. We received net proceeds of $438.4 million, after the initial purchasers’ discount of $10.1 million and offering costs of $1.5 million. We used the net proceeds to reduce the outstanding balance on our Revolving Credit Facility.

 

The 2021 Notes mature on October 15, 2021. Interest is payable on April 15 and October 15 of each year. We have the right to redeem the 2021 Notes prior to the maturity date, although we would be required to pay a premium for early redemption.

 

The Partnership and NGL Energy Finance Corp. are co-issuers of the 2021 Notes, and the obligations under the 2021 Notes are guaranteed by certain of our existing and future restricted subsidiaries that incur or guarantee indebtedness under certain of our other indebtedness, including the Revolving Credit Facility. The purchase agreement and the indenture governing the 2021 Notes contain various customary representations, warranties, and additional covenants, including, without limitation, limitations on fundamental changes and limitations on indebtedness and liens. Our obligations under the purchase agreement and the indenture may be accelerated following certain events of default (subject to applicable cure periods), including, without limitation, (i) the failure to pay principal or interest when due, (ii) experiencing an event of default on certain other debt agreements, or (iii) certain events of bankruptcy or insolvency.

 

At June 30, 2014, we were in compliance with the covenants under the purchase agreement and indenture governing the 2021 Notes.

 

We also entered into a registration rights agreement whereby we have committed to exchange the 2021 Notes for a new issue of notes registered under the Securities Act that has substantially identical terms to the 2021 Notes on or before October 16, 2014. If we are unable to fulfill this obligation, we would be required to pay liquidated damages to the holders of the 2021 Notes.

 

2022 Notes

 

On June 19, 2012, we entered into a Note Purchase Agreement (as amended, the “Note Purchase Agreement”) whereby we issued $250.0 million of Senior Notes in a private placement (the “2022 Notes”). The 2022 Notes bear interest at a fixed rate of 6.65%. Interest is payable quarterly. The 2022 Notes are required to be repaid in

 

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semi-annual installments of $25.0 million beginning on December 19, 2017 and ending on the maturity date of June 19, 2022. We have the option to prepay outstanding principal, although we would incur a prepayment penalty. The 2022 Notes are secured by substantially all of our assets and rank equal in priority with borrowings under the Credit Agreement.

 

The Note Purchase Agreement contains various customary representations, warranties, and additional covenants that, among other things, limit our ability to (subject to certain exceptions): (i) incur additional debt, (ii) pay dividends and make other restricted payments, (iii) create or permit certain liens, (iv) create or permit restrictions on the ability of certain of our subsidiaries to pay dividends or make other distributions to us, (v) enter into transactions with affiliates, (vi) enter into sale and leaseback transactions and (vii) consolidate or merge or sell all or substantially all or any portion of our assets. In addition, the Note Purchase Agreement contains substantially the same leverage ratio and interest coverage ratio requirements as our Credit Agreement, which are described above.

 

The Note Purchase Agreement provides for customary events of default that include, among other things (subject in certain cases to customary grace and cure periods): (i) nonpayment of principal or interest, (ii) breach of certain covenants contained in the Note Purchase Agreement or the 2022 Notes, (iii) failure to pay certain other indebtedness or the acceleration of certain other indebtedness prior to maturity if the total amount of such indebtedness unpaid or accelerated exceeds $10.0 million, (iv) the rendering of a judgment for the payment of money in excess of $10.0 million, (v) the failure of the Note Purchase Agreement, the 2022 Notes, or the guarantees by the subsidiary guarantors to be in full force and effect in all material respects and (vi) certain events of bankruptcy or insolvency. Generally, if an event of default occurs (subject to certain exceptions), the trustee or the holders of at least 51% in aggregate principal amount of the then outstanding 2022 Notes of any series may declare all of the 2022 Notes of such series to be due and payable immediately.

 

At June 30, 2014, we were in compliance with the covenants under the Note Purchase Agreement.

 

Revolving Credit Balances

 

The following table summarizes Revolving Credit Facility borrowings:

 

 

 

Average

 

 

 

 

 

 

 

Daily

 

Lowest

 

Highest

 

 

 

Balance

 

Balance

 

Balance

 

 

 

(in thousands)

 

Three Months Ended June 30, 2014:

 

 

 

 

 

 

 

Expansion loans

 

$

529,038

 

$

270,000

 

$

578,500

 

Working capital loans

 

418,973

 

339,500

 

500,500

 

 

 

 

 

 

 

 

 

Three Months Ended June 30, 2013:

 

 

 

 

 

 

 

Expansion loans

 

$

442,522

 

$

441,500

 

$

444,500

 

Working capital loans

 

26,967

 

 

76,000

 

 

 

 

 

 

 

 

 

 

Cash Flows

 

The following summarizes the sources (uses) of our cash flows:

 

 

 

Three Months Ended June 30,

 

Cash Flows Provided By (Used In):

 

2014

 

2013

 

 

 

(in thousands)

 

Operating activities, before changes in operating assets and liabilities

 

$

27,078

 

$

22,446

 

Changes in operating assets and liabilities

 

(17,872

)

3,087

 

 

 

 

 

 

 

Operating activities

 

$

9,206

 

$

25,533

 

 

 

 

 

 

 

Investing activities

 

(77,808

)

(45,117

)

 

 

 

 

 

 

Financing activities

 

97,841

 

12,626

 

 

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Operating Activities. The seasonality of our natural gas liquids businesses has a significant effect on our cash flows from operating activities. The changes in our operating assets and liabilities caused by the seasonality of our retail and wholesale natural gas liquids businesses also have a significant impact on our net cash flows from operating activities. Increases in natural gas liquids prices will tend to result in reduced operating cash flows due to the need to use more cash to fund increases in inventories, and price decreases tend to increase our operating cash flow due to lower cash requirements to fund increases in inventories.

 

In general, our operating cash flows are at their lowest levels during our first and second fiscal quarters, or the six months ending September 30, when we experience operating losses or lower operating income as a result of lower volumes of natural gas liquids sales and when we are building our inventory levels for the upcoming heating season. Our operating cash flows are generally greatest during our third and fourth fiscal quarters, or the six months ending March 31, when our operating income levels are highest and customers pay for natural gas liquids consumed during the heating season months. We borrow under our Revolving Credit Facility to supplement our operating cash flows as necessary during our first and second quarters.

 

Investing Activities. Our cash flows from investing activities are primarily impacted by our capital expenditures. In periods where we are engaged in significant acquisitions, we will generally realize negative cash flows in investing activities, which, depending on our cash flows from operating activities, may require us to increase the borrowings under our Revolving Credit Facility.

 

During the three months ended June 30, 2014, we paid $48.9 million for capital expenditures, which related primarily to water disposal and crude logistics assets. Of this amount, $42.4 million represented expansion capital and $6.5 million represented maintenance capital.

 

During the three months ended June 30, 2014, we paid $15.0 million to acquire an interest in a water supply company and an additional $0.9 million for a retail propane business. During the three months ended June 30, 2013, we paid $5.0 million to acquire two retail propane businesses.

 

Financing Activities. Changes in our cash flow from financing activities include advances from and repayments on our Revolving Credit Facility, to fund our operating or investing requirements. In periods where our cash flows from operating activities are reduced (such as during our first and second quarters), we may fund the cash flow deficits through our Working Capital Facility. During the three months ended June 30, 2014, we repaid $186.5 million on our Revolving Credit Facility (net of borrowings). During the three months ended June 30, 2014, we received net proceeds of $338.0 million from the sale of common units. During the three months ended June 30, 2013, we borrowed $43.0 million on our Revolving Credit Facility (net of repayments).

 

Cash flows from financing activities also include distributions paid to owners. We expect our distributions to our partners to increase in future periods under the terms of our partnership agreement. Based on the number of common and subordinated units outstanding at June 30, 2014 (exclusive of invested restricted units issued pursuant to employee and director compensation programs), if we made distributions equal to our minimum quarterly distribution of $0.3375 per unit ($1.35 annualized), total distributions would equal $29.5 million per quarter ($118.0 million per year). To the extent our cash flows from operating activities are not sufficient to finance our required distributions, we may be required to increase the borrowings under our Working Capital Facility.

 

The following table summarizes the distributions declared since our initial public offering:

 

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Amount

 

Amount Paid To

 

Amount Paid To

 

Date Declared

 

Record Date

 

Date Paid

 

Per Unit

 

Limited Partners

 

General Partner

 

 

 

 

 

 

 

 

 

(in thousands)

 

(in thousands)

 

July 25, 2011

 

August 3, 2011

 

August 12, 2011

 

$

0.1669

 

$

2,467

 

$

3

 

October 21, 2011

 

October 31, 2011

 

November 14, 2011

 

0.3375

 

4,990

 

5

 

January 24, 2012

 

February 3, 2012

 

February 14, 2012

 

0.3500

 

7,735

 

10

 

April 18, 2012

 

April 30, 2012

 

May 15, 2012

 

0.3625

 

9,165

 

10

 

July 24, 2012

 

August 3, 2012

 

August 14, 2012

 

0.4125

 

13,574

 

134

 

October 17, 2012

 

October 29, 2012

 

November 14, 2012

 

0.4500

 

22,846

 

707

 

January 24, 2013

 

February 4, 2013

 

February 14, 2013

 

0.4625

 

24,245

 

927

 

April 25, 2013

 

May 6, 2013

 

May 15, 2013

 

0.4775

 

25,605

 

1,189

 

July 25, 2013

 

August 5, 2013

 

August 14, 2013

 

0.4938

 

31,725

 

1,739

 

October 23, 2013

 

November 4, 2013

 

November 14, 2013

 

0.5113

 

35,908

 

2,491

 

January 23, 2014

 

February 4, 2014

 

February 14, 2014

 

0.5313

 

42,150

 

4,283

 

April 24, 2014

 

May 5, 2014

 

May 15, 2014

 

0.5513

 

43,737

 

5,754

 

July 24, 2014

 

August 4, 2014

 

August 14, 2014

 

0.5888

 

52,036

 

9,481

 

 

Contractual Obligations

 

The following table summarizes our contractual obligations at June 30, 2014 for our fiscal years ending thereafter:

 

 

 

 

 

Nine Months

 

 

 

 

 

 

 

 

 

 

 

 

 

Ending

 

 

 

 

 

 

 

 

 

 

 

 

 

March 31,

 

Years Ending March 31,

 

 

 

 

Total

 

2015

 

2016

 

2017

 

2018

 

Thereafter

 

 

 

(in thousands)

 

Principal payments on long-term debt:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Expansion capital borrowings

 

$

 

270,000

 

$

 

 

$

 

 

$

 

 

$

 

$

270,000

 

Working capital borrowings

 

465,500

 

 

 

 

 

465,500

 

2021 Notes

 

450,000

 

 

 

 

 

450,000

 

2022 Notes

 

250,000

 

 

 

 

25,000

 

225,000

 

Other long-term debt

 

12,543

 

4,696

 

3,640

 

2,376

 

1,413

 

418

 

Interest payments on long-term debt:

 

 

 

 

 

 

 

 

 

 

 

 

 

Revolving credit facility (1)

 

108,446

 

18,698

 

24,930

 

24,930

 

24,930

 

14,958

 

2021 Notes

 

232,031

 

15,469

 

30,938

 

30,938

 

30,938

 

123,748

 

2022 Notes

 

95,594

 

12,469

 

16,625

 

16,625

 

16,209

 

33,666

 

Other long-term debt

 

684

 

257

 

206

 

119

 

78

 

24

 

Letters of credit

 

220,323

 

 

 

 

 

220,323

 

Future minimum lease payments under other noncancelable operating leases

 

424,222

 

95,506

 

89,761

 

70,821

 

56,960

 

111,174

 

Future minimum throughput payments under noncancelable agreements (2)

 

440,476

 

39,237

 

82,293

 

82,293

 

82,293

 

154,360

 

Fixed-priced commodity purchase commitments

 

59,367

 

59,367

 

 

 

 

 

Index-priced commodity purchase commitments (3)

 

1,192,304

 

1,149,674

 

42,630

 

 

 

 

Total contractual obligations

 

$

 

4,221,490

 

$

 

1,395,373

 

$

 

291,023

 

$

 

228,102

 

$

237,821

 

$

2,069,171

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Natural gas liquids gallons under fixed-priced purchase commitments (thousands) (4)

 

48,959

 

48,959

 

 

 

 

 

Natural gas liquids gallons under index-priced purchase commitments (thousands) (4)

 

709,787

 

701,546

 

8,241

 

 

 

 

Crude oil barrels under index-priced purchase commitments (thousands) (4)

 

3,711

 

3,354

 

357

 

 

 

 

 

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(1)         The estimated interest payments on our Revolving Credit Facility are based on principal and letters of credit outstanding at June 30, 2014. See Note 7 to our condensed consolidated financial statements included in this Quarterly Report for additional information on our Credit Agreement.

(2)         At June 30, 2014, we had agreements with crude oil pipeline operators obligating us to minimum throughput payments in exchange for pipeline capacity commitments.

(3)         Index prices are based on a forward price curve at June 30, 2014. A theoretical change of $0.10 per gallon in the underlying commodity price at June 30, 2014 would result in a change of $71.0 million in the value of our index-based natural gas liquids purchase commitments. A theoretical change of $1.00 per barrel in the underlying commodity price at June 30, 2014 would result in a change of $3.7 million in the value of our index-based crude oil purchase commitments.

(4)         At June 30, 2014, we had fixed-priced and index-priced sales contracts for 171.6 million and 436.1 million gallons of natural gas liquids, respectively. At June 30, 2014, we had index-priced sales contracts for 1.8 million barrels of crude oil.

 

Off-Balance Sheet Arrangements

 

We do not have any off balance sheet arrangements other than the operating leases described in Note 9 to our condensed consolidated financial statements included in this Quarterly Report.

 

Environmental Legislation

 

Please see our Annual Report on Form 10-K for the fiscal year ended March 31, 2014 for a discussion of proposed environmental legislation and regulations that, if enacted, could result in increased compliance and operating costs. However, at this time we cannot predict the structure or outcome of any future legislation or regulations or the eventual cost we could incur in compliance.

 

Trends

 

Crude Oil Logistics

 

Crude oil prices fluctuate widely due to changes in supply and demand conditions. The opportunity to generate revenues in our crude oil logistics business is heavily influenced by the volume of crude oil being produced. Currently, production of crude oil in North America is increasing, but changes in the level of production could impact our ability to generate revenues in the future.

 

The spread between the prices of crude oil in different locations can also fluctuate widely. If these price differences are wide, we are able to generate increased margins by transporting crude oil from lower-price markets to higher-price markets. During the three months ended June 30, 2013, spreads narrowed considerably, which had a significant impact on our operations in the Rocky Mountain and South Texas regions, where these spreads remain narrow. When price differences between markets are reduced, it is necessary to renegotiate price terms with producers and to not fully utilize our transportation fleet until this process has been completed and margins have improved.

 

Water Solutions

 

Our opportunity to earn revenues in our water solutions business is based on the level of production of natural gas and crude oil in the areas where our facilities are located. Currently, production levels are increasing, and we are expanding our operations in Colorado and Texas to meet this demand.

 

Liquids

 

The volumes we sell in our wholesale natural gas liquids business are heavily dependent on the demand for propane and butane, which is influenced by weather conditions and gasoline blending. The margins we generate in our wholesale natural gas liquids business are influenced by changes in prices over the course of a year. During years when demand is higher during the winter months, we have the opportunity to utilize our storage assets to increase margins.

 

Demand for natural gas liquids was high during the recent winter, due to cold weather conditions. Demand continued to be high during the three months ended June 30, 2014, as customers sought to replenish their supplies of natural gas liquids that had been depleted during the winter. As a result, sales volumes and prices were higher during the three months ended June 30, 2014 than during the corresponding period in the prior year. However, our product margin per gallon sold was lower during the three months ended June 30, 2014 than during the corresponding period in the prior year, as we began the year with inventory that had a high cost basis as a result of the high demand during the previous winter.

 

We use a weighted-average inventory costing method for our wholesale propane inventory, with the costing pools segregated based on the location of the inventory. During periods of declining prices, our margins are reduced, as the weighted-average costing pool includes inventory that was purchased when prices were higher.

 

One of our business strategies is to purchase and store inventory during the warmer months for sale during the winter months. We seek to lock in a margin on inventory held in storage through back-to-back purchases and sales, fixed-price forward sale commitments, and financial derivatives. We also have contracts whereby we have committed to purchase ratable volumes each month at index prices. We seek to manage the price risk associated with these contracts primarily by selling the inventory immediately after it is received. When we sell product, we record the cost of the sale at the average cost of all inventory at that location, which may include inventory stored for sale in the future. During periods of rising prices, this can result in greater margins on these sales. During periods of falling prices, this can result in negative margins on these sales.

 

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Retail Propane

 

The volumes we sell in our retail propane business are dependent on weather conditions, as cold weather significantly increases customer demand for propane. During times of lower propane prices, margins per gallon typically increase. During times of higher propane prices, margins per gallon typically decrease.

 

Refined Products and Renewables

 

The spread between the prices of ethanol in different locations can fluctuate widely. If these price differences are high, we are able to generate increased margins by transporting ethanol from lower-price markets to higher-price markets. During the three months ended June 30, 2014, the spread between ethanol prices in different markets narrowed, which reduced our opportunities to generate favorable margins by transporting ethanol from one region to another.

 

Demand for biodiesel is driven in part by EPA mandates for the volume of biodiesel that refiners and blenders must use. The EPA has not yet issued its final mandate for 2014 biodiesel usage. The current uncertainty regarding the requirements has reduced the demand for biodiesel, which has had an adverse impact on biodiesel prices and volumes.

 

Recent Accounting Pronouncements

 

In May 2014, the Financial Accounting Standard Board issued Accounting Standards Update (“ASU”) No. 2014-09, “Revenue from Contracts with Customers.” ASU No. 2014-09 will replace most existing revenue recognition guidance in GAAP. The core principle of this ASU is that an entity should recognize revenue for the transfer of goods or services equal to the amount that it expects to be entitled to receive for those goods or services. The ASU is effective for the Partnership beginning April 1, 2017, and allows for both retrospective and prospective methods of adoption. We are in the process of determining the method of adoption and assessing the impact of this ASU on our consolidated financial statements.

 

Critical Accounting Policies

 

The preparation of financial statements and related disclosures in compliance with GAAP requires the selection and application of appropriate accounting principles to the relevant facts and circumstances of the Partnership’s operations and the use of estimates made by management. We have identified the following accounting policies that are most important to the portrayal of our financial condition and results of operations. The application of these accounting policies necessarily requires subjective or complex judgments regarding estimates and projected outcomes of future events that could have a material effect on our financial statements. Changes in these policies could have a material effect on the financial statements.

 

Revenue Recognition

 

We record revenues from product sales at the time title to the product transfers to the purchaser, which typically occurs upon receipt of the product by the purchaser. We record terminaling, storage, and service revenues at the time the service is performed, and we record tank and other rentals over the term of the lease. Revenues for our water solutions business are recognized upon receipt of the wastewater at our disposal facilities.

 

We report taxes collected from customers and remitted to taxing authorities, such as sales and use taxes, on a net basis. Amounts billed to customers for shipping and handling costs are included in revenues in our condensed consolidated statements of operations.

 

We enter into certain contracts whereby we agree to purchase product from a counterparty and to sell the same volume of product to the same counterparty at a different location or time. When such agreements are entered into concurrently and are entered into in contemplation of each other, we record the revenues for these transactions net of cost of sales.

 

Impairment of Long-Lived Assets

 

Goodwill is subject to at least an annual assessment for impairment. We perform our annual assessment of impairment during the fourth quarter of our fiscal year, and more frequently if circumstances warrant. To perform this assessment, we consider qualitative factors to determine whether it is more likely than not that the fair value of each reporting unit exceeds its carrying amount. We completed the assessment of each of our reporting units and determined it was more likely than not that no impairment existed for the year ended March 31, 2014. The assessment of the value of our reporting units requires us to make certain assumptions relating to future operations. When evaluating operating performance, various factors are considered, such as current and changing economic conditions and the commodity price environment, among others. If the growth assumptions embodied in the current year impairment testing prove inaccurate, we could incur an impairment charge.

 

We evaluate property, plant and equipment and amortizable intangible assets for potential impairment when events and circumstances warrant such a review. A long-lived asset group is considered impaired when the anticipated undiscounted future cash flows from the use and eventual disposition of the asset group is less than its carrying value.

 

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We evaluate equity method investments for impairment when we believe the current fair value may be less than the carrying amount. We record impairments of equity method investments if we believe the decline in value is other than temporary.

 

Asset Retirement Obligations

 

We are required to recognize the fair value of a liability for an asset retirement obligation if a reasonable estimate of fair value can be made. In order to determine the fair value of such a liability, we must make certain estimates and assumptions including, among other things, projected cash flows, the estimated timing of retirement, a credit-adjusted risk-free interest rate, and an assessment of market conditions, which could significantly impact the estimated fair value of the asset retirement obligation. These estimates and assumptions are very subjective and can vary over time. We have recorded a liability of $2.3 million at June 30, 2014. This liability is related to wastewater disposal facilities and crude oil facilities for which we have contractual and regulatory obligations to perform remediation and, in some instances, dismantlement and removal activities when the assets are retired.

 

In addition to the obligations described above, we may be obligated to remove facilities or perform other remediation upon retirement of certain other assets. We do not believe the present value of these asset retirement obligations, under current laws and regulations, after taking into consideration the estimated lives of our facilities, is material to our consolidated financial position or results of operations.

 

Depreciation Methods and Estimated Useful Lives of Property, Plant and Equipment

 

Depreciation expense represents the systematic write-off of the cost of our property, plant and equipment, net of residual or salvage value (if any), to the results of operations for the quarterly and annual periods during which the assets are used. We depreciate the majority of our property, plant and equipment using the straight-line method, which results in our recording depreciation expense evenly over the estimated life of the individual asset. The estimate of depreciation expense requires us to make assumptions regarding the useful economic lives and residual values of our assets. At the time we acquire and place our property, plant and equipment in service, we develop assumptions about the lives and residual values of such assets that we believe to be reasonable; however, circumstances may develop that could require us to change these assumptions in future periods, which would change our depreciation expense prospectively. Examples of such circumstances include changes in laws and regulations that limit the estimated economic life of an asset, changes in technology that render an asset obsolete, or changes in expected salvage values.

 

Amortization of Intangible Assets

 

Amortization expense represents the systematic write-off of the cost of our amortizable intangible assets to the results of operations for the quarterly and annual periods during which the assets are used. We amortize the majority of these intangible assets using the straight-line method, which results in our recording amortization expense evenly over the estimated life of the individual asset. The estimate of amortization expense requires us to make assumptions regarding the useful economic lives of our assets. At the time we acquire intangible assets, we develop assumptions about the lives of such assets that we believe to be reasonable; however, circumstances may develop that could require us to change these assumptions in future periods, which would change our amortization expense prospectively. Examples of such circumstances include changes in customer attrition rates and changes in laws and regulations that could limit the estimated economic life of an asset.

 

Business Combinations

 

We have made in the past, and expect to make in the future, acquisitions of other businesses. We record business combinations using the “acquisition method,” in which the assets acquired and liabilities assumed are recorded at their estimated fair values. Fair values of assets acquired and liabilities assumed are based upon available information and may involve us engaging an independent third party to perform an appraisal. Estimating fair values can be complex and subject to significant business judgment. We must also identify and include in the allocation all acquired tangible and intangible assets that meet certain criteria, including assets that were not previously recorded by the acquired entity. The estimates most commonly involve property, plant and equipment and intangible assets, including those with indefinite lives. The estimates also include the fair value of contracts including commodity purchase and sale agreements, storage and transportation contracts, and employee compensation commitments. The excess of the purchase price over the net fair value of acquired assets over the assumed liabilities is recorded as goodwill, which is not amortized but is reviewed annually for impairment. Generally, we have up to one year from the acquisition date to finalize the identification and valuation of assets acquired and liabilities assumed. The impact of subsequent changes to the identification of assets and liabilities may require retrospective adjustments to our previously-reported consolidated financial position and results of operations.

 

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Inventory

 

Our inventory consists primarily of crude oil, natural gas liquids, refined products, ethanol, and biodiesel. The market values of these commodities change on a daily basis as supply and demand conditions change. We value our inventory using the weighted-average cost and first in, first out methods. At the end of each fiscal year, we also perform a “lower of cost or market” analysis; if the cost basis of the inventory would not be recoverable based on market prices at the end of the year, we reduce the book value of the inventory to the recoverable amount. In performing this analysis, we take into consideration fixed-price forward sale commitments and the opportunity to transfer propane inventory from our wholesale business to our retail business to sell the inventory in retail markets. When performing this analysis during interim periods within a fiscal year, accounting standards do not require us to record a lower of cost or market write-down if we expect the market values to recover by our fiscal year end of March 31. We are unable to control changes in the market value of these commodities and are unable to determine whether write-downs will be required in future periods. In addition, write-downs at interim periods could be required if we cannot conclude that market values will recover sufficiently by our fiscal year end.

 

Equity-Based Compensation

 

Our general partner has granted certain restricted units to employees and directors under a long-term incentive plan. These units vest in tranches, subject to the continued service of the recipients.

 

We record the expense for the first tranche of each award on a straight-line basis over the period beginning with the grant date of the awards and ending with the vesting date of the tranche. We record the expense for succeeding tranches over the period beginning with the vesting date of the previous tranche and ending with the vesting date of the tranche.

 

At each balance sheet date, we adjust the cumulative expense recorded using the estimated fair value of the awards at the balance sheet date. We calculate the fair value of the awards using the closing price of our common units on the New York Stock Exchange on the balance sheet date, adjusted to reflect the fact that the holders of the unvested units are not entitled to distributions during the vesting period. We estimate the impact of the lack of distribution rights during the vesting period using the value of the most recent distribution and assumptions that a market participant might make about future distribution growth.

 

We report unvested units as liabilities on our condensed consolidated balance sheets. When units vest and are issued, we record an increase to equity.

 

Item 3.                  Quantitative and Qualitative Disclosures About Market Risk

 

Interest Rate Risk

 

At June 30, 2014, a significant portion of our long-term debt is variable-rate debt. Changes in interest rates impact the interest payments of our variable-rate debt but generally do not impact the fair value of the liability. Conversely, changes in interest rates impact the fair value of the fixed-rate debt but do not impact its cash flows.

 

Our Revolving Credit Facility is variable-rate debt with interest rates that are generally indexed to bank prime or LIBOR interest rates. At June 30, 2014, we had $735.5 million of outstanding borrowings under our Revolving Credit Facility at a rate of 2.16%. A change in interest rates of 0.125% would result in an increase or decrease of our annual interest expense of $0.9 million on the $735.5 million of outstanding borrowings under the Revolving Credit Facility at June 30, 2014.

 

Commodity Price and Credit Risk

 

Our operations are subject to certain business risks, including commodity price risk and credit risk. Commodity price risk is the risk that the market value of crude oil, propane, and other natural gas liquids will change, either favorably or unfavorably, in response to changing market conditions. Credit risk is the risk of loss from nonperformance by suppliers, customers or financial counterparties to a contract.

 

As is customary in the crude oil industry, we generally receive payment from customers for sales of crude oil on a monthly basis. As a result, receivables from individual customers in our crude oil logistics segment are generally higher than the receivables from customers in our other segments.

 

Procedures and limits for managing commodity price risks and credit risks are specified in our market risk policy and credit risk policy, respectively. Open commodity positions and market price changes are monitored daily and are reported to senior management and to marketing operations personnel. We attempt to minimize credit risk exposure through credit policies and periodic monitoring procedures as well as through customer deposits, restrictions on product liftings, letters of credit and entering into netting agreements that allow for offsetting counterparty receivable and payable balances for certain transactions, as deemed appropriate. The

 

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principal counterparties associated with our operations at June 30, 2014 were retailers, resellers, energy marketers, producers, refiners and dealers.

 

The natural gas liquids and crude oil industries are “margin-based” and “cost-plus” businesses in which gross profits depend on the differential of sales prices over supply costs. As a result, our profitability may be impacted by changes in wholesale prices of natural gas liquids and crude oil. When there are sudden and sharp increases in the wholesale cost of natural gas liquids and crude oil, we may not be able to pass on these increases to our customers through retail or wholesale prices. Natural gas liquids and crude oil are commodities and the price we pay for them can fluctuate significantly in response to supply or other market conditions. We have no control over supply or market conditions. In addition, the timing of cost increases can significantly affect our realized margins. Sudden and extended wholesale price increases could reduce our gross margins and could, if continued over an extended period of time, reduce demand by encouraging end users to conserve or convert to alternative energy sources.

 

We engage in derivative financial and other risk management transactions, including various types of forward contracts and financial derivatives, to reduce the effect of price volatility on our product costs, protect the value of our inventory positions, and to help ensure the availability of product during periods of short supply. We attempt to balance our contractual portfolio by purchasing volumes when we have a matching purchase commitment from our wholesale and retail customers. We may experience net unbalanced positions from time to time. In addition to our ongoing policy to maintain a balanced position, for accounting purposes we are required, on an ongoing basis, to track and report the market value of our derivative portfolio.

 

Although we use derivative commodity instruments to reduce the market price risk associated with forecasted transactions, we have not accounted for such derivative commodity instruments as hedges. We record the changes in fair value of these derivative commodity instruments within cost of sales. The following table summarizes the hypothetical impact on the fair value of our commodity derivatives of an increase of 10% in the value of the underlying commodity (in thousands):

 

 

 

Increase

 

 

 

(Decrease)

 

 

 

To Fair Value

 

Crude oil (crude oil logistics segment)

 

$

(9,710

)

Crude oil (water solutions segment)

 

(10,586

)

Propane (liquids segment)

 

3,977

 

Other products (liquids segment)

 

(3,448

)

Refined products (refined products segment)

 

(2,323

)

Renewables (renewables segment)

 

431

 

 

Fair Value

 

We use observable market values for determining the fair value of our derivative instruments. In cases where actively quoted prices are not available, other external sources are used which incorporate information about commodity prices in actively quoted markets, quoted prices in less active markets and other market fundamental analysis.

 

Item 4.                   Controls and Procedures

 

We maintain disclosure controls and procedures, as defined in Rules 13(a)-15(e) and 15(d)-15(e) of the Securities Exchange Act of 1934, as amended (the “Exchange Act”), that are designed to provide reasonable assurance that information required to be disclosed in our filings and submissions under the Exchange Act is recorded, processed, summarized and reported within the periods specified in the rules and forms of the SEC and that such information is accumulated and communicated to our management, including our principal executive officer and principal financial officer of our general partner, as appropriate, to allow timely decisions regarding required disclosure.

 

We completed an evaluation under the supervision and with participation of our management, including the principal executive officer and principal financial officer of our general partner, of the effectiveness of the design and operation of our disclosure controls and procedures at June 30, 2014. Based on this evaluation, the principal executive officer and principal financial officer of our general partner have concluded that as of June 30, 2014, such disclosure controls and procedures were effective to provide the reasonable assurance described above.

 

Other than changes that have resulted or may result from our acquisition of Gavilon Energy, as discussed below, there have been no changes in our internal controls over financial reporting (as defined in Rule 13(a)—15(f) of the Exchange Act) during the

 

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three months ended June 30, 2014 that have materially affected, or are reasonably likely to materially affect, our internal controls over financial reporting.

 

We acquired Gavilon Energy in December 2013, and TransMontaigne in July 2014, as described in Notes 4 and 15 to our condensed consolidated financial statements included in this Quarterly Report. At this time, we continue to evaluate the business and internal controls and processes of these acquired businesses and are making various changes to their operating and organizational structures based on our business plan. We are in the process of implementing our internal control structure over these acquired businesses. We expect that our evaluation and integration efforts related to those operations will continue into future fiscal quarters.

 

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PART II

 

Item 1.                   Legal Proceedings

 

For information related to legal proceedings, please see the discussion under the captions “Legal Contingencies” and “Customer Dispute” in Note 9 to our unaudited condensed consolidated financial statements in Part I, Item I, of this Quarterly Report, which information is incorporated by reference into this Item 1.

 

Item 1A.          Risk Factors

 

Set forth below is a risk factor that is relevant to the operations of TransMontaigne Partners L.P. We acquired the general partner interest and certain limited partner interests in TransMontaigne Partners L.P. in July 2014. Except as set forth below, there have been no material changes from the risk factors previously disclosed in “Item 1A — Risk Factors” in our Annual Report on Form 10-K for the fiscal year ended March 31, 2014.

 

Although we control TransMontaigne Partners L.P. (“TLP”) through our ownership of its general partner, TLP’s general partner owes fiduciary duties to TLP’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 TLP and its limited partners, on the other hand. The directors and officers of TLP’s general partner have fiduciary duties to manage TLP in a manner beneficial to us. At the same time, TLP’s general partner has fiduciary duties to manage TLP in a manner beneficial to TLP and its limited partners. The board of directors of TLP’s general partner will resolve any such conflict 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.

 

For example, conflicts of interest with TLP may arise in the following situations:

 

·                  the interpretation and enforcement of contractual obligations between us and our affiliates, on the one hand, and TLP, on the other hand;

 

·                  the determination of the amount of cash to be distributed to TLP’s limited partners and the amount of cash to be reserved for the future conduct of TLP’s business; and

 

·                  the determination whether to make borrowings under TLP’s revolving credit facility to pay distributions to its limited partners.

 

Item 2.         Unregistered Sales of Equity Securities and Use of Proceeds

 

None.

 

Item 3.         Defaults Upon Senior Securities

 

Not applicable.

 

Item 4.         Mine Safety Disclosures

 

Not applicable.

 

Item 5.         Other Information

 

None.

 

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Item 6.         Exhibits

 

Exhibit
Number

 

 

Exhibit

 

 

 

 

 

3.1

 

 

Amendment No. 2 to Third Amended and Restated Limited Liability Company Agreement of NGL Energy Holdings LLC, dated as of June 27, 2014 (incorporated by reference to Exhibit 3.1 to the Current Report on Form 8-K (File No. 001-35172) filed on July 3, 2014)

 

4.1

 

 

Amendment No. 6 to Note Purchase Agreement, dated as of June 30, 2014, among the Partnership and the purchasers named therein (incorporated by reference to Exhibit 4.1 to the Current Report on Form 8-K (File No. 001-35172) filed on July 3, 2014)

 

10.1

 

 

Amendment No. 6 to Credit Agreement, dated as of June 12, 2014, among NGL Energy Operating LLC, the Partnership, the subsidiary borrowers party thereto, Deutsche Bank Trust Company Americas and the other financial institutions party thereto (incorporated by reference to Exhibit 10.1 to the Current Report on Form 8-K (File No. 001-35172) filed on June 16, 2014)

 

10.2

 

 

Amendment No. 7 to Credit Agreement, dated as of June 27, 2014, among NGL Energy Operating LLC, the Partnership, the subsidiary borrowers party thereto, Deutsche Bank Trust Company Americas and the other financial institutions party thereto (incorporated by reference to Exhibit 10.1 to the Current Report on Form 8-K (File No. 001-35172) filed on July 3, 2014)

 

12.1

*

 

Ratios of earnings to fixed charges

 

31.1

*

 

Certification of Chief Executive Officer pursuant to Section 302 of the Sarbanes — Oxley Act of 2002

 

31.2

*

 

Certification of Chief Financial Officer pursuant to Section 302 of the Sarbanes — Oxley Act of 2002

 

32.1

*

 

Certification of Chief Executive Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes — Oxley Act of 2002

 

32.2

*

 

Certification of Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes — Oxley Act of 2002

 

101.INS

**

 

XBRL Instance Document

 

101.SCH

**

 

XBRL Schema Document

 

101.CAL

**

 

XBRL Calculation Linkbase Document

 

101.DEF

**

 

XBRL Definition Linkbase Document

 

101.LAB

**

 

XBRL Label Linkbase Document

 

101.PRE

**

 

XBRL Presentation Linkbase Document

 


 

 

*

 

Exhibits filed with this report.

 

 

 

 

 

 

 

**

 

Attached as Exhibit 101 to this report are the following documents formatted in XBRL (Extensible Business Reporting Language): (i) Condensed Consolidated Balance Sheets at June 30, 2014 and March 31, 2014, (ii) Condensed Consolidated Statements of Operations for the three months ended June 30, 2014 and 2013, (iii) Condensed Consolidated Statements of Comprehensive Loss for the three months ended June 30, 2014 and 2013, (iv) Condensed Consolidated Statement of Changes in Equity for the three months ended June 30, 2014, (v) Condensed Consolidated Statements of Cash Flows for the three months ended June 30, 2014 and 2013, and (vi) Notes to Condensed Consolidated Financial Statements.

 

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SIGNATURES

 

Pursuant to the requirements of the Securities Exchange Act of 1934, as amended, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

 

 

NGL ENERGY PARTNERS LP

 

 

 

By:

NGL Energy Holdings LLC, its general partner

 

 

 

 

Date: August 11, 2014

 

By:

/s/ H. Michael Krimbill

 

 

 

H. Michael Krimbill

 

 

 

Chief Executive Officer

 

 

 

 

Date: August 11, 2014

 

By:

/s/ Atanas Atanasov

 

 

 

Atanas H. Atanasov

 

 

 

Chief Financial Officer

 

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EXHIBIT INDEX

 

Exhibit
Number

 

Exhibit

 

 

 

 

 

3.

1

 

 

Amendment No. 2 to Third Amended and Restated Limited Liability Company Agreement of NGL Energy Holdings LLC, dated as of June 27, 2014 (incorporated by reference to Exhibit 3.1 to the Current Report on Form 8-K (File No. 001-35172) filed on July 3, 2014)

4.

1

 

 

Amendment No. 6 to Note Purchase Agreement, dated as of June 30, 2014, among the Partnership and the purchasers named therein (incorporated by reference to Exhibit 4.1 to the Current Report on Form 8-K (File No. 001-35172) filed on July 3, 2014)

10.

1

 

 

Amendment No. 6 to Credit Agreement, dated as of June 12, 2014, among NGL Energy Operating LLC, the Partnership, the subsidiary borrowers party thereto, Deutsche Bank Trust Company Americas and the other financial institutions party thereto (incorporated by reference to Exhibit 10.1 to the Current Report on Form 8-K (File No. 001-35172) filed on June 16, 2014)

10.

2

 

 

Amendment No. 7 to Credit Agreement, dated as of June 27, 2014, among NGL Energy Operating LLC, the Partnership, the subsidiary borrowers party thereto, Deutsche Bank Trust Company Americas and the other financial institutions party thereto (incorporated by reference to Exhibit 10.1 to the Current Report on Form 8-K (File No. 001-35172) filed on July 3, 2014)

12.

1

*

 

Ratios of earnings to fixed charges

31.

1

*

 

Certification of Chief Executive Officer pursuant to Section 302 of the Sarbanes — Oxley Act of 2002

31.

2

*

 

Certification of Chief Financial Officer pursuant to Section 302 of the Sarbanes — Oxley Act of 2002

32.

1

*

 

Certification of Chief Executive Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes — Oxley Act of 2002

32.

2

*

 

Certification of Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes — Oxley Act of 2002

101.

INS

**

 

XBRL Instance Document

101.

SCH

**

 

XBRL Schema Document

101.

CAL

**

 

XBRL Calculation Linkbase Document

101.

DEF

**

 

XBRL Definition Linkbase Document

101.

LAB

**

 

XBRL Label Linkbase Document

101.

PRE

**

 

XBRL Presentation Linkbase Document

 


 

 

*

 

Exhibits filed with this report.

 

 

 

 

 

 

 

**

 

Attached as Exhibit 101 to this report are the following documents formatted in XBRL (Extensible Business Reporting Language): (i) Condensed Consolidated Balance Sheets at June 30, 2014 and March 31, 2014, (ii) Condensed Consolidated Statements of Operations for the three months ended June 30, 2014 and 2013, (iii) Condensed Consolidated Statements of Comprehensive Loss for the three months ended June 30, 2014 and 2013, (iv) Condensed Consolidated Statement of Changes in Equity for the three months ended June 30, 2014, (v) Condensed Consolidated Statements of Cash Flows for the three months ended June 30, 2014 and 2013, and (vi) Notes to Condensed Consolidated Financial Statements.

 

71