AMERICAN MIDSTREAM PARTNERS, LP, 10-Q filed on 8/10/2015
Quarterly Report
Document and Entity Information
6 Months Ended
Jun. 30, 2015
Aug. 7, 2015
Dec. 31, 2014
Document Information [Line Items]
 
 
 
Entity Registrant Name
American Midstream Partners, LP 
 
 
Entity Central Index Key
0001513965 
 
 
Document Type
10-Q 
 
 
Document Period End Date
Jun. 30, 2015 
 
 
Amendment Flag
false 
 
 
Document Fiscal Year Focus
2015 
 
 
Document Fiscal Period Focus
Q2 
 
 
Current Fiscal Year End Date
--12-31 
 
 
Entity Filer Category
Accelerated Filer 
 
 
Entity Common Stock, Shares Outstanding
 
22,762,504 
 
Series A convertible preferred, units, outstanding
8,682,000 
8,682,271 
5,745,000 
Series B [Member]
 
 
 
Document Information [Line Items]
 
 
 
Limited Partners' Capital Account, units outstanding
 
1,301,282 
1,255,000 
Condensed Consolidated Balance Sheets (Unaudited) (USD $)
In Thousands, unless otherwise specified
Jun. 30, 2015
Dec. 31, 2014
Current assets
 
 
Cash and cash equivalents
$ 348 
$ 499 
Accounts receivable
6,263 
4,924 
Unbilled revenue
18,655 
24,619 
Risk management assets
1,155 
688 
Other current assets
8,134 
15,554 
Current deferred tax assets
5,504 
3,086 
Total current assets
40,059 
49,370 
Property, plant and equipment, net
622,590 
582,182 
Goodwill
134,853 
142,236 
Intangible assets, net
103,228 
106,306 
Investment in unconsolidated affiliates
21,935 
22,252 
Other assets, net
13,982 
14,298 
Total assets
936,647 
916,644 
Current liabilities
 
 
Accounts payable
15,957 
20,326 
Accrued gas purchases
9,617 
14,326 
Accrued expenses and other current liabilities
18,557 
25,800 
Current portion of long-term debt
737 
2,908 
Risk management liabilities
69 
215 
Total current liabilities
44,937 
63,575 
Asset retirement obligations
35,048 
34,645 
Other liabilities
287 
126 
Long-term debt
387,100 
372,950 
Deferred tax liabilities
11,087 
8,199 
Total liabilities
478,459 
479,495 
Series A convertible preferred units (8,682 thousand and 5,745 thousand units issued and outstanding as of June 30, 2015 and December 31, 2014, respectively)
160,373 
107,965 
Equity and partners' capital
 
 
General Partner Interests (411 thousand and 392 thousand units issued and outstanding as of June 30, 2015 and December 31, 2014)
(5,218)
(2,450)
Accumulated other comprehensive income (loss)
(32)
2 
Total partners’ capital
293,122 
324,467 
Noncontrolling interests
4,693 
4,717 
Total equity and partners' capital
297,815 
329,184 
Total liabilities, equity and partners' capital
936,647 
916,644 
Limited Partner Common Units [Member]
 
 
Equity and partners' capital
 
 
Limited Partner Interests (22,757 thousand and 22,670 thousand units issued and outstanding as of June 30, 2015 and December 31, 2014, respectively)
265,319 
294,695 
Limited Partner Series B Convertible Units [Member]
 
 
Equity and partners' capital
 
 
Limited Partner Interests (22,757 thousand and 22,670 thousand units issued and outstanding as of June 30, 2015 and December 31, 2014, respectively)
$ 33,053 
$ 32,220 
Condensed Consolidated Balance Sheets (Parenthetical) (Unaudited)
Jun. 30, 2015
Dec. 31, 2014
Statement of Financial Position [Abstract]
 
 
Series A convertible preferred, units, issued
8,682,000 
5,745,000 
Series A convertible preferred, units, outstanding
8,682,000 
5,745,000 
General partner interest, units issued
411,000 
392,000 
General partner interest units,outstanding
411,000 
392,000 
Limited Partner Series B Convertible Units [Member]
 
 
Statement of Financial Position [Abstract]
 
 
Limited Partners' Capital Account, Units Issued
1,301,000 
1,255,000 
Limited Partners' Capital Account, units outstanding
1,301,000 
1,255,000 
Limited Partner Common Units [Member]
 
 
Statement of Financial Position [Abstract]
 
 
Limited Partners' Capital Account, Units Issued
22,757,000 
22,670,000 
Limited Partners' Capital Account, units outstanding
22,757,000 
22,670,000 
Condensed Consolidated Statements of Operations (Unaudited) (USD $)
In Thousands, except Per Share data, unless otherwise specified
3 Months Ended 6 Months Ended
Jun. 30, 2015
Jun. 30, 2014
Jun. 30, 2015
Jun. 30, 2014
Revenue
$ 67,198 
$ 77,873 
$ 131,660 
$ 158,241 
Gain (loss) on commodity derivatives, net
311 
(193)
458 
(323)
Total revenue
67,509 
77,680 
132,118 
157,918 
Operating expenses:
 
 
 
 
Purchases of natural gas, NGLs and condensate
33,334 
53,818 
62,311 
109,039 
Direct operating expenses
13,967 
11,044 
27,834 
20,005 
Selling, general and administrative expenses
5,571 
5,637 
12,506 
11,230 
Equity compensation expense
550 
435 
2,248 
795 
Depreciation, amortization and accretion expense
9,250 
6,012 
18,939 
13,644 
Total operating expenses
62,672 
76,946 
123,838 
154,713 
Operating Expenses
62,672 
76,946 
123,838 
154,713 
Gain (loss) on sale of assets, net
(2,970)
0 
(2,978)
(21)
Operating income (loss)
1,867 
734 
5,302 
3,184 
Interest expense
(3,556)
(1,680)
(6,166)
(3,583)
Earnings in unconsolidated affiliates
4 
0 
171 
0 
Net income (loss) before income tax (expense) benefit
(1,685)
(946)
(693)
(399)
Income tax (expense) benefit
(317)
(149)
(473)
(138)
Net income (loss) from continuing operations
(2,002)
(1,095)
(1,166)
(537)
Income (loss) from discontinued operations, net of tax
(31)
(506)
(26)
(556)
Net income (loss)
(2,033)
(1,601)
(1,192)
(1,093)
Net income (loss) attributable to noncontrolling interests
32 
66 
46 
174 
Net income (loss) attributable to the Partnership
(2,065)
(1,667)
(1,238)
(1,267)
Distribution declared per common unit (a)
$ 0.4725 1
$ 0.4625 1
$ 0.9450 1
$ 0.9150 1
Income (Loss) from Continuing Operations, Per Outstanding Limited Partnership Unit, Basic, Net of Tax
$ (0.35)
$ (0.55)
$ (0.53)
$ (0.92)
Weighted average number of units used in computation of limited partners’ net (loss) income per unit (basic and diluted)
22,757 
11,139 
22,730 
10,496 
Net Income (Loss), Per Outstanding Limited Partnership Unit, Basic, Net of Tax
$ (0.35)
$ (0.59)
$ (0.53)
$ (0.97)
General Partner [Member]
 
 
 
 
Operating expenses:
 
 
 
 
General Partner's Interest in net income (loss)
(25)
(22)
(14)
(15)
Limited Partner [Member]
 
 
 
 
Operating expenses:
 
 
 
 
Limited Partners' Interest in net income (loss)
$ (2,040)
$ (1,645)
$ (1,224)
$ (1,252)
Condensed Consolidated Statements of Comprehensive Income (Unaudited) (USD $)
In Thousands, unless otherwise specified
3 Months Ended 6 Months Ended
Jun. 30, 2015
Jun. 30, 2014
Jun. 30, 2015
Jun. 30, 2014
Net income (loss)
$ (2,033)
$ (1,601)
$ (1,192)
$ (1,093)
Income (loss) from discontinued operations, net of tax
(31)
(506)
(26)
(556)
Comprehensive income (loss)
(2,056)
(1,591)
(1,226)
(1,047)
Less: Comprehensive income (loss) attributable to noncontrolling interests
32 
66 
46 
174 
Comprehensive income (loss) attributable to Partnership
(2,088)
(1,657)
(1,272)
(1,221)
Accumulated Other Comprehensive Income (Loss) [Member]
 
 
 
 
Unrealized gain (loss) on postretirement benefit plan assets and liabilities
$ (23)
$ 10 
$ (34)
$ 46 
Condensed Consolidated Statements of Changes in Partners' Capital (Unaudited) (USD $)
In Thousands, except Per Share data, unless otherwise specified
3 Months Ended 6 Months Ended
Jun. 30, 2015
Jun. 30, 2014
Jun. 30, 2015
Jun. 30, 2014
Dec. 31, 2014
Dec. 31, 2013
Net Income (Loss), Per Outstanding Limited Partnership Unit, Basic, Net of Tax
$ (0.35)
$ (0.59)
$ (0.53)
$ (0.97)
 
 
Income (Loss) from Continuing Operations, Per Outstanding Limited Partnership Unit, Basic, Net of Tax
$ (0.35)
$ (0.55)
$ (0.53)
$ (0.92)
 
 
Partners' Capital
$ 293,122 
 
$ 293,122 
 
$ 324,467 
$ 73,839 
Net income (loss)
(2,033)
(1,601)
(1,192)
(1,093)
 
 
Net Income (Loss) Attributable to Parent
(2,065)
(1,667)
(1,238)
(1,267)
 
 
Income (loss) from discontinued operations, net of tax
(31)
(506)
(26)
(556)
 
 
Less: Comprehensive income (loss) attributable to noncontrolling interests
32 
66 
46 
174 
 
 
LTIP vesting
 
 
 
128 
 
 
LTIP tax netting unit repurchase
 
 
(725)
(151)
 
 
Issuance of common units, net of offering costs
 
 
 
86,900 
 
 
Partners' Capital
293,122 
 
293,122 
 
324,467 
73,839 
Parent [Member]
 
 
 
 
 
 
Partners' Capital
293,122 
173,261 
293,122 
173,261 
 
 
Net Income (Loss) Attributable to Parent
 
 
(1,238)
(1,267)
 
 
Unitholder contributions
 
 
376 
1,276 
 
 
Unitholder distributions
 
 
(32,804)
(19,285)
 
 
Acquisition of noncontrolling interests
 
 
 
(21)
 
 
LTIP vesting
 
 
195 
 
 
 
LTIP tax netting unit repurchase
 
 
(725)
(151)
 
 
Equity based compensation
 
 
2,052 
698 
 
 
Unrealized gain (loss) on postretirement benefit plan assets and liabilities
 
 
(34)
46 
 
 
Issuance of common units, net of offering costs
 
 
 
86,904 
 
 
Partners' Capital
293,122 
173,261 
293,122 
173,261 
 
 
General Partner [Member]
 
 
 
 
 
 
Partners' Capital
(5,218)
(4,212)
(5,218)
(4,212)
(2,450)
2,696 
Net Income (Loss) Allocated to General Partners
(25)
(22)
(14)
(15)
 
 
Unitholder contributions
 
 
376 
1,276 
 
 
Unitholder distributions
 
 
(3,004)
(1,192)
 
 
Issuance and exercise of warrant
 
 
 
(7,164)
 
 
LTIP vesting
 
 
(2,178)
(511)
 
 
Equity based compensation
 
 
2,052 
698 
 
 
Partners' Capital
(5,218)
(4,212)
(5,218)
(4,212)
(2,450)
2,696 
Limited Partner [Member]
 
 
 
 
 
 
Partners' Capital
265,319 
146,271 
265,319 
146,271 
294,695 
71,039 
Net Income (Loss) Allocated to Limited Partners
(2,040)
(1,645)
(1,224)
(1,252)
 
 
Unitholder distributions
 
 
(29,800)
(18,093)
 
 
Issuance and exercise of warrant
 
 
 
7,164 
 
 
Acquisition of noncontrolling interests
 
 
 
(21)
 
 
LTIP vesting
 
 
2,373 
639 
 
 
LTIP tax netting unit repurchase
 
 
(725)
(151)
 
 
Issuance of common units, net of offering costs
 
 
 
86,904 
 
 
Partners' Capital
265,319 
146,271 
265,319 
146,271 
294,695 
71,039 
Series B [Member]
 
 
 
 
 
 
Partners' Capital
33,053 
31,052 
33,053 
31,052 
32,220 
0 
Partners' Capital
33,053 
31,052 
33,053 
31,052 
32,220 
0 
Accumulated Other Comprehensive Income (Loss) [Member]
 
 
 
 
 
 
Partners' Capital
(32)
150 
(32)
150 
2 
104 
Unrealized gain (loss) on postretirement benefit plan assets and liabilities
(23)
10 
(34)
46 
 
 
Partners' Capital
(32)
150 
(32)
150 
2 
104 
Noncontrolling Interest [Member]
 
 
 
 
 
 
Partners' Capital
4,693 
4,547 
4,693 
4,547 
4,717 
4,628 
Net distributions to noncontrolling interests
 
 
(70)
(226)
 
 
Acquisition of noncontrolling interests
 
 
 
(29)
 
 
Partners' Capital
4,693 
4,547 
4,693 
4,547 
4,717 
4,628 
Series B [Member]
 
 
 
 
 
 
Unitholder distributions
(413)
(560)
(833)
(1,052)
 
 
Series B [Member] |
Parent [Member]
 
 
 
 
 
 
Issuance of Series B units
 
 
833 
31,052 
 
 
Series B [Member] |
Series B [Member]
 
 
 
 
 
 
Issuance of Series B units
 
 
$ 833 
$ 31,052 
 
 
Condensed Consolidated Statements of Cash Flows (Unaudited) (USD $)
In Thousands, unless otherwise specified
6 Months Ended
Jun. 30, 2015
Jun. 30, 2014
Net income (loss)
$ (1,192)
$ (1,093)
Depreciation, amortization and accretion expense
18,939 
13,644 
Amortization of deferred financing costs
667 
847 
Amortization of weather derivative premium
475 
554 
Unrealized (gain) loss on commodity derivatives, net
(213)
113 
Non-cash compensation
2,294 
730 
Postretirement expense (benefit)
18 
(23)
(Gain) loss on sale of assets, net
2,978 
106 
Loss on impairment of noncurrent assets held for sale
0 
673 
Deferred tax expense (benefit)
457 
(161)
Accounts receivable
(1,331)
(556)
Unbilled revenue
5,964 
(2,083)
Risk management assets and liabilities
(875)
(965)
Other current assets
1,041 
1,547 
Other assets, net
37 
22 
Accounts payable
6,200 
(851)
Accrued gas purchases
(4,709)
(188)
Accrued expenses and other current liabilities
(1,293)
680 
Asset retirement obligations
0 
(623)
Other liabilities
163 
38 
Net cash provided by operating activities
29,620 
12,411 
Cost of acquisitions, net of cash acquired
7,383 
(110,909)
Additions to property, plant and equipment
(79,734)
(13,229)
Proceeds from disposals of property, plant and equipment
3,876 
6,202 
Investment in unconsolidated affiliate
(626)
0 
Return of capital from unconsolidated affiliate
1,329 
0 
Restricted cash
6,475 
0 
Net cash used in investing activities
(61,297)
(117,936)
Proceeds from issuance of common units to public, net of offering costs
(348)
86,904 
Unitholder contributions
330 
1,276 
Unitholder distributions
(24,364)
(13,793)
Issuance of Series A Units
45,000 
0 
Acquisition of noncontrolling interests
0 
(8)
Net distributions to noncontrolling interests
(70)
(226)
LTIP tax netting unit repurchase
(725)
(151)
Payment of deferred financing costs
(276)
(154)
Payments on other debt
(2,171)
(1,644)
Borrowings on other debt
0 
170 
Payments on long-term debt
(123,650)
(75,220)
Borrowings on long-term debt
137,800 
80,985 
Net cash provided by financing activities
31,526 
108,139 
Net increase (decrease) in cash and cash equivalents
(151)
2,614 
Beginning of period
499 
393 
End of period
348 
3,007 
Interest payments, net
5,572 
2,718 
Increase (decrease) in accrued property, plant and equipment
(16,897)
9,501 
Series A [Member]
 
 
Accrued paid in-kind unitholder distributions for Series A Units
7,607 
5,760 
Series B [Member]
 
 
Issuance of Series A Units
0 
30,000 
Accrued paid in-kind unitholder distributions for Series A Units
$ 833 
$ 1,052 
Organization and Basis of Presentation
Organization and Basis of Presentation
Organization and Basis of Presentation

General

American Midstream Partners, LP (the "Partnership", "we", "us", or "our"), was formed on August 20, 2009 as a Delaware limited partnership for the purpose of operating, developing and acquiring a diversified portfolio of midstream energy assets. The Partnership's general partner, American Midstream GP, LLC (the "General Partner"), is 95% owned by High Point Infrastructure Partners, LLC ("HPIP") and 5% owned by AIM Midstream Holdings, LLC. We hold our assets in a series of wholly owned limited liability companies, two limited partnerships and a corporation. Our capital accounts consist of notional general partner units and limited partner interests.

Nature of Business

We are engaged in the business of gathering, treating, processing, and transporting natural gas, fractionating NGLs, transporting oil and storing specialty chemical products through our ownership and operation of twelve gathering systems, five processing facilities, three fractionation facilities, four marine terminal sites, three interstate pipelines, five intrastate pipelines and one oil pipeline. We also own a 66.7% non-operating interest in Main Pass Oil Gathering, LP ("MPOG"), a crude oil gathering and processing system, a 50% undivided, non-operating interest in the Burns Point Plant, a natural gas processing plant, and a 46% non-operated interest in Mesquite, an off-spec condensate fractionation project. Our primary assets, which are strategically located in Alabama, Georgia, Louisiana, Maryland, Mississippi, North Dakota, Tennessee and Texas, provide critical infrastructure that links producers of natural gas, NGLs, condensate and specialty chemicals to numerous intermediate and end-use markets. We currently operate more than 3,000 miles of pipelines that gather and transport over 1 Bcf/d of natural gas and operate approximately 1.7 million barrels of storage capacity across four marine terminal sites.

Basis of Presentation

These unaudited condensed consolidated financial statements have been prepared in accordance with generally accepted accounting principles ("GAAP") for interim financial information. Accordingly, they do not include all of the information and footnotes required by GAAP for complete financial statements. The year-end balance sheet data was derived from consolidated audited financial statements but does not include disclosures required by GAAP for annual periods. The information furnished herein reflects all normal recurring adjustments that are, in the opinion of management, necessary for a fair statement of financial position and results of operations for the respective interim periods.

Our financial results for the three and six months ended June 30, 2015, are not necessarily indicative of the results that may be expected for the full year ended December 31, 2015. These unaudited condensed consolidated financial statements should be read in conjunction with our consolidated financial statements and notes thereto included in our Annual Report on Form 10-K for the year ended December 31, 2014 (“Annual Report”) filed with the Securities and Exchange Commission (the "SEC") on March 10, 2015.

Consolidation Policy

The accompanying condensed consolidated financial statements include accounts of American Midstream Partners, LP, and its controlled subsidiaries. All significant inter-company accounts and transactions have been eliminated in the preparation of the accompanying condensed consolidated financial statements. We hold a 50% undivided interest in the Burns Point natural gas processing plant in which we are responsible for our proportionate share of the costs and expenses of the facility. Our condensed consolidated financial statements reflect our proportionate share of the revenues, expenses, assets and liabilities of this undivided interest. As of June 30, 2015, we also hold a 92.2% undivided interest in the Chatom Processing and Fractionation facility (the "Chatom System"). Our condensed consolidated financial statements reflect the accounts of the Chatom System and the interests in the Chatom System held by non-affiliated working interest owners are reflected as noncontrolling interests in the Partnership's condensed consolidated financial statements.

The Partnership accounts for its 66.7% non-operated interest in MPOG and its 46.0% non-operated interest in Mesquite under the equity method.

Use of Estimates

When preparing condensed consolidated financial statements in conformity with GAAP, management must make estimates and assumptions based on information available at the time. These estimates and assumptions affect the reported amounts of assets, liabilities, revenues and expenses, as well as the disclosures of contingent assets and liabilities as of the date of the financial statements. Estimates and assumptions are based on information available at the time such estimates and assumptions are made. Adjustments made with respect to the use of these estimates and assumptions often relate to information not previously available. Uncertainties with respect to such estimates and assumptions are inherent in the preparation of financial statements. Estimates and assumptions are used in, among other things i) estimating unbilled revenues, product purchases and operating and general and administrative costs, ii) developing fair value estimates, including assumptions for future cash flows and discount rates, iii) analyzing long-lived assets, goodwill and intangible assets for possible impairment, iv) estimating the useful lives of assets and v) determining amounts to accrue for contingencies, guarantees and indemnifications. Actual results, therefore, could differ materially from estimated amounts.
Acquisitions and Divestitures
Acquisitions and Divestitures
Acquisitions and Divestitures

Costar Acquisition

On October 14, 2014, the Partnership acquired 100% of the membership interests of Costar Midstream, L.L.C. ("Costar") from Energy Spectrum Partners VI LP and Costar Midstream Energy, LLC, in exchange for $258.0 million in cash and 6.9 million of the Partnership's common units representing Limited Partner interests, or common units (the "Costar Acquisition"). Costar is an onshore gathering and processing company with its primary gathering, processing, fractionation, and off-spec condensate treating and stabilization assets in East Texas and the Permian basin, with a significant crude oil gathering system project under development in the Bakken oil play.

The Costar Acquisition was accounted for using the acquisition method of accounting and as a result, the aggregate purchase price was allocated to the assets acquired, liabilities assumed and a noncontrolling interest in a Costar subsidiary based on their respective fair values as of the acquisition date. The excess of the aggregate purchase price over the fair values of the assets acquired, liabilities assumed and the noncontrolling interest was classified as goodwill, which is attributable to future prospective customer agreements expected to be obtained as a result of the acquisition. The operating systems acquired have been included in the Partnership’s Gathering and Processing segment from the acquisition date.

During the first quarter of 2015, we reached an agreement on certain working capital matters with the Costar sellers, resulting in a decrease to goodwill of $0.2 million.

In the second quarter of 2015, we reached an agreement with the Costar sellers regarding certain capital expenditures that we have incurred, or will incur, that were not known at the time of closing, which resulted in a decrease to goodwill and cash consideration transferred of $7.2 million.

The following table summarizes the fair value of consideration transferred to acquire Costar and the allocation of that amount to the assets acquired, liabilities assumed and the noncontrolling interest based upon their respective fair values as of the acquisition date (in thousands).

Fair value of consideration transferred:
 
Cash
$
258,001

Limited partner common units
147,296

Total fair value of consideration
$
405,297


Fair Value of assets acquired, liabilities assumed and noncontrolling interest:
 
Working capital
$
8,152

Property, plant and equipment:
 
Processing plants
$
48,357

Pipelines
128,799

Land
1,244

Buildings
682

Equipment
9,827

Construction in progress
16,146

Total property, plant and equipment
205,055

Investment in unconsolidated affiliate
11,884

Intangible assets:
 
Customer relationships
53,400

Dedicated acreage
32,000

Goodwill
95,025

Noncontrolling interest
(219
)
 
$
405,297



The fair value of the common units of $147.3 million differs from the amount determined using the market price of such units on the date of the acquisition as a result of restrictions which require the sellers to hold the units for specified periods of time. The fair value of Limited Partner common units issued in the transaction was determined using an option pricing model and the following key assumptions: i) the closing unit market price on the day of the acquisition, ii) the contractual holding periods, iii) historical unit price volatility for the Partnership and its peers, and iv) a risk-free rate of return.

The fair value of property, plant and equipment was determined using both the cost and market approaches which required significant Level 3 inputs. Key assumptions included i) estimated replacement costs for individual assets or asset groups, ii) estimated remaining useful lives for the acquired assets, and iii) recent market transactions for similar assets. The fair value of intangible assets was determined using the income approach which also required significant Level 3 inputs. Key assumptions included i) estimated throughput volumes, ii) forward market prices for natural gas and NGLs as of the acquisition date, iii) estimated future operating and development cash flows, and iv) discount rates ranging from 11.0% to 16.0%.

The intangible assets acquired relate to existing customer relationships that Costar had at the time of the acquisition, as well as agreements with two producers under which Costar agreed to construct and operate gathering and processing facilities in exchange for the producers’ agreements to dedicate certain acreage and related production to those facilities. Working capital includes $11.2 million of accounts receivable, all of which were subsequently collected.

For the three and six months ended June 30, 2015, Costar contributed revenue of $24.2 million and $45.6 million, respectively, and net income of $0.6 million and $1.8 million, respectively, attributable to the Partnership's Gathering and Processing segment.

Lavaca Acquisition

On January 31, 2014, the Partnership acquired approximately 120 miles of high- and low-pressure pipelines and associated facilities located in the Eagle Ford shale in Gonzales and Lavaca Counties, Texas from Penn Virginia Corporation (NYSE: PVA) ("PVA") for $104.4 million in cash (the "Lavaca Acquisition"). The Lavaca Acquisition was financed with proceeds from the Partnership's January 2014 equity offering and from the issuance of Series B Units to our General Partner.

The Lavaca Acquisition was accounted for using the acquisition method of accounting and, as a result, the purchase price was allocated to the assets acquired upon their respective fair values as of the acquisition date. The excess of the purchase price over the fair value of the assets acquired was classified as goodwill.

The following table summarizes the final allocation of the purchase price to the assets acquired based upon their respective fair values as of the acquisition date (in thousands):

Property, plant and equipment:
 
Land
$
2

Pipelines
58,737

Equipment
753

Total property, plant and equipment
59,492

Intangible assets
21,350

Goodwill
23,567

Total cash consideration
$
104,409



The fair value of property, plant and equipment was determined using the cost approach which required significant Level 3 inputs. Key assumptions included i) estimated replacement costs for individual assets or asset groups and ii) estimated remaining useful lives for the acquired assets. The fair value of intangible assets was determined using the income approach which also required significant Level 3 inputs. Key assumptions included i) estimated throughput volumes, ii) future operating and development cash flows, and iii) a discount rate of 10.5%.

The intangible assets acquired relate to a gas gathering agreement under which PVA has dedicated certain acreage and related production to the acquired facilities.

For the three and six months ended June 30, 2015, Lavaca contributed revenue of $5.9 million and $11.9 million, respectively, and net income of $2.3 million and $4.5 million, respectively, attributable to the Partnership's Gathering and Processing segment. For the three and six months ended June 30, 2014, Lavaca contributed revenue of $3.7 million and $6.0 million, respectively, and net income of $0.6 million and $2.2 million, respectively, attributable to the Partnership's Gathering and Processing segment.

Other Acquisitions

Investment in Unconsolidated Affiliates

On August 11, 2014, the Partnership acquired a 66.7% non-operated interest in MPOG, an offshore oil gathering system, for a net purchase price of $12.0 million, which was financed with borrowings from the Partnership's credit facility. Although the Partnership owns a majority interest in MPOG, the ownership structure requires unanimous approval of all owners on decisions impacting the operation of the assets and any changes in ownership structure. Therefore, the Partnership's voting rights are not proportional to its obligation to absorb losses or receive returns. The Partnership accounts for its 66.7% interest using the equity method.

For three and six months ended June 30, 2015, the Partnership recorded less than $0.1 million and $0.2 million, respectively, in earnings from MPOG. The Partnership received cash distributions of $0.5 million and $1.5 million for the three and six months ended June 30, 2015, respectively. The excess of the cash distributions received over the earnings recorded from MPOG is classified as a return of capital within the investing section of our consolidated statement of cash flows.

Williams Pipeline Acquisition

In the first quarter of 2014, the Partnership acquired natural gas pipeline facilities that are contiguous to and connect with our High Point System in our Transmission segment located in offshore Louisiana from Transcontinental Gas Pipe Line Company, LLC, a subsidiary of Williams Partners, LP. for $6.5 million in cash. The acquisition was subject to FERC approval of the seller's application to abandon by sale to us the pipeline facilities and to permit the facilities to serve a gathering function, exempt from FERC's jurisdiction. The FERC granted approval of the application during the first quarter of 2014, and the purchase and sale agreement closed on March 14, 2014. The purchase price was allocated to pipelines using the income approach which required certain Level 3 inputs.

Divestitures

On June 1, 2015, the Partnership disposed of certain non-strategic off-shore transmission assets in Louisiana with a net book value of $3.0 million for nominal proceeds, resulting in a non-cash loss on disposal of $3.0 million.

On March 31, 2014, the Partnership completed the sale of certain gathering and processing assets in Madison County, Texas. We received $6.1 million in cash proceeds related to the sale, which approximated its net book value.
Summary of Significant Accounting Policies
Recent Accounting Pronouncements
Recent Accounting Pronouncements

In May 2014, the FASB issued Accounting Standards Update ("ASU") No. 2014-09, Revenue from Contracts with Customers (Topic 606), which amends the existing accounting standards for revenue recognition. The standard requires an entity to recognize revenue in a manner that depicts the transfer of goods or services to customers at an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. The guidance in ASU 2014-09 is now effective for annual reporting periods beginning after December 15, 2017, including interim periods therein, as a result of the FASB's recent decision to defer the effective date by one year. We are currently evaluating the method of adoption and impact this standard will have on our condensed consolidated financial statements and related disclosures.

In February 2015, the FASB issued ASU No. 2015-02, Amendments to the Consolidation Analysis. This guidance amends the analysis that a reporting entity must perform to determine whether it should consolidate certain types of legal entities. ASU 2015-02 is effective for fiscal years, and for interim periods within those fiscal years, beginning after December 15, 2015, and early adoption is permitted. The Partnership is currently evaluating the potential impact this standard will have on its condensed consolidated financial statements and related disclosures.

In April 2015, the FASB issued ASU No. 2015-03, Simplifying the Presentation of Debt Issuance Costs. This amendment requires that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. ASU 2015-03 is effective for fiscal years beginning after December 15, 2015, including interim periods therein, and is applied retrospectively. Early adoption is permitted for financial statements that have not been previously issued. Given the Partnership's debt issuance costs relate to its revolving debt Credit Facility, the Partnership does not anticipate this standard to alter its current accounting for such costs.

In April 2015, the FASB issued ASU No. 2015-06, Earnings Per Share (Topic 260).  This guidance clarifies the process for updating historical earnings per unit disclosures when a drop-down transaction occurs between entities under common control.  Pursuant to the amendment, the previously reported earnings per unit measure presented in the historical financial statements would not change as a result of the drop-down transaction.  ASU 2015-06 is effective for annual reporting periods beginning after December 15, 2015, and for interim periods within those fiscal years.  Early adoption is permitted.  The Partnership has evaluated this guidance and determined it is consistent with our policy and historical presentation of earnings per unit.
Discontinued Operations (Notes)
Disposal Groups, Including Discontinued Operations, Disclosure [Text Block]
Discontinued Operations

The Partnership continues to classify the terminal asset in Salisbury, Maryland as held for sale as we are continuing negotiations for the sale of those assets, contingent upon the purchaser’s completion of due diligence. The net book value of the assets and liabilities attributable to the terminal asset comprise less than $0.1 million of Other current assets, $1.2 million of Other assets, net, and less than $0.1 million of Accrued expenses and other current liabilities as of June 30, 2015 and December 31, 2014.

We have classified these assets as discontinued operations within our condensed consolidated statement of operations. Accordingly, we reclassified the disposal group's results of operations from our results of continuing operations to Income (loss) from discontinued operations, net of tax in our accompanying condensed consolidated statement of operations for all periods presented. We elected not to present separately the operating, investing and financing cash flows related to the disposal groups in our accompanying condensed consolidated statement of cash flows as this activity was immaterial for all periods presented. The following table presents the revenue, expense and gain (loss) from operations of disposal groups associated with the assets classified as held for sale for the three and six months ended June 30, 2015 and 2014 (in thousands, except per unit amounts):
 
Three months ended June 30,
 
Six months ended June 30,
 
2015
 
2014
 
2015
 
2014
Revenue
$
10

 
$
212

 
$
74

 
$
449

Expense
(61
)
 
(268
)
 
(116
)
 
(545
)
Loss on impairment of property, plant and equipment
—

 
(673
)
 
—

 
(673
)
Loss on sale of assets
—

 
(65
)
 
—

 
(87
)
Income tax benefit
20

 
288

 
16

 
300

Income (loss) from operations of disposal groups, net of tax
$
(31
)
 
$
(506
)
 
$
(26
)
 
$
(556
)
Limited partners' net income (loss) per unit from discontinued operations (basic and diluted)
$
—

 
$
(0.04
)
 
$
—

 
$
(0.05
)
Concentration of Credit Risk and Trade Accounts Receivable
Concentration of Credit Risk and Trade Account Receivable
Concentration of Credit Risk and Trade Accounts Receivable

Our primary assets, which are strategically located in Alabama, Georgia, Louisiana, Maryland, Mississippi, North Dakota, Tennessee and Texas, provide critical infrastructure that links customers of natural gas, NGLs, condensate and specialty chemicals to numerous intermediate and end-use markets.  As a result of recent acquisitions and geographic diversification, we have reduced the concentration of trade receivable balances due from these customer groups, and as such reduced the concentration which may affect our overall credit risk in that the customers may be similarly affected by changes in economic, regulatory or other factors. We maintain allowances for potentially uncollectible accounts receivable; however, for the three and six months ended June 30, 2015 and 2014, no allowances on or significant write-offs of accounts receivable were recorded.

During the three and six months ended June 30, 2015, no individual customer accounted for 10% or more of the Partnership's consolidated revenue.
Other Current Assets (Notes)
Schedule of Other Current Assets
Other current assets consist of the following (in thousands):
 
June 30,
 
December 31,
 
2015
 
2014
Prepaid insurance
$
1,922

 
$
4,162

Restricted cash
—

 
6,475

Other current assets
6,212

 
4,917

 
$
8,134

 
$
15,554


Restricted cash of $6.5 million as of December 31, 2014 consisted of a cash-backed letter of credit related to Costar operations that the Partnership was contractually obligated to maintain after the Costar Acquisition. The Partnership was released from this obligation in January 2015. Other current assets primarily consist of natural gas imbalances and amounts due from related parties.
Derivatives
Derivatives
Derivatives

Commodity Derivatives

To minimize the effect of commodity price changes and maintain our cash flow and the economics of our development plans, we enter into commodity hedge contracts from time to time. The terms of the contracts depend on various factors, including management's view of future commodity prices, economics on purchased assets and future financial commitments. This hedging program is designed to mitigate the effect of commodity price declines while allowing us to participate in some commodity price upside. Management regularly monitors the commodity markets and financial commitments to determine if, when, and at what level commodity hedging is appropriate in accordance with policies that are established by the board of directors of our General Partner. Currently, our commodity derivatives are in the form of swaps. As of June 30, 2015, the aggregate notional volume of our commodity derivatives was 4.3 million gallons of NGLs, natural gasoline, and crude oil equivalent.

We enter into commodity contracts with multiple counterparties, and in some cases, may be required to post collateral with our counterparties in connection with our derivative positions. As of June 30, 2015, we were not required to post collateral with any counterparty. The counterparties are not required to post collateral with us in connection with their derivative positions. Netting agreements are in place that permit us to offset our commodity derivative asset and liability positions with our counterparties.

We did not designate any of our commodity derivatives as hedges for accounting purposes. As a result, our commodity derivatives are accounted for at fair value in our condensed consolidated balance sheets with changes in fair value recognized currently in earnings.

Interest Rate Swap

We entered into an interest rate swap to manage the impact of the interest rate risk associated with our credit facility, effectively converting a portion of the cash flows related to our long-term variable rate debt into fixed rate cash flows. As of June 30, 2015, the notional amount of our interest rate swap was $100.0 million. The interest rate swap was entered into with a single counterparty and we were not required to post collateral. The interest rate swap expired August 1, 2015.

Weather Derivative

In the second quarter of 2015, we entered into a weather derivative to mitigate the impact of potential unfavorable weather to our operations under which we could receive payments totaling up to $10.0 million in the event that a hurricane or hurricanes of certain strength pass through the area as identified in the derivative agreement. The weather derivatives are accounted for using the intrinsic value method, under which the fair value of the contract was zero and any amounts received are recognized as gains during the period received. The weather derivatives were entered into with a single counterparty, and we were not required to post collateral.

We paid premiums of $0.9 million in 2015, which are recorded as current Risk management assets on our condensed consolidated balance sheet and are being amortized to Direct operating expenses on a straight-line basis over the term of the contract of one year. Unamortized amounts associated with the weather derivatives were approximately $0.8 million as of June 30, 2015.
As of June 30, 2015 and December 31, 2014, the value associated with our commodity derivatives, interest rate swap, and weather derivative were recorded in our condensed consolidated balance sheets, under the captions as follows (in thousands):
 
 
Gross Risk Management Assets
 
Gross Risk Management Liabilities
 
Net Risk Management Assets (Liabilities)
Balance Sheet Classification
 
June 30,
2015
 
December 31, 2014
 
June 30,
2015
 
December 31, 2014
 
June 30,
2015
 
December 31, 2014
Current
 
$
1,155

 
$
688

 
$
—

 
$
—

 
$
1,155

 
$
688

Noncurrent
 
—

 
—

 
—

 
—

 
—

 
—

Total assets
 
$
1,155

 
$
688

 
$
—

 
$
—

 
$
1,155

 
$
688

 
 
 
 
 
 
 
 
 
 
 
 
 
Current
 
$
—

 
$
—

 
$
(69
)
 
$
(215
)
 
$
(69
)
 
$
(215
)
Noncurrent
 
—

 
—

 
—

 
—

 
—

 
—

Total liabilities
 
$
—

 
$
—

 
$
(69
)
 
$
(215
)
 
$
(69
)
 
$
(215
)


For the three and six months ended June 30, 2015 and 2014, respectively, the realized and unrealized gains (losses) associated with our commodity derivatives, interest rate swap instrument and weather derivative were recorded in our condensed consolidated statements of operations, under the captions as follows (in thousands):
 
Three months ended June 30,
 
Six months ended June 30,
 
Gain (loss) on derivatives
 
Gain (loss) on derivatives
Statement of Operations Classification
Realized
 
Unrealized
 
Realized
 
Unrealized
2015
 
 
 
 
 
 
 
Gain (loss) on commodity derivatives, net
$
252

 
$
59

 
$
391

 
$
67

Interest expense
(101
)
 
98

 
(203
)
 
146

Direct operating expenses
(234
)
 
—

 
(475
)
 
—

Total
$
(83
)
 
$
157

 
$
(287
)
 
$
213

2014
 
 
 
 
 
 
 
Gain (loss) on commodity derivatives, net
$
(80
)
 
$
(113
)
 
$
(182
)
 
$
(141
)
Interest expense
(109
)
 
38

 
(213
)
 
28

Direct operating expenses
(269
)
 
—

 
(553
)
 
—

Total
$
(458
)
 
$
(75
)
 
$
(948
)
 
$
(113
)
Fair Value Measurement
Fair Value Measurement
Fair Value Measurement

We believe the carrying amount of cash and cash equivalents, accounts receivable and accounts payable approximates fair value because of the short-term maturity of these instruments.

The recorded value of the amounts outstanding under the credit facility approximates its fair value, as interest rates are variable, based on prevailing market rates and the short-term nature of borrowings and repayments under the credit facility.

The fair value of all derivatives instruments is estimated using a market valuation methodology based upon forward commodity price curves, volatility curves as well as other relevant economic measures, if necessary. Discount factors may be utilized to extrapolate a forecast of future cash flows associated with long dated transactions or illiquid market points. The inputs are obtained from independent pricing services, and we have made no adjustments to the obtained prices.

We have consistently applied these valuation techniques in all periods presented and believe we have obtained the most accurate information available for the types of derivatives contracts held. We will recognize transfers between levels at the end of the reporting period in which the transfer occurred. There were no such transfers for the six months ended June 30, 2015 and 2014.

Fair Value of Financial Instruments

The following table sets forth by level within the fair value hierarchy, our commodity derivative instruments and interest rate swap, included as part of Risk management assets and Risk management liabilities within our condensed consolidated balance sheets, that were measured at fair value on a recurring basis as of June 30, 2015 and December 31, 2014 (in thousands):
 
Carrying
Amount
 
Estimated Fair Value of the Asset (Liability)
 
Level 1
 
Level 2
 
Level 3
 
Total
Commodity derivative instruments, net
 
 
 
 
 
 
 
 
 
June 30, 2015
$
353

 
$
—

 
$
353

 
$
—

 
$
353

December 31, 2014
286

 
—

 
286

 
—

 
286

Interest rate swap
 
 
 
 
 
 
 
 
 
June 30, 2015
$
(69
)
 
$
—

 
$
(69
)
 
$
—

 
$
(69
)
December 31, 2014
(215
)
 
—

 
(215
)
 
—

 
(215
)


The unamortized portion of the premium paid to enter the weather derivative described in Note 7 "Derivatives" is included within Risk management assets on our condensed consolidated balance sheet but is not included as part of the above table as it is recorded at amortized carrying cost, not fair value.
Property, Plant and Equipment
Property, Plant and Equipment
Property, Plant and Equipment, Net

Property, plant and equipment, net, as of June 30, 2015 and December 31, 2014 were as follows (in thousands):
 
Useful Life
(in years)
 
June 30,
2015
 
December 31,
2014
Land
N/A
 
$
5,282

 
$
5,282

Construction in progress
N/A
 
90,085

 
77,550

Base gas
N/A
 
1,108

 
1,108

Buildings and improvements
4 to 40
 
9,708

 
6,855

Processing and treating plants
8 to 40
 
81,404

 
80,837

Pipelines
3 to 40
 
479,749

 
451,341

Compressors
4 to 20
 
30,506

 
24,548

Dock
20 to 40
 
8,105

 
8,072

Tanks, truck rack and piping
20 to 40
 
32,826

 
30,079

Equipment
8 to 20
 
9,474

 
8,855

Computer software
5
 
3,856

 
3,490

Total property, plant and equipment
 
 
752,103

 
698,017

Accumulated depreciation
 
 
(129,513
)
 
(115,835
)
Property, plant and equipment, net
 
 
$
622,590

 
$
582,182



Of the gross property, plant and equipment balances at June 30, 2015 and December 31, 2014, $104.4 million and $101.9 million, respectively, were related to AlaTenn, Midla and HPGT, our FERC regulated interstate and intrastate assets.

Capitalized interest was $0.5 million and $0.1 million for the three months ended June 30, 2015 and 2014, respectively, and $0.7 million and $0.2 million for the six months ended June 30, 2015 and 2014, respectively.

Depreciation expense was $7.6 million and $4.7 million for the three months ended June 30, 2015 and 2014, respectively, and $15.5 million and $11.1 million for the six months ended June 30, 2015 and 2014, respectively.
Goodwill and Intangible Assets, Net (Notes)
Goodwill and Intangible Assets, Net
Goodwill and Intangible Assets, Net

The carrying value of goodwill as of June 30, 2015 and December 31, 2014, was $134.9 million and $142.2 million, respectively. See Note 3 "Acquisitions and Divestitures" for discussion regarding the change in goodwill from December 31, 2014 to June 30, 2015. Goodwill as of June 30, 2015 consisted of $118.6 million and $16.3 million related to our Gathering and Processing and Terminal segments, respectively. Goodwill as of December 31, 2014 consisted of $125.9 million and $16.3 million related to our Gathering and Processing and Terminal segments, respectively.

The goodwill associated with our Gathering and Processing segment relates to the Costar and Lavaca Acquisitions and primarily represent strategic developmental locations to grow the business within the segment. The goodwill associated with our Terminal segment was contributed to the Partnership as part of the Partnerships' acquisition of Blackwater Midstream Holdings LLC ("Blackwater") and other related subsidiaries from an affiliate of HPIP (the "Blackwater Acquisition"). Goodwill was recorded as a result of the excess of the investment by an affiliate of HPIP in Blackwater over the fair market value of the identifiable net assets and customer contracts acquired.

Intangible assets, net, consists of customer contracts, relationships and dedicated acreage agreements identified as part of the Costar Acquisition, Lavaca Acquisition and Blackwater Acquisition. These intangible assets have definite lives and are subject to amortization on a straight-line basis over their economic lives, currently ranging from 5 months to thirty years. Intangible assets, net, consist of the following (in thousands):

 
June 30,
 
December 31,
 
2015
 
2014
Gross carrying amount:
 
 
 
    Customer contracts
$
12,101

 
$
12,101

    Customer relationships
53,400

 
53,400

    Dedicated acreage
53,350

 
53,350

 
$
118,851

 
$
118,851

Accumulated amortization:
 
 
 
    Customer contracts
$
(12,013
)
 
$
(11,110
)
    Customer relationships
(1,815
)
 
(553
)
    Dedicated acreage
(1,795
)
 
(882
)
 
$
(15,623
)
 
$
(12,545
)
Net carrying amount:
 
 
 
    Customer contracts
$
88

 
$
991

    Customer relationships
51,585

 
52,847

    Dedicated acreage
51,555

 
52,468

 
$
103,228

 
$
106,306



Amortization expense on our intangible assets totaled $1.5 million and $1.2 million for the three months ended June 30, 2015 and 2014, respectively, and $3.1 million and $2.1 million for the six months ended June 30, 2015 and 2014, respectively.
Accrued Expenses and Other Current Liabilities (Notes)
Accrued Expenses and Other Current Liabilities
Accrued Expenses and Other Current Liabilities

Accrued expenses and other current liabilities were as follows (in thousands):
 
 
June 30,
 
December 31,
 
 
2015
 
2014
Accrued capital expenditures
 
$
8,225

 
$
17,134

Accrued expenses
 
5,587

 
7,036

Gas imbalances payable
 
895

 
1,069

Other
 
3,850

 
561

 
 
$
18,557

 
$
25,800

Debt Obligations
Debt Obligations
Debt Obligations

Our outstanding borrowings under the credit facility were (in thousands):
 
June 30,
2015
 
December 31,
2014
Revolving credit facility
$
387,100

 
$
372,950

Other debt
737

 
2,908

Total debt
387,837

 
375,858

Less: current portion
737

 
2,908

Long-term debt
$
387,100

 
$
372,950



On September 5, 2014, the Partnership entered into an amended and restated credit agreement (the "Credit Agreement"), which provides for a maximum borrowing equal to $500.0 million, with the ability to further increase the borrowing capacity subject to lender approval. We can elect to have loans under our Credit Agreement bear interest either at a Eurodollar-based rate plus a margin ranging from 2.00% to 3.25% depending on our total leverage ratio then in effect, or a base rate which is a fluctuating rate per annum equal to the highest of (a) the Federal Funds Rate plus 0.50%, (b) the rate of interest in effect for such day as publicly announced from time to time by Bank of America as its “prime rate”, or (c) the Eurodollar Rate plus 1.00% plus a margin ranging from 1.00% to 2.25% depending on the total leverage ratio then in effect. We also pay a commitment fee of 0.50% per annum on the undrawn portion of the revolving loan.

Our obligations under the Credit Agreement are secured by a first mortgage in favor of the lenders in the majority of our real property. Advances made under the Credit Agreement are guaranteed on a senior unsecured basis by certain of our subsidiaries (the “Guarantors”). These guarantees are full and unconditional and joint and several among the Guarantors. The terms of the Credit Agreement include covenants that restrict our ability to make cash distributions and acquisitions in some circumstances. The remaining principal balance of loans and any accrued and unpaid interest will be due and payable in full on the maturity date, which is September 5, 2019.

The Credit Agreement contains certain financial covenants, including the requirement that our indebtedness not exceed 4.75 times adjusted consolidated EBITDA (except for the current and subsequent two quarters after the consummation of a permitted acquisition, at which time the covenant is increased to 5.25 times adjusted Consolidated EBITDA) and a minimum interest coverage ratio test (not less than 2.50). The financial covenants in our Credit Agreement may limit the amount available to us for borrowing to less than $500.0 million. In addition to the financial covenants described above, the Credit Agreement also contains customary representations and warranties (including those relating to organization and authorization, compliance with laws, absence of defaults, material agreements and litigation) and customary events of default (including those relating to monetary defaults, covenant defaults, cross defaults and bankruptcy events).

For the six months ended June 30, 2015 and 2014, the weighted average interest rate on borrowings under the Credit Agreement was approximately 3.90% and 4.18%, respectively.

As of June 30, 2015, our consolidated total leverage was 5.00 and our interest coverage ratio was 8.48, which were in compliance with the consolidated total leverage ratio and interest coverage ratio tests in accordance with the financial covenants required in the Credit Agreement. At June 30, 2015 and December 31, 2014, letters of credit outstanding under the Credit Agreement were $1.6 million.

Other debt

Other debt represents insurance premium financing in the original amount of $3.3 million bearing interest at 3.95% per annum, which is repayable in equal monthly installments of approximately $0.4 million through the third quarter of 2015.
Partners' Capital
Partners' Capital
Partners’ Capital and Convertible Preferred Units

Our capital accounts are comprised of approximately 1.2% notional general partner interests and 98.8% limited partner interests. Our limited partners have limited rights of ownership as provided for under our partnership agreement and the right to participate in our distributions. Our General Partner manages our operations and participates in our distributions, including certain incentive distributions pursuant to the incentive distribution rights that are non-voting limited partner rights held by our General Partner.

Our General Partner holds and participates in the distribution of Series B Units with such distributions being made in cash or with paid-in-kind Series B Units at the election of the Partnership. The holders of Series B Units are entitled to vote along with the holders of Limited Partner common units and such units will automatically convert to Limited Partner common units on January 31, 2016.

HPIP holds and participates in the distribution of Series A-1 Units with such distributions being made in paid-in-kind Series A-1 Units, cash or a combination thereof, at the election of the board of directors of our General Partner through the distribution for the earlier of (a) the quarter ended March 31, 2016 or (b) the time in which the Series A-1 Units are converted into common units. The Series A-1 Units are entitled to vote along with Limited Partner common unitholders and such units are currently convertible to Limited Partner common units.

Series A-2 Units

On March 30, 2015 and June 30, 2015, we entered into two Series A-2 Convertible Preferred Unit Purchase Agreements with Magnolia Infrastructure Partners, LLC (an affiliate of HPIP) pursuant to which the Partnership issued, in separate private placements, newly-designated Series A-2 Units (the “Series A-2 Units”) representing limited partnership interests in the Partnership. As a result, the Partnership issued a total of 2,571,430 Series A-2 Units for approximately $45.0 million in aggregate proceeds during the six months ended. The Series A-2 Units will participate in distributions of the Partnership along with common units in a manner identical to the existing Series A Units (such previously existing Series A Units now referred to as the "Series A-1 Units" and, together with the Series A-2 Units, the "Series A Units"), with such distributions being made in cash or with paid-in-kind Series A Units at the election of the board of directors of our General Partner. The board of directors of our General Partner has, to date, elected to pay Series A distributions using paid-in-kind Series A Units.

On July 27, 2015, we entered into the Fifth Amendment (the “Fifth Amendment”) to our partnership agreement. The Fifth Amendment grants us the right (the “Call Right”) to require the holders of the Series A-2 Units (the “Series A-2 Holders”) to sell, assign and transfer all or a portion of the then outstanding Series A-2 Units to us for a purchase price of $17.50 per Series A-2 Unit (subject to appropriate adjustment for any equity distribution, subdivision or combination of equity interests in the Partnership). We may exercise the Call Right at any time after January 1, 2016, in connection with our or our affiliate’s acquisition of assets or equity from ArcLightEnergy Partners Fund V, L.P., or one of its affiliates, for a purchase price in excess of $100 million. We may not exercise the Call Right with respect to any Series A-2 Units that a Series A-2 Holder has elected to convert into common units on or prior to the date we have provided notice of our intent to exercise the Call Right, and may not exercise the Call Right if doing so would result in a default under any of our or our affiliates’ financing agreements or obligations.

Equity Offerings

On January 29, 2014, the Partnership and certain of its affiliates entered into an underwriting agreement with Barclays Capital Inc. and UBS Securities LLC (the “Underwriters”), providing for the issuance and sale by the Partnership, and the purchase by the Underwriters, of 3,400,000 Limited Partner common units representing limited partner interests in the Partnership at a price to the public of $26.75 per common unit. The Partnership used the net proceeds of $86.9 million to fund a portion of the Lavaca Acquisition.

Issuance and Exercise of Warrant

Effective February 5, 2014, we issued to AIM Midstream Holdings, LLC a warrant to purchase up to 300,000 Limited Partner common units of the Partnership at an exercise price of $0.01 per common unit (the “Warrant”). The Warrant was exercised on February 21, 2014, resulting in the issuance of approximately 300,000 Limited Partner common units. The value of the Warrant of $7.2 million was determined based on the close price of $23.89 of the Limited Partner common units on the exercise date.

Equity Outstanding

The number of units outstanding as of June 30, 2015 and December 31, 2014, respectively, were as follows (in thousands):
 
June 30,
2015
 
December 31,
2014
Series A convertible preferred units
8,682

 
5,745

Series B convertible units
1,301

 
1,255

Limited Partner common units
22,757

 
22,670

General Partner units
411

 
392



Distributions

We made cash distributions as follows (in thousands):
 
Three months ended June 30,
 
Six months ended June 30,
 
2015
 
2014
 
2015
 
2014
Series A convertible preferred units
—

 
1,338

 
—

 
2,658

Limited Partner common units
10,753

 
5,152

 
21,466

 
10,049

General Partner units
159

 
76

 
317

 
148

General Partners' incentive distribution rights
1,293

 
527

 
2,581

 
937

 
$
12,205

 
$
7,093

 
$
24,364

 
$
13,792



The Partnership executed a fourth amendment to its partnership agreement (the "Fourth Amendment"), which became effective March 30, 2015, related to its outstanding Series A Units. As a result of the Fourth Amendment, distributions on Series A Units will be made with paid-in-kind Series A Units, cash or a combination thereof, at the discretion of the board of directors of our General Partner, which began with the distribution for the three months ended June 30, 2014 and will continue through the distribution for the earlier of (a) the quarter ended March 31, 2016 or (b) the time in which the Series A-1 Units are converted into common units. At June 30, 2015, we have accrued $4.2 million for the paid-in-kind Series A Units. The distributions will be made in the third quarter of 2015.

Net Income (Loss) attributable to Limited Partner Common Units

Net income (loss) is allocated to the General Partner and the limited partners in accordance with their respective ownership percentages, after giving effect to contractual distributions on Series A Units, declared distributions on the Series B Units, common units representing Limited Partner interests and to the General Partner units, including incentive distribution rights. Unvested unit-based payment awards that contain non-forfeitable rights to distributions (whether paid or unpaid) are classified as participating securities and are included in our computation of basic and diluted net income per limited partner unit. Basic and diluted net income (loss) per limited partner unit is calculated by dividing limited partners’ interest in net income (loss) by the weighted average number of outstanding Limited Partner common units during the period. We determined basic and diluted net income (loss) per limited partner unit as follows, (in thousands, except per unit amounts):
 
Three months ended June 30,
 
Six months ended June 30,
 
2015
 
2014
 
2015
 
2014
Net income (loss) from continuing operations
$
(2,002
)
 
$
(1,095
)
 
$
(1,166
)
 
$
(537
)
Less: Net income (loss) attributable to noncontrolling interests
32

 
66

 
46

 
174

Net income (loss) from continuing operations attributable to the Partnership
(2,034
)
 
(1,161
)
 
(1,212
)
 
(711
)
Less:
 
 
 
 
 
 
 
Contractual distributions on Series A Units
4,196

 
3,917

 
7,607

 
7,098

Declared distributions on Series B Units
413

 
560

 
833

 
1,052

General partner's distribution
1,452

 
603

 
2,899

 
1,085

General partner's share in undistributed loss
(234
)
 
(149
)
 
(422
)
 
(262
)
Net income (loss) from continuing operations available to limited partners
(7,861
)
 
(6,092
)
 
(12,129
)
 
(9,684
)
Net income (loss) from discontinued operations available to limited partners
(31
)
 
(499
)
 
(26
)
 
(549
)
Net income (loss) available to limited partners
$
(7,892
)
 
$
(6,591
)
 
$
(12,155
)
 
$
(10,233
)
 
 
 
 
 
 
 
 
Weighted average number of units used in computation of limited partners’ net (loss) income per unit (basic and diluted)
22,757

 
11,139

 
22,730

 
10,496

 
 
 
 
 
 
 
 
Limited partners' net loss per common unit
 
 
 
 
 
 
 
Basic and diluted:
 
 
 
 
 
 
 
Loss from continuing operations
$
(0.35
)
 
$
(0.55
)
 
$
(0.53
)
 
$
(0.92
)
Loss from discontinued operations
—

 
(0.04
)
 
—

 
(0.05
)
Net loss
$
(0.35
)
 
$
(0.59
)
 
$
(0.53
)
 
$
(0.97
)
Long-Term Incentive Plan
Long-Term Incentive Plan
Long-Term Incentive Plan

Our General Partner manages our operations and activities and employs personnel who provide support to our operations. The board of directors of our General Partner grants awards under its long-term incentive plan (“LTIP”) for its employees, consultants and directors who perform services for it or its affiliates. At June 30, 2015 and December 31, 2014, 399,832 and 688,976 units, respectively, were available for future grant under the LTIP.

LTIP awards are subject to forfeiture until the vesting date. The LTIP is administered by the board of directors of our General Partner which, at its discretion, may elect to settle such vested phantom units with a number of units equivalent to the fair market value at the date of vesting in lieu of cash. Although our General Partner has the option to settle in cash upon the vesting of phantom units, our General Partner has not historically settled these awards in cash. Although other types of awards are contemplated under the LTIP, all currently outstanding awards are phantom units without distribution equivalent rights.

Generally, grants issued under the LTIP vest in increments of 25% on each grant date anniversary and do not contain any vesting conditions other than continued employment requirements.

The following table summarizes changes in our unit-based awards during the six months ended June 30, 2015 indicated, in units:
 
 
Six months ended June 30, 2015
 
 
Units
 
Weighted-Average Exercise Price
Outstanding at beginning of period
 
201,132

 
$
19.85

Granted
 
336,613

 
15.78

Forfeited
 
(8,297
)
 
17.24

Vested
 
(126,897
)
 
18.84

Outstanding at end of period
 
402,551

 
$
16.82



The fair value of our phantom units, which are subject to equity classification, is based on the fair value of our limited partner units at the grant date. Compensation costs related to these awards, including amortization, for the three months ended June 30, 2015 and 2014 were $0.6 million and $0.4 million, respectively, and for the six months ended June 30, 2015 and 2014 were $2.2 million and $0.8 million, respectively, which are classified as Equity compensation expense in our condensed consolidated statements of operations and the non-cash portion in partners’ capital on our condensed consolidated balance sheets.

The total fair value of vested units at the time of vesting was $2.3 million and $0.8 million for the six months ended June 30, 2015 and 2014, respectively.

Equity compensation expense related to unvested awards not yet recognized at June 30, 2015 and 2014 was $6.0 million and $3.8 million, respectively, and the weighted average period over which this cost is expected to be recognized as of June 30, 2015 is approximately 3.2 years.
Income Tax (Notes)
Income Tax
Income Taxes

The Partnership is not a taxable entity for U.S. federal income tax purposes or for the majority of states that impose an income tax. However, the State of Texas imposes a margin tax upon the Partnership that is assessed annually against the taxable margin apportioned to Texas. In general, taxes on our net income are borne by our unitholders through the allocation of taxable income. However, one of our subsidiaries, American Midstream Blackwater, LLC, owns a corporate consolidated tax return group which is a separate taxable entity for U.S. federal income tax and state income tax purposes. The provision for income taxes is attributable to the activities of the taxable corporate consolidated tax return group and taxable margin apportioned to Texas.
On October 2, 2014, the Partnership received a “Notice of Beginning of Administrative Proceeding” (the “NBAP”) relating to the Internal Revenue Service (the “IRS”) commencing an audit of the Partnership’s 2012 Form 1065 federal tax return. Under IRS regulations, the Partnership was required to communicate the NBAP to all limited partners who hold less than 1% of its outstanding units ("Non-Notice Partners") within 75 days of receipt of the NBAP. The Partnership filed a Current Report on Form 8-K with the SEC on November 19, 2014, furnishing a copy of the NBAP to its Non-Notice Partners.
On June 19, 2015, the Partnership received a No Adjustments Letter (the "No Adjustments Letter") relating to the IRS audit of Partnership’s 2012 Form 1065 federal tax return. There were no adjustments proposed by the IRS for the Partnership’s 2012 Form 1065 federal tax return. The Partnership filed a Current Report on Form 8-K with the SEC on June 24, 2015, furnishing a copy of the No Adjustments Letter to its Non-Notice Partners.

Income tax expense for the three and six months ended June 30, 2015 was $0.3 million and $0.5 million, respectively, resulting in an effective tax rate of 18.8% and 68.3%, respectively. For the three and six months ended June 30, 2014, income tax expense was $0.1 million and $0.1 million, respectively, resulting in an effective tax rate of 15.8% and 34.6%, respectively.

The effective tax rates for the three and six months ended June 30, 2015 and June 30, 2014, differ from the statutory rate primarily due to the portion of the Partnership's income and loss that is not subject to U. S. federal income taxes, as well as transactions between the Partnership and its taxable subsidiary that generate tax deductions for the taxable subsidiary, which are eliminated in the consolidation of Net income (loss) before income tax (expense) benefit.
Commitments and Contingencies
Commitments and Contingencies
Commitments and Contingencies

Legal proceedings

We are not currently party to any pending litigation or governmental proceedings, other than ordinary routine litigation incidental to our business. While the ultimate impact of any proceedings cannot be predicted with certainty, our management believes that the resolution of any of our pending proceedings will not have a material adverse effect on our financial condition or results of operations.

Environmental matters

We are subject to federal and state laws and regulations relating to the protection of the environment. Environmental risk is inherent to natural gas pipelines, NGL and crude pipelines and operations, as well as terminal operations and we could, at times, be subject to environmental cleanup and enforcement actions. We attempt to manage this environmental risk through appropriate environmental policies and practices to minimize any impact our operations may have on the environment.
Regulatory matters

On December 11, 2014, American Midstream (Midla), LLC ("Midla"), a subsidiary of the Partnership, filed a Stipulation and Agreement (the "Midla Agreement") which resolved all of the outstanding issues between Midla and its customers regarding its interstate pipeline that traverses Louisiana and Mississippi owned and operated by Midla. The parties involved reached agreement in order to provide continued service to Midla’s customers while addressing safety concerns with the existing pipeline.

On April 16, 2015, the FERC approved the Midla Agreement between Midla and its customers allowing Midla to retire the existing 1920s vintage pipeline and replace the existing natural gas service with a new pipeline from Winnsboro, Louisiana to Natchez, Mississippi (the “Midla-Natchez Line”) to serve existing residential, commercial, and industrial customers. Under the Midla Agreement, customers not served by the new Midla-Natchez Line will be connected to other interstate or intrastate pipelines, other gas distribution systems, or offered conversion to propane service.

On June 29, 2015, the Partnership filed with the FERC for authorization to construct the Midla-Natchez pipeline. The Midla-Natchez pipeline will replace the Midla pipeline with a new, 12-inch pipeline extending approximately 50 miles from Winnsboro, Louisiana to Natchez, Mississippi. Subject to FERC approval, construction is expected to commence in the first half of 2016 with service beginning in late 2016. Under the Midla Agreement, Midla will execute long-term agreements to recover its investment in the Midla-Natchez Line.
Related-Party Transactions
Related-Party Transactions
Related-Party Transactions

Employees of our General Partner are assigned to work for us. Where directly attributable, the costs of all compensation, benefits expenses and employer expenses for these employees are charged directly by our General Partner to the Partnership, which, in turn, charges the appropriate subsidiary. Our General Partner does not record any profit or margin for the administrative and operational services charged to us. During the three and six months ended June 30, 2015, administrative and operational services expenses of $7.4 million and $15.0 million, respectively, were charged to us by our General Partner. During the three and six months ended June 30, 2014, administrative and operational services expenses of $5.1 million and $10.1 million, respectively, were charged to us by our General Partner. For the three and six months ended June 30, 2015, our General Partner incurred approximately $0.5 million and $0.9 million, respectively, of costs primarily associated with certain business development activities. For the three and six months ended June 30, 2014, our General Partner incurred costs primarily associated with certain business development activities in amounts equal to approximately $0.2 million and $0.7 million, respectively.

For the three and six months ended June 30, 2015, the Partnership and an affiliate of HPIP entered into arrangements under which the affiliate reimbursed the Partnership for right-of-ways purchased on the affiliate's behalf for approximately $1.1 million and $3.9 million, respectively.

During the second quarter of 2014, the Partnership and an affiliate of its General Partner entered into a Management Service Fee arrangement under which the affiliate pays a monthly fee to reimburse the Partnership for administrative expenses incurred on the affiliates' behalf. During the three and six months ended June 30, 2015, the Partnership recognized $0.4 million and $0.9 million, in management fee income, respectively, and $0.2 million during the three and six months ended June 30, 2014 that has been recorded as a reduction to Selling, general and administrative expenses.
Reporting Segments
Reporting Segments
Reporting Segments

Our operations are located in the United States and are organized into three reporting segments: i) Gathering and Processing, ii) Transmission and iii) Terminals.

Gathering and Processing

Our Gathering and Processing segment provides “wellhead-to-market” services to producers of natural gas and oil, which include transporting raw natural gas from the wellhead through gathering systems, treating the raw natural gas, processing raw natural gas to separate the NGLs from the natural gas, fractionating NGLs, and selling or delivering pipeline-quality natural gas and NGLs to various markets and pipeline systems.

Transmission

Our Transmission segment transports and delivers natural gas from producing wells, receipt points or pipeline interconnects for shippers and other customers, which include local distribution companies, utilities and industrial, commercial and power generation customers.

Terminals

Our Terminals segment provides above-ground storage services at our marine terminals that support various commercial customers, including commodity brokers, refiners and chemical manufacturers to store a range of products, including petroleum products, distillates, chemicals and agricultural products.

These segments are monitored separately by management for performance and are consistent with the Partnership's internal financial reporting. These segments have been identified based on the differing products and services, regulatory environment and the expertise required for these operations. Gross margin is the performance measure utilized by management to monitor the business of each segment.

The following tables set forth our segment information for the three and six months ended June 30, 2015 and 2014 (in thousands):
 
 
Three months ended June 30, 2015
 
Gathering
and
Processing
 
Transmission
 
Terminals
 
Total
Revenue
$
50,439

 
$
12,423

 
$
4,336

 
$
67,198

Gain (loss) on commodity derivatives, net
311

 
—

 
—

 
311

Total revenue
50,750

 
12,423

 
4,336

 
67,509

Operating expenses:
 
 
 
 
 
 
 
Purchases of natural gas, NGL's and condensate
30,272

 
3,062

 
—

 
33,334

Direct operating expenses
9,130

 
3,253

 
1,584

 
13,967

Selling, general and administrative expenses
 
 
 
 
 
 
5,571

Equity compensation expense
 
 
 
 
 
 
550

Depreciation, amortization and accretion expense
 
 
 
 
 
 
9,250

Total operating expenses
 
 
 
 
 
 
62,672

Gain (loss) on sale of assets, net
 
 
 
 
 
 
(2,970
)
Interest expense
 
 
 
 
 
 
(3,556
)
Earnings in unconsolidated affiliates
 
 
 
 
 
 
4

Income tax benefit (expense)
 
 
 
 
 
 
(317
)
Gain (loss) from discontinued operations, net of tax
 
 
 
 
 
 
(31
)
Net income (loss)
 
 
 
 
 
 
(2,033
)
Less: Net income (loss) attributable to noncontrolling interests
 
 
 
 
 
 
32

Net income (loss) attributable to the Partnership
 
 
 
 
 
 
$
(2,065
)
 
 
 
 
 
 
 
 
Segment gross margin (a)
$
20,219

 
$
9,333

 
$
2,752

 
$
32,304


 
Three months ended June 30, 2014
 
Gathering
and
Processing
 
Transmission
 
Terminals
 
Total
Revenue
$
50,015

 
$
23,960

 
$
3,898

 
$
77,873

Gain (loss) on commodity derivatives, net
(193
)
 
—

 
—

 
(193
)
Total revenue
49,822

 
23,960

 
3,898

 
77,680

Operating expenses:
 
 
 
 
 
 
 
Purchases of natural gas, NGL's and condensate
39,238

 
14,580

 
—

 
53,818

Direct operating expenses
5,746

 
3,736

 
1,562

 
11,044

Selling, general and administrative expenses
 
 
 
 
 
 
5,637

Equity compensation expense
 
 
 
 
 
 
435

Depreciation, amortization and accretion expense
 
 
 
 
 
 
6,012

Total operating expenses
 
 
 
 
 
 
76,946

Interest expense
 
 
 
 
 
 
(1,680
)
Income tax benefit (expense)
 
 
 
 
 
 
(149
)
Gain (loss) from discontinued operations, net of tax
 
 
 
 
 
 
(506
)
Net income (loss)
 
 
 
 
 
 
(1,601
)
Less: Net income (loss) attributable to noncontrolling interests
 
 
 
 
 
 
66

Net income (loss) attributable to the Partnership
 
 
 
 
 
 
$
(1,667
)
 
 
 
 
 
 
 
 
Segment gross margin (a)
$
10,481

 
$
9,350

 
$
2,336

 
$
22,167


 
Six months ended June 30, 2015
 
Gathering
and
Processing
 
Transmission
 
Terminals
 
Total
Revenue
$
98,888

 
$
24,171

 
$
8,601

 
$
131,660

Gain (loss) on commodity derivatives, net
458

 
—

 
—

 
458

Total revenue
99,346

 
24,171

 
8,601

 
132,118

Operating expenses:
 
 
 
 
 
 
 
Purchases of natural gas, NGL's and condensate
57,590

 
4,721

 
—

 
62,311

Direct operating expenses
18,223

 
6,432

 
3,179

 
27,834

Selling, general and administrative expenses
 
 
 
 
 
 
12,506

Equity compensation expense
 
 
 
 
 
 
2,248

Depreciation, amortization and accretion expense
 
 
 
 
 
 
18,939

Total operating expenses
 
 
 
 
 
 
123,838

Gain (loss) on sale of assets, net
 
 
 
 
 
 
(2,978
)
Interest expense
 
 
 
 
 
 
(6,166
)
Earnings in unconsolidated affiliates
 
 
 
 
 
 
171

Income tax benefit (expense)
 
 
 
 
 
 
(473
)
Gain (loss) from discontinued operations, net of tax
 
 
 
 
 
 
(26
)
Net income (loss)
 
 
 
 
 
 
(1,192
)
Less: Net income (loss) attributable to noncontrolling interests
 
 
 
 
 
 
46

Net income (loss) attributable to the Partnership
 
 
 
 
 
 
$
(1,238
)
 
 
 
 
 
 
 
 
Segment gross margin (a)
$
41,265

 
$
19,394

 
$
5,422

 
$
66,081


 
Six months ended June 30, 2014
 
Gathering
and
Processing
 
Transmission
 
Terminals
 
Total
Revenue
$
101,641

 
$
49,088

 
$
7,512

 
$
158,241

Gain (loss) on commodity derivatives, net
(323
)
 
—

 
—

 
(323
)
Total revenue
101,318

 
49,088

 
7,512

 
157,918

Operating expenses:
 
 
 
 
 
 
 
Purchases of natural gas, NGL's and condensate
80,359

 
28,680

 
—

 
109,039

Direct operating expenses
9,914

 
6,854

 
3,237

 
20,005

Selling, general and administrative expenses
 
 
 
 
 
 
11,230

Equity compensation expense
 
 
 
 
 
 
795

Depreciation, amortization and accretion expense
 
 
 
 
 
 
13,644

Total operating expenses
 
 
 
 
 
 
154,713

Gain (loss) on sale of assets, net
 
 
 
 
 
 
(21
)
Interest expense
 
 
 
 
 
 
(3,583
)
Income tax benefit (expense)
 
 
 
 
 
 
(138
)
Gain (loss) from discontinued operations, net of tax
 
 
 
 
 
 
(556
)
Net income (loss)
 
 
 
 
 
 
(1,093
)
Less: Net income (loss) attributable to noncontrolling interests
 
 
 
 
 
 
174

Net income (loss) attributable to the Partnership
 
 
 
 
 
 
$
(1,267
)
 
 
 
 
 
 
 
 
Segment gross margin (a)
$
20,610

 
$
20,363

 
$
4,275

 
$
45,248


 
June 30,
 
December 31,
 
2015
 
2014
Segment assets:
 
 
 
Gathering and Processing
$
684,359

 
$
686,395

Transmission
128,291

 
132,767

Terminals
83,766

 
71,180

Other (b)
40,231

 
26,302

Total assets
$
936,647

 
$
916,644


(a)
Segment gross margin for our Gathering and Processing segment consists of revenue and realized gains or (losses) on commodity derivatives less purchases of natural gas, NGLs and condensate and revenue from construction, operating and maintenance agreements (“COMA”). Segment gross margin for our Transmission segment consists of revenue, less purchases of natural gas and COMA. Segment gross margin for our Terminals segment consists of revenue, less direct operating expenses. Gross margin consists of the sum of the segment gross margin amounts for each of these segments. As an indicator of our operating performance, gross margin should not be considered an alternative to, or more meaningful than, net income or cash flow from operations as determined in accordance with GAAP. Our gross margin may not be comparable to a similarly titled measure of another company because other entities may not calculate gross margin in the same manner.
(b)
Other assets not allocable to segments consist of investment in unconsolidated affiliates, corporate leasehold improvements, and other assets.
Subsequent Events
Subsequent Events
Subsequent Events

GP Contribution

In connection with the issuance of the Series A-2 Units discussed in Note 13, the General Partner exercised its right to maintain its general partner interest at 1.3%. As a result, we received proceeds of $0.4 million from our General Partner as consideration for 21,975 additional notional general partner units in July of 2015.

Distribution

On July 23, 2015, we announced a distribution of $0.4725 per unit for the quarter ended June 30, 2015, or $1.89 per unit on an annualized basis, payable on August 14, 2015 to unitholders of record on August 5, 2015.
Organization and Basis of Presentation (Policies)
Nature of Business 

Nature of Business

We are engaged in the business of gathering, treating, processing, and transporting natural gas, fractionating NGLs, transporting oil and storing specialty chemical products through our ownership and operation of twelve gathering systems, five processing facilities, three fractionation facilities, four marine terminal sites, three interstate pipelines, five intrastate pipelines and one oil pipeline. We also own a 66.7% non-operating interest in Main Pass Oil Gathering, LP ("MPOG"), a crude oil gathering and processing system, a 50% undivided, non-operating interest in the Burns Point Plant, a natural gas processing plant, and a 46% non-operated interest in Mesquite, an off-spec condensate fractionation project. Our primary assets, which are strategically located in Alabama, Georgia, Louisiana, Maryland, Mississippi, North Dakota, Tennessee and Texas, provide critical infrastructure that links producers of natural gas, NGLs, condensate and specialty chemicals to numerous intermediate and end-use markets. We currently operate more than 3,000 miles of pipelines that gather and transport over 1 Bcf/d of natural gas and operate approximately 1.7 million barrels of storage capacity across four marine terminal sites.

Basis of Presentation 
Basis of Presentation

These unaudited condensed consolidated financial statements have been prepared in accordance with generally accepted accounting principles ("GAAP") for interim financial information. Accordingly, they do not include all of the information and footnotes required by GAAP for complete financial statements. The year-end balance sheet data was derived from consolidated audited financial statements but does not include disclosures required by GAAP for annual periods. The information furnished herein reflects all normal recurring adjustments that are, in the opinion of management, necessary for a fair statement of financial position and results of operations for the respective interim periods.

Our financial results for the three and six months ended June 30, 2015, are not necessarily indicative of the results that may be expected for the full year ended December 31, 2015. These unaudited condensed consolidated financial statements should be read in conjunction with our consolidated financial statements and notes thereto included in our Annual Report on Form 10-K for the year ended December 31, 2014 (“Annual Report”) filed with the Securities and Exchange Commission (the "SEC") on March 10, 2015.
Consolidation Policy 
Consolidation Policy

The accompanying condensed consolidated financial statements include accounts of American Midstream Partners, LP, and its controlled subsidiaries. All significant inter-company accounts and transactions have been eliminated in the preparation of the accompanying condensed consolidated financial statements. We hold a 50% undivided interest in the Burns Point natural gas processing plant in which we are responsible for our proportionate share of the costs and expenses of the facility. Our condensed consolidated financial statements reflect our proportionate share of the revenues, expenses, assets and liabilities of this undivided interest. As of June 30, 2015, we also hold a 92.2% undivided interest in the Chatom Processing and Fractionation facility (the "Chatom System"). Our condensed consolidated financial statements reflect the accounts of the Chatom System and the interests in the Chatom System held by non-affiliated working interest owners are reflected as noncontrolling interests in the Partnership's condensed consolidated financial statements.

The Partnership accounts for its 66.7% non-operated interest in MPOG and its 46.0% non-operated interest in Mesquite under the equity method.
Use of Estimates 
Use of Estimates

When preparing condensed consolidated financial statements in conformity with GAAP, management must make estimates and assumptions based on information available at the time. These estimates and assumptions affect the reported amounts of assets, liabilities, revenues and expenses, as well as the disclosures of contingent assets and liabilities as of the date of the financial statements. Estimates and assumptions are based on information available at the time such estimates and assumptions are made. Adjustments made with respect to the use of these estimates and assumptions often relate to information not previously available. Uncertainties with respect to such estimates and assumptions are inherent in the preparation of financial statements. Estimates and assumptions are used in, among other things i) estimating unbilled revenues, product purchases and operating and general and administrative costs, ii) developing fair value estimates, including assumptions for future cash flows and discount rates, iii) analyzing long-lived assets, goodwill and intangible assets for possible impairment, iv) estimating the useful lives of assets and v) determining amounts to accrue for contingencies, guarantees and indemnifications. Actual results, therefore, could differ materially from estimated amounts.
Acquisitions and Divestitures (Tables)
Schedule of Business Acquisitions, by Acquisition 
The following table summarizes the fair value of consideration transferred to acquire Costar and the allocation of that amount to the assets acquired, liabilities assumed and the noncontrolling interest based upon their respective fair values as of the acquisition date (in thousands).

Fair value of consideration transferred:
 
Cash
$
258,001

Limited partner common units
147,296

Total fair value of consideration
$
405,297

Schedule of Recognized Identified Assets Acquired and Liabilities Assumed 
Fair Value of assets acquired, liabilities assumed and noncontrolling interest:
 
Working capital
$
8,152

Property, plant and equipment:
 
Processing plants
$
48,357

Pipelines
128,799

Land
1,244

Buildings
682

Equipment
9,827

Construction in progress
16,146

Total property, plant and equipment
205,055

Investment in unconsolidated affiliate
11,884

Intangible assets:
 
Customer relationships
53,400

Dedicated acreage
32,000

Goodwill
95,025

Noncontrolling interest
(219
)
 
$
405,297

The following table summarizes the final allocation of the purchase price to the assets acquired based upon their respective fair values as of the acquisition date (in thousands):

Property, plant and equipment:
 
Land
$
2

Pipelines
58,737

Equipment
753

Total property, plant and equipment
59,492

Intangible assets
21,350

Goodwill
23,567

Total cash consideration
$
104,409

Discontinued Operations Operation of discontinued operations (Tables)
Schedule of Disposal Groups, Including Discontinued Operations, Income Statement, Balance Sheet and Additional Disclosures
The following table presents the revenue, expense and gain (loss) from operations of disposal groups associated with the assets classified as held for sale for the three and six months ended June 30, 2015 and 2014 (in thousands, except per unit amounts):
 
Three months ended June 30,
 
Six months ended June 30,
 
2015
 
2014
 
2015
 
2014
Revenue
$
10

 
$
212

 
$
74

 
$
449

Expense
(61
)
 
(268
)
 
(116
)
 
(545
)
Loss on impairment of property, plant and equipment
—

 
(673
)
 
—

 
(673
)
Loss on sale of assets
—

 
(65
)
 
—

 
(87
)
Income tax benefit
20

 
288

 
16

 
300

Income (loss) from operations of disposal groups, net of tax
$
(31
)
 
$
(506
)
 
$
(26
)
 
$
(556
)
Limited partners' net income (loss) per unit from discontinued operations (basic and diluted)
$
—

 
$
(0.04
)
 
$
—

 
$
(0.05
)
Other Current Assets (Tables)
Other Current Assets
Other current assets consist of the following (in thousands):
 
June 30,
 
December 31,
 
2015
 
2014
Prepaid insurance
$
1,922

 
$
4,162

Restricted cash
—

 
6,475

Other current assets
6,212

 
4,917

 
$
8,134

 
$
15,554


Restricted cash of $6.5 million as of December 31, 2014 consisted of a cash-backed letter of credit related to Costar operations that the Partnership was contractually obligated to maintain after the Costar Acquisition. The Partnership was released from this obligation in January 2015. Other current assets primarily consist of natural gas imbalances and amounts due from related parties.
Derivatives (Tables)
Fair value associated with commodity derivative instruments 
As of June 30, 2015 and December 31, 2014, the value associated with our commodity derivatives, interest rate swap, and weather derivative were recorded in our condensed consolidated balance sheets, under the captions as follows (in thousands):
 
 
Gross Risk Management Assets
 
Gross Risk Management Liabilities
 
Net Risk Management Assets (Liabilities)
Balance Sheet Classification
 
June 30,
2015
 
December 31, 2014
 
June 30,
2015
 
December 31, 2014
 
June 30,
2015
 
December 31, 2014
Current
 
$
1,155

 
$
688

 
$
—

 
$
—

 
$
1,155

 
$
688

Noncurrent
 
—

 
—

 
—

 
—

 
—

 
—

Total assets
 
$
1,155

 
$
688

 
$
—

 
$
—

 
$
1,155

 
$
688

 
 
 
 
 
 
 
 
 
 
 
 
 
Current
 
$
—

 
$
—

 
$
(69
)
 
$
(215
)
 
$
(69
)
 
$
(215
)
Noncurrent
 
—

 
—

 
—

 
—

 
—

 
—

Total liabilities
 
$
—

 
$
—

 
$
(69
)
 
$
(215
)
 
$
(69
)
 
$
(215
)
Realized and unrealized gains (losses) with commodity and interst rate derivative instruments 
For the three and six months ended June 30, 2015 and 2014, respectively, the realized and unrealized gains (losses) associated with our commodity derivatives, interest rate swap instrument and weather derivative were recorded in our condensed consolidated statements of operations, under the captions as follows (in thousands):
 
Three months ended June 30,
 
Six months ended June 30,
 
Gain (loss) on derivatives
 
Gain (loss) on derivatives
Statement of Operations Classification
Realized
 
Unrealized
 
Realized
 
Unrealized
2015
 
 
 
 
 
 
 
Gain (loss) on commodity derivatives, net
$
252

 
$
59

 
$
391

 
$
67

Interest expense
(101
)
 
98

 
(203
)
 
146

Direct operating expenses
(234
)
 
—

 
(475
)
 
—

Total
$
(83
)
 
$
157

 
$
(287
)
 
$
213

2014
 
 
 
 
 
 
 
Gain (loss) on commodity derivatives, net
$
(80
)
 
$
(113
)
 
$
(182
)
 
$
(141
)
Interest expense
(109
)
 
38

 
(213
)
 
28

Direct operating expenses
(269
)
 
—

 
(553
)
 
—

Total
$
(458
)
 
$
(75
)
 
$
(948
)
 
$
(113
)
Fair Value Measurement (Tables)
Fair value of financial instruments

The following table sets forth by level within the fair value hierarchy, our commodity derivative instruments and interest rate swap, included as part of Risk management assets and Risk management liabilities within our condensed consolidated balance sheets, that were measured at fair value on a recurring basis as of June 30, 2015 and December 31, 2014 (in thousands):
 
Carrying
Amount
 
Estimated Fair Value of the Asset (Liability)
 
Level 1
 
Level 2
 
Level 3
 
Total
Commodity derivative instruments, net
 
 
 
 
 
 
 
 
 
June 30, 2015
$
353

 
$
—

 
$
353

 
$
—

 
$
353

December 31, 2014
286

 
—

 
286

 
—

 
286

Interest rate swap
 
 
 
 
 
 
 
 
 
June 30, 2015
$
(69
)
 
$
—

 
$
(69
)
 
$
—

 
$
(69
)
December 31, 2014
(215
)
 
—

 
(215
)
 
—

 
(215
)
Property, Plant and Equipment (Tables)
Property, plant and equipment, net
Property, plant and equipment, net, as of June 30, 2015 and December 31, 2014 were as follows (in thousands):
 
Useful Life
(in years)
 
June 30,
2015
 
December 31,
2014
Land
N/A
 
$
5,282

 
$
5,282

Construction in progress
N/A
 
90,085

 
77,550

Base gas
N/A
 
1,108

 
1,108

Buildings and improvements
4 to 40
 
9,708

 
6,855

Processing and treating plants
8 to 40
 
81,404

 
80,837

Pipelines
3 to 40
 
479,749

 
451,341

Compressors
4 to 20
 
30,506

 
24,548

Dock
20 to 40
 
8,105

 
8,072

Tanks, truck rack and piping
20 to 40
 
32,826

 
30,079

Equipment
8 to 20
 
9,474

 
8,855

Computer software
5
 
3,856

 
3,490

Total property, plant and equipment
 
 
752,103

 
698,017

Accumulated depreciation
 
 
(129,513
)
 
(115,835
)
Property, plant and equipment, net
 
 
$
622,590

 
$
582,182

Goodwill and Intangible Assets, Net (Tables)
Schedule of Finite-Lived Intangible Assets
Intangible assets, net, consist of the following (in thousands):

 
June 30,
 
December 31,
 
2015
 
2014
Gross carrying amount:
 
 
 
    Customer contracts
$
12,101

 
$
12,101

    Customer relationships
53,400

 
53,400

    Dedicated acreage
53,350

 
53,350

 
$
118,851

 
$
118,851

Accumulated amortization:
 
 
 
    Customer contracts
$
(12,013
)
 
$
(11,110
)
    Customer relationships
(1,815
)
 
(553
)
    Dedicated acreage
(1,795
)
 
(882
)
 
$
(15,623
)
 
$
(12,545
)
Net carrying amount:
 
 
 
    Customer contracts
$
88

 
$
991

    Customer relationships
51,585

 
52,847

    Dedicated acreage
51,555

 
52,468

 
$
103,228

 
$
106,306

Accrued Expenses and Other Current Liabilities (Tables)
Schedule of Accrued Liabilities
Accrued expenses and other current liabilities were as follows (in thousands):
 
 
June 30,
 
December 31,
 
 
2015
 
2014
Accrued capital expenditures
 
$
8,225

 
$
17,134

Accrued expenses
 
5,587

 
7,036

Gas imbalances payable
 
895

 
1,069

Other
 
3,850

 
561

 
 
$
18,557

 
$
25,800

Debt Obligations (Tables)
Outstanding borrowings under the credit facility
Our outstanding borrowings under the credit facility were (in thousands):
 
June 30,
2015
 
December 31,
2014
Revolving credit facility
$
387,100

 
$
372,950

Other debt
737

 
2,908

Total debt
387,837

 
375,858

Less: current portion
737

 
2,908

Long-term debt
$
387,100

 
$
372,950

Partners' Capital (Tables)
Numbers of units outstanding 
The number of units outstanding as of June 30, 2015 and December 31, 2014, respectively, were as follows (in thousands):
 
June 30,
2015
 
December 31,
2014
Series A convertible preferred units
8,682

 
5,745

Series B convertible units
1,301

 
1,255

Limited Partner common units
22,757

 
22,670

General Partner units
411

 
392

Distributions

We made cash distributions as follows (in thousands):
 
Three months ended June 30,
 
Six months ended June 30,
 
2015
 
2014
 
2015
 
2014
Series A convertible preferred units
—

 
1,338

 
—

 
2,658

Limited Partner common units
10,753

 
5,152

 
21,466

 
10,049

General Partner units
159

 
76

 
317

 
148

General Partners' incentive distribution rights
1,293

 
527

 
2,581

 
937

 
$
12,205

 
$
7,093

 
$
24,364

 
$
13,792

Schedule of Calulation for Net Income (Loss) Per Limited Partner Unit 
We determined basic and diluted net income (loss) per limited partner unit as follows, (in thousands, except per unit amounts):
 
Three months ended June 30,
 
Six months ended June 30,
 
2015
 
2014
 
2015
 
2014
Net income (loss) from continuing operations
$
(2,002
)
 
$
(1,095
)
 
$
(1,166
)
 
$
(537
)
Less: Net income (loss) attributable to noncontrolling interests
32

 
66

 
46

 
174

Net income (loss) from continuing operations attributable to the Partnership
(2,034
)
 
(1,161
)
 
(1,212
)
 
(711
)
Less:
 
 
 
 
 
 
 
Contractual distributions on Series A Units
4,196

 
3,917

 
7,607

 
7,098

Declared distributions on Series B Units
413

 
560

 
833

 
1,052

General partner's distribution
1,452

 
603

 
2,899

 
1,085

General partner's share in undistributed loss
(234
)
 
(149
)
 
(422
)
 
(262
)
Net income (loss) from continuing operations available to limited partners
(7,861
)
 
(6,092
)
 
(12,129
)
 
(9,684
)
Net income (loss) from discontinued operations available to limited partners
(31
)
 
(499
)
 
(26
)
 
(549
)
Net income (loss) available to limited partners
$
(7,892
)
 
$
(6,591
)
 
$
(12,155
)
 
$
(10,233
)
 
 
 
 
 
 
 
 
Weighted average number of units used in computation of limited partners’ net (loss) income per unit (basic and diluted)
22,757

 
11,139

 
22,730

 
10,496

 
 
 
 
 
 
 
 
Limited partners' net loss per common unit
 
 
 
 
 
 
 
Basic and diluted:
 
 
 
 
 
 
 
Loss from continuing operations
$
(0.35
)
 
$
(0.55
)
 
$
(0.53
)
 
$
(0.92
)
Loss from discontinued operations
—

 
(0.04
)
 
—

 
(0.05
)
Net loss
$
(0.35
)
 
$
(0.59
)
 
$
(0.53
)
 
$
(0.97
)
Long-Term Incentive Plan (Tables)
Table summarizes our unit-based awards
The following table summarizes changes in our unit-based awards during the six months ended June 30, 2015 indicated, in units:
 
 
Six months ended June 30, 2015
 
 
Units
 
Weighted-Average Exercise Price
Outstanding at beginning of period
 
201,132

 
$
19.85

Granted
 
336,613

 
15.78

Forfeited
 
(8,297
)
 
17.24

Vested
 
(126,897
)
 
18.84

Outstanding at end of period
 
402,551

 
$
16.82

Reporting Segments (Tables)
Segment information
The following tables set forth our segment information for the three and six months ended June 30, 2015 and 2014 (in thousands):
 
 
Three months ended June 30, 2015
 
Gathering
and
Processing
 
Transmission
 
Terminals
 
Total
Revenue
$
50,439

 
$
12,423

 
$
4,336

 
$
67,198

Gain (loss) on commodity derivatives, net
311

 
—

 
—

 
311

Total revenue
50,750

 
12,423

 
4,336

 
67,509

Operating expenses:
 
 
 
 
 
 
 
Purchases of natural gas, NGL's and condensate
30,272

 
3,062

 
—

 
33,334

Direct operating expenses
9,130

 
3,253

 
1,584

 
13,967

Selling, general and administrative expenses
 
 
 
 
 
 
5,571

Equity compensation expense
 
 
 
 
 
 
550

Depreciation, amortization and accretion expense
 
 
 
 
 
 
9,250

Total operating expenses
 
 
 
 
 
 
62,672

Gain (loss) on sale of assets, net
 
 
 
 
 
 
(2,970
)
Interest expense
 
 
 
 
 
 
(3,556
)
Earnings in unconsolidated affiliates
 
 
 
 
 
 
4

Income tax benefit (expense)
 
 
 
 
 
 
(317
)
Gain (loss) from discontinued operations, net of tax
 
 
 
 
 
 
(31
)
Net income (loss)
 
 
 
 
 
 
(2,033
)
Less: Net income (loss) attributable to noncontrolling interests
 
 
 
 
 
 
32

Net income (loss) attributable to the Partnership
 
 
 
 
 
 
$
(2,065
)
 
 
 
 
 
 
 
 
Segment gross margin (a)
$
20,219

 
$
9,333

 
$
2,752

 
$
32,304


 
Three months ended June 30, 2014
 
Gathering
and
Processing
 
Transmission
 
Terminals
 
Total
Revenue
$
50,015

 
$
23,960

 
$
3,898

 
$
77,873

Gain (loss) on commodity derivatives, net
(193
)
 
—

 
—

 
(193
)
Total revenue
49,822

 
23,960

 
3,898

 
77,680

Operating expenses:
 
 
 
 
 
 
 
Purchases of natural gas, NGL's and condensate
39,238

 
14,580

 
—

 
53,818

Direct operating expenses
5,746

 
3,736

 
1,562

 
11,044

Selling, general and administrative expenses
 
 
 
 
 
 
5,637

Equity compensation expense
 
 
 
 
 
 
435

Depreciation, amortization and accretion expense
 
 
 
 
 
 
6,012

Total operating expenses
 
 
 
 
 
 
76,946

Interest expense
 
 
 
 
 
 
(1,680
)
Income tax benefit (expense)
 
 
 
 
 
 
(149
)
Gain (loss) from discontinued operations, net of tax
 
 
 
 
 
 
(506
)
Net income (loss)
 
 
 
 
 
 
(1,601
)
Less: Net income (loss) attributable to noncontrolling interests
 
 
 
 
 
 
66

Net income (loss) attributable to the Partnership
 
 
 
 
 
 
$
(1,667
)
 
 
 
 
 
 
 
 
Segment gross margin (a)
$
10,481

 
$
9,350

 
$
2,336

 
$
22,167


 
Six months ended June 30, 2015
 
Gathering
and
Processing
 
Transmission
 
Terminals
 
Total
Revenue
$
98,888

 
$
24,171

 
$
8,601

 
$
131,660

Gain (loss) on commodity derivatives, net
458

 
—

 
—

 
458

Total revenue
99,346

 
24,171

 
8,601

 
132,118

Operating expenses:
 
 
 
 
 
 
 
Purchases of natural gas, NGL's and condensate
57,590

 
4,721

 
—

 
62,311

Direct operating expenses
18,223

 
6,432

 
3,179

 
27,834

Selling, general and administrative expenses
 
 
 
 
 
 
12,506

Equity compensation expense
 
 
 
 
 
 
2,248

Depreciation, amortization and accretion expense
 
 
 
 
 
 
18,939

Total operating expenses
 
 
 
 
 
 
123,838

Gain (loss) on sale of assets, net
 
 
 
 
 
 
(2,978
)
Interest expense
 
 
 
 
 
 
(6,166
)
Earnings in unconsolidated affiliates
 
 
 
 
 
 
171

Income tax benefit (expense)
 
 
 
 
 
 
(473
)
Gain (loss) from discontinued operations, net of tax
 
 
 
 
 
 
(26
)
Net income (loss)
 
 
 
 
 
 
(1,192
)
Less: Net income (loss) attributable to noncontrolling interests
 
 
 
 
 
 
46

Net income (loss) attributable to the Partnership
 
 
 
 
 
 
$
(1,238
)
 
 
 
 
 
 
 
 
Segment gross margin (a)
$
41,265

 
$
19,394

 
$
5,422

 
$
66,081


 
Six months ended June 30, 2014
 
Gathering
and
Processing
 
Transmission
 
Terminals
 
Total
Revenue
$
101,641

 
$
49,088

 
$
7,512

 
$
158,241

Gain (loss) on commodity derivatives, net
(323
)
 
—

 
—

 
(323
)
Total revenue
101,318

 
49,088

 
7,512

 
157,918

Operating expenses:
 
 
 
 
 
 
 
Purchases of natural gas, NGL's and condensate
80,359

 
28,680

 
—

 
109,039

Direct operating expenses
9,914

 
6,854

 
3,237

 
20,005

Selling, general and administrative expenses
 
 
 
 
 
 
11,230

Equity compensation expense
 
 
 
 
 
 
795

Depreciation, amortization and accretion expense
 
 
 
 
 
 
13,644

Total operating expenses
 
 
 
 
 
 
154,713

Gain (loss) on sale of assets, net
 
 
 
 
 
 
(21
)
Interest expense
 
 
 
 
 
 
(3,583
)
Income tax benefit (expense)
 
 
 
 
 
 
(138
)
Gain (loss) from discontinued operations, net of tax
 
 
 
 
 
 
(556
)
Net income (loss)
 
 
 
 
 
 
(1,093
)
Less: Net income (loss) attributable to noncontrolling interests
 
 
 
 
 
 
174

Net income (loss) attributable to the Partnership
 
 
 
 
 
 
$
(1,267
)
 
 
 
 
 
 
 
 
Segment gross margin (a)
$
20,610

 
$
20,363

 
$
4,275

 
$
45,248


 
June 30,
 
December 31,
 
2015
 
2014
Segment assets:
 
 
 
Gathering and Processing
$
684,359

 
$
686,395

Transmission
128,291

 
132,767

Terminals
83,766

 
71,180

Other (b)
40,231

 
26,302

Total assets
$
936,647

 
$
916,644


(a)
Segment gross margin for our Gathering and Processing segment consists of revenue and realized gains or (losses) on commodity derivatives less purchases of natural gas, NGLs and condensate and revenue from construction, operating and maintenance agreements (“COMA”). Segment gross margin for our Transmission segment consists of revenue, less purchases of natural gas and COMA. Segment gross margin for our Terminals segment consists of revenue, less direct operating expenses. Gross margin consists of the sum of the segment gross margin amounts for each of these segments. As an indicator of our operating performance, gross margin should not be considered an alternative to, or more meaningful than, net income or cash flow from operations as determined in accordance with GAAP. Our gross margin may not be comparable to a similarly titled measure of another company because other entities may not calculate gross margin in the same manner.
(b)
Other assets not allocable to segments consist of investment in unconsolidated affiliates, corporate leasehold improvements, and other assets.
Organization and Basis of Presentation (Details)
0 Months Ended 6 Months Ended
Jun. 29, 2015
mi
Jun. 30, 2015
mi
billion_cubic_feet_per_day
bbl
facility
gathering_system
pipeline
Collaborative Arrangements and Non-collaborative Arrangement Transactions [Line Items]
 
 
General Partners' Capital Account, Percentage
 
95.00% 
Limited Partners' Capital Account, Percentage
 
5.00% 
Number of Gathering Systems
 
12 
Number of Processing Facilities
 
5 
Number of Fractionation Facilities
 
3 
Number of Marine Terminal Sites
 
4 
Number of Interstate Pipelines
 
3 
Number of Intrastate Pipelines
 
5 
Number of Oil Pipelines
 
1 
Length Of Pipeline
50 
3,000 
Volume of Natural Gas, Operating
 
1 
Million barrels of storage capacity
 
1,700,000 
Noncontrolling Interest, Ownership Percentage by Parent
 
92.20% 
Burns Point Plant [Member]
 
 
Collaborative Arrangements and Non-collaborative Arrangement Transactions [Line Items]
 
 
Percentage of voting interests acquired
 
50.00% 
Mesquite [Member]
 
 
Collaborative Arrangements and Non-collaborative Arrangement Transactions [Line Items]
 
 
Equity Method Investment, Ownership Percentage
 
46.00% 
MPOG [Member]
 
 
Collaborative Arrangements and Non-collaborative Arrangement Transactions [Line Items]
 
 
Equity Method Investment, Ownership Percentage
 
66.70% 
Acquisitions and Divestitures Lavaca Acquisition (Details) (USD $)
In Thousands, unless otherwise specified
0 Months Ended 3 Months Ended 6 Months Ended 0 Months Ended 3 Months Ended 6 Months Ended 6 Months Ended
Jun. 29, 2015
mi
Jun. 30, 2015
Jun. 30, 2014
Jun. 30, 2015
mi
Jun. 30, 2014
Dec. 31, 2014
Jan. 31, 2014
Lavaca [Member]
mi
Jun. 30, 2015
Lavaca [Member]
Jun. 30, 2014
Lavaca [Member]
Jun. 30, 2015
Lavaca [Member]
Jun. 30, 2014
Lavaca [Member]
Jan. 31, 2014
Lavaca [Member]
Jun. 30, 2015
Minimum [Member]
Jun. 30, 2015
Maximum [Member]
Jan. 31, 2014
Pipelines [Member]
Lavaca [Member]
Business Acquisition [Line Items]
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Total revenue
 
$ 67,509 
$ 77,680 
$ 132,118 
$ 157,918 
 
 
$ 5,900 
$ 3,700 
$ 11,900 
$ 6,000 
 
 
 
 
Business Acquisition, Purchase Price Allocation, Land
 
 
 
 
 
 
 
 
 
 
 
2 
 
 
 
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment
 
 
 
 
 
 
 
 
 
 
 
59,492 
 
 
58,737 
Length Of Pipeline
50 
 
 
3,000 
 
 
120 
 
 
 
 
 
 
 
 
Payments to Acquire Businesses, Gross
 
 
 
 
 
 
104,409 
 
 
 
 
 
 
 
 
Finite-Lived Intangible Asset, Useful Life
 
 
 
 
 
 
 
 
 
 
 
 
0 years 5 months 0 days 
30 years 
 
Fair Value Inputs, Discount Rate
 
 
 
 
 
 
10.50% 
 
 
 
 
 
 
 
 
Business Acquisition, Purchase Price Allocation, Equipment
 
 
 
 
 
 
 
 
 
 
 
753 
 
 
 
Business Acquisition, Purchase Price Allocation, Amortizable Intangible Assets
 
 
 
 
 
 
 
 
 
 
 
21,350 
 
 
 
Goodwill
 
134,853 
 
134,853 
 
142,236 
 
 
 
 
 
23,567 
 
 
 
Operating Income (Loss)
 
$ 1,867 
$ 734 
$ 5,302 
$ 3,184 
 
 
$ 2,300 
$ 600 
$ 4,500 
$ 2,200 
 
 
 
 
Acquisitions and Divestitures Blackwater Acquisition (Details) (USD $)
In Thousands, unless otherwise specified
3 Months Ended 6 Months Ended
Jun. 30, 2015
Jun. 30, 2014
Jun. 30, 2015
Jun. 30, 2014
Business Combinations [Abstract]
 
 
 
 
Total revenue
$ 67,509 
$ 77,680 
$ 132,118 
$ 157,918 
Acquisitions and Divestitures Madison Divestiture (Details) (USD $)
In Thousands, unless otherwise specified
6 Months Ended 3 Months Ended
Jun. 30, 2015
Jun. 30, 2014
Mar. 31, 2014
Madison [Member]
Significant Acquisitions and Disposals [Line Items]
 
 
 
Proceeds from disposals of property, plant and equipment
$ 3,876 
$ 6,202 
$ 6,100 
Acquisitions and Divestitures MPOG Acquisition (Details) (USD $)
3 Months Ended 6 Months Ended 1 Months Ended 3 Months Ended
Jun. 30, 2015
Jun. 30, 2014
Jun. 30, 2015
Jun. 30, 2014
Aug. 14, 2014
Equity Method Investments [Member]
Aug. 11, 2014
Equity Method Investments [Member]
Jun. 30, 2015
MPOG [Member]
Schedule of Equity Method Investments [Line Items]
 
 
 
 
 
 
 
Equity Method Investment, Ownership Percentage
 
 
 
 
 
66.70% 
 
Payments to Acquire Equity Method Investments
 
 
$ 626,000 
$ 0 
$ 12,000,000 
 
 
Earnings in unconsolidated affiliates
4,000 
0 
171,000 
0 
 
 
100,000 
Proceeds from Equity Method Investment, Dividends or Distributions, Return of Capital
$ 500,000 
 
$ 1,500,000 
 
 
 
 
Acquisitions and Divestitures Costar Midstream (Details) (USD $)
Share data in Millions, unless otherwise specified
3 Months Ended 6 Months Ended 0 Months Ended 3 Months Ended 6 Months Ended 0 Months Ended 3 Months Ended 6 Months Ended 0 Months Ended
Jun. 30, 2015
Mar. 31, 2015
Jun. 30, 2014
Jun. 30, 2015
Jun. 30, 2014
Dec. 31, 2014
Oct. 14, 2014
Costar Midstream, L.L.C. [Member]
Jun. 30, 2015
Costar Midstream, L.L.C. [Member]
Jun. 30, 2015
Costar Midstream, L.L.C. [Member]
Oct. 14, 2014
Costar Midstream, L.L.C. [Member]
Jan. 31, 2014
Lavaca [Member]
Jun. 30, 2015
Lavaca [Member]
Jun. 30, 2014
Lavaca [Member]
Jun. 30, 2015
Lavaca [Member]
Jun. 30, 2014
Lavaca [Member]
Jan. 31, 2014
Lavaca [Member]
Oct. 14, 2014
Minimum [Member]
Costar Midstream, L.L.C. [Member]
Oct. 14, 2014
Maximum [Member]
Costar Midstream, L.L.C. [Member]
Business Acquisition [Line Items]
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Percentage of voting interests acquired
 
 
 
 
 
 
 
 
 
100.00% 
 
 
 
 
 
 
 
 
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Working Capital
 
 
 
 
 
 
 
 
 
$ 8,152,000 
 
 
 
 
 
 
 
 
Payments to Acquire Businesses, Gross
 
 
 
 
 
 
258,001,000 
 
 
 
104,409,000 
 
 
 
 
 
 
 
Business Combination, Consideration Transferred, Equity Interests Issued and Issuable, Units
 
 
 
 
 
 
6.9 
 
 
 
 
 
 
 
 
 
 
 
Business Combination, Consideration Transferred, Equity Interests Issued and Issuable
 
 
 
 
 
 
147,296,000 
 
 
 
 
 
 
 
 
 
 
 
Business Combination, Consideration Transferred
 
 
 
 
 
 
405,297,000 
 
 
 
 
 
 
 
 
 
 
 
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Processing Plants
 
 
 
 
 
 
 
 
 
48,357,000 
 
 
 
 
 
 
 
 
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Pipelines
 
 
 
 
 
 
 
 
 
128,799,000 
 
 
 
 
 
 
 
 
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Land
 
 
 
 
 
 
 
 
 
1,244,000 
 
 
 
 
 
2,000 
 
 
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Buildings
 
 
 
 
 
 
 
 
 
682,000 
 
 
 
 
 
 
 
 
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Equipment
 
 
 
 
 
 
 
 
 
9,827,000 
 
 
 
 
 
753,000 
 
 
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Construction in Progress
 
 
 
 
 
 
 
 
 
16,146,000 
 
 
 
 
 
 
 
 
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment
 
 
 
 
 
 
 
 
 
205,055,000 
 
 
 
 
 
59,492,000 
 
 
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Investment in Unconsolidated Affiliate
 
 
 
 
 
 
 
 
 
11,884,000 
 
 
 
 
 
 
 
 
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Customer Relationships
 
 
 
 
 
 
 
 
 
53,400,000 
 
 
 
 
 
 
 
 
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Dedicated Acreage
 
 
 
 
 
 
 
 
 
32,000,000 
 
 
 
 
 
 
 
 
Goodwill
134,853,000 
 
 
134,853,000 
 
142,236,000 
 
 
 
95,025,000 
 
 
 
 
 
23,567,000 
 
 
Business Combination, Acquisition of Less than 100 Percent, Noncontrolling Interest, Fair Value
 
 
 
 
 
 
 
 
 
(219,000)
 
 
 
 
 
 
 
 
Business Combination, Recognized Identifiable Assets Acquired, Goodwill, and Liabilities Assumed, Less Noncontrolling Interest
 
 
 
 
 
 
 
 
 
405,297,000 
 
 
 
 
 
 
 
 
Fair Value Inputs, Discount Rate
 
 
 
 
 
 
 
 
 
 
10.50% 
 
 
 
 
 
11.00% 
16.00% 
Business Combination, Acquired Receivables, Gross Contractual Amount
 
 
 
 
 
 
 
 
 
11,200,000 
 
 
 
 
 
 
 
 
Acquisition Working Capital Adjustment
7,200,000 
200,000 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Revenues
67,509,000 
 
77,680,000 
132,118,000 
157,918,000 
 
 
24,200,000 
45,600,000 
 
 
5,900,000 
3,700,000 
11,900,000 
6,000,000 
 
 
 
Operating Income (Loss)
$ 1,867,000 
 
$ 734,000 
$ 5,302,000 
$ 3,184,000 
 
 
$ 600,000 
$ 1,800,000 
 
 
$ 2,300,000 
$ 600,000 
$ 4,500,000 
$ 2,200,000 
 
 
 
Acquisitions and Divestitures Williams Acquisition (Details) (Williams [Member], USD $)
In Millions, unless otherwise specified
Mar. 31, 2014
Williams [Member]
 
Business Acquisition [Line Items]
 
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net
$ 6.5 
Acquisitions and Divestitures Eloi Bay Divestiture (Details) (USD $)
Jun. 30, 2015
Dec. 31, 2014
Jun. 1, 2015
Eloi Bay [Member]
Property, Plant and Equipment [Line Items]
 
 
 
Significant Acquisitions and Disposals, Gain (Loss) on Sale or Disposal, Net of Tax
 
 
$ 3,000,000 
Property, Plant and Equipment, Net
$ 622,590,000 
$ 582,182,000 
$ 3,000,000 
Discontinued Operations (Details) (USD $)
3 Months Ended 6 Months Ended
Jun. 30, 2015
Jun. 30, 2014
Jun. 30, 2015
Jun. 30, 2014
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
 
 
 
 
Disposal Group, Including Discontinued Operation, Revenue
$ 10,000 
$ 212,000 
$ 74,000 
$ 449,000 
Disposal Group, Including Discontinued Operation, Operating Expense
(61,000)
(268,000)
(116,000)
(545,000)
Disposal Group, Including Discontinued Operation, Impairment
0 
(673,000)
0 
(673,000)
Discontinued Operation, Gain (Loss) on Disposal of Discontinued Operation, Net of Tax
0 
(65,000)
0 
(87,000)
Discontinued Operation, Tax Effect of Discontinued Operation
20,000 
288,000 
16,000 
300,000 
Income (loss) from discontinued operations, net of tax
(31,000)
(506,000)
(26,000)
(556,000)
Income (loss) from discontinued operations
$ 0.00 
$ (0.04)
$ 0.00 
$ (0.05)
Blackwater [Member]
 
 
 
 
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
 
 
 
 
Disposal Group, Including Discontinued Operation, Other Assets, Current
100,000 
 
100,000 
 
Noncurrent assets held for sale, net
1,200,000 
 
1,200,000 
 
Current liabilities held for sale
$ 100,000 
 
$ 100,000 
 
Other Current Assets (Details) (USD $)
In Thousands, unless otherwise specified
Jun. 30, 2015
Dec. 31, 2014
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
 
 
Prepaid insurance
$ 1,922 
$ 4,162 
Restricted cash
0 
6,475 
Other current assets
6,212 
4,917 
Other Assets, Current
$ 8,134 
$ 15,554 
Derivatives (Fair Value of Commodity Derivatives) (Details) (USD $)
In Thousands, unless otherwise specified
Jun. 30, 2015
Dec. 31, 2014
Derivative [Line Items]
 
 
Gross Risk Management Assets
$ 1,155 
$ 688 
Gross Risk Management Liabilities
0 
0 
Net Risk Management Assets (Liabilities)
1,155 
688 
Gross Risk Management Assets
0 
0 
Gross Risk Management Liabilities
(69)
(215)
Net Risk Management Assets (Liabilities)
(69)
(215)
Risk Management Assets [Member] |
Commodity derivatives [Member]
 
 
Derivative [Line Items]
 
 
Gross Risk Management Assets
1,155 
688 
Gross Risk Management Liabilities
0 
0 
Net Risk Management Assets (Liabilities)
1,155 
688 
Risk Management Assets - Long Term [Member] |
Commodity derivatives [Member]
 
 
Derivative [Line Items]
 
 
Gross Risk Management Assets
0 
0 
Gross Risk Management Liabilities
0 
0 
Net Risk Management Assets (Liabilities)
0 
0 
Risk Management Liabilities [Member] |
Commodity derivatives [Member]
 
 
Derivative [Line Items]
 
 
Gross Risk Management Assets
0 
0 
Gross Risk Management Liabilities
(69)
(215)
Net Risk Management Assets (Liabilities)
(69)
(215)
Risk Management Liabilities - Long Term [Member] |
Commodity derivatives [Member]
 
 
Derivative [Line Items]
 
 
Gross Risk Management Assets
0 
0 
Gross Risk Management Liabilities
0 
0 
Net Risk Management Assets (Liabilities)
$ 0 
$ 0 
Derivatives (Realized and Unrealized Gains (Losses)) (Details) (USD $)
In Thousands, unless otherwise specified
3 Months Ended 6 Months Ended
Jun. 30, 2015
Jun. 30, 2014
Jun. 30, 2015
Jun. 30, 2014
Derivatives, Fair Value [Line Items]
 
 
 
 
Derivative, Gain (Loss) on Derivative, Net
$ 311 
$ (193)
$ 458 
$ (323)
Commodity derivatives [Member]
 
 
 
 
Derivatives, Fair Value [Line Items]
 
 
 
 
Derivative, Loss on Derivative
(83)
(458)
(287)
(948)
Gain on commodity derivatives, net
157 
(75)
213 
(113)
Gain (Loss) on Derivative Instruments [Member] |
Commodity derivatives [Member]
 
 
 
 
Derivatives, Fair Value [Line Items]
 
 
 
 
Derivative, Gain (Loss) on Derivative, Net
252 
(80)
391 
(182)
Gain on commodity derivatives, net
59 
(113)
67 
(141)
Interest Expense [Member] |
Commodity derivatives [Member]
 
 
 
 
Derivatives, Fair Value [Line Items]
 
 
 
 
Derivative, Loss on Derivative
(101)
(109)
(203)
(213)
Gain on commodity derivatives, net
98 
38 
146 
28 
Other Income [Member] |
Commodity derivatives [Member]
 
 
 
 
Derivatives, Fair Value [Line Items]
 
 
 
 
Derivative, Loss on Derivative
(234)
(269)
(475)
(553)
Gain on commodity derivatives, net
$ 0 
$ 0 
$ 0 
$ 0 
Derivatives (Details Textual) (USD $)
6 Months Ended
Jun. 30, 2015
gal
Jun. 30, 2014
Derivative [Line Items]
 
 
Aggregate notional volume of our commodity derivative
4,300,000 
 
Amortization of weather derivative premium
$ 475,000 
$ 554,000 
Interest Rate Swap [Member]
 
 
Derivative [Line Items]
 
 
Notional amount of interest rate swap
100,000,000 
 
Weather Contract [Member]
 
 
Derivative [Line Items]
 
 
Potential proceeds from derivative contract
10,000,000 
 
Fair value of derivative
0 
 
Payment for weather derivative premium
(900,000)
 
Derivative term of contract
1 year 0 months 0 days 
 
Amortization of weather derivative premium
$ 800,000 
 
Fair Value Measurement (Details) (USD $)
In Thousands, unless otherwise specified
Jun. 30, 2015
Dec. 31, 2014
Commodity Contract [Member]
 
 
Derivatives, Fair Value [Line Items]
 
 
Commodity derivative instruments, net
$ 353 
$ 286 
Interest Rate Swap [Member]
 
 
Derivatives, Fair Value [Line Items]
 
 
Commodity derivative instruments, net
(69)
(215)
Estimate of Fair Value Measurement [Member] |
Commodity Contract [Member]
 
 
Derivatives, Fair Value [Line Items]
 
 
Commodity derivative instruments, net
353 
286 
Estimate of Fair Value Measurement [Member] |
Commodity Contract [Member] |
Level 1 [Member]
 
 
Derivatives, Fair Value [Line Items]
 
 
Commodity derivative instruments, net
0 
0 
Estimate of Fair Value Measurement [Member] |
Commodity Contract [Member] |
Level 2 [Member]
 
 
Derivatives, Fair Value [Line Items]
 
 
Commodity derivative instruments, net
353 
286 
Estimate of Fair Value Measurement [Member] |
Commodity Contract [Member] |
Level 3 [Member]
 
 
Derivatives, Fair Value [Line Items]
 
 
Commodity derivative instruments, net
0 
0 
Estimate of Fair Value Measurement [Member] |
Interest Rate Swap [Member]
 
 
Derivatives, Fair Value [Line Items]
 
 
Commodity derivative instruments, net
(69)
(215)
Estimate of Fair Value Measurement [Member] |
Interest Rate Swap [Member] |
Level 1 [Member]
 
 
Derivatives, Fair Value [Line Items]
 
 
Commodity derivative instruments, net
0 
0 
Estimate of Fair Value Measurement [Member] |
Interest Rate Swap [Member] |
Level 2 [Member]
 
 
Derivatives, Fair Value [Line Items]
 
 
Commodity derivative instruments, net
(69)
(215)
Estimate of Fair Value Measurement [Member] |
Interest Rate Swap [Member] |
Level 3 [Member]
 
 
Derivatives, Fair Value [Line Items]
 
 
Commodity derivative instruments, net
$ 0 
$ 0 
Property, Plant and Equipment (Details) (USD $)
In Thousands, unless otherwise specified
6 Months Ended
Jun. 30, 2015
Dec. 31, 2014
Property, Plant and Equipment, Net [Abstract]
 
 
Accumulated depreciation
$ (129,513)
$ (115,835)
Property, plant and equipment, net
622,590 
582,182 
Land [Member]
 
 
Property, Plant and Equipment, Net [Abstract]
 
 
Property plant and equipment gross
5,282 
5,282 
Construction in progress [Member]
 
 
Property, Plant and Equipment, Net [Abstract]
 
 
Property plant and equipment gross
90,085 
77,550 
Base gas [Member]
 
 
Property, Plant and Equipment, Net [Abstract]
 
 
Property plant and equipment gross
1,108 
1,108 
Buildings and improvements [Member]
 
 
Property, Plant and Equipment, Net [Abstract]
 
 
Property plant and equipment gross
9,708 
6,855 
Processing and treating plants [Member]
 
 
Property, Plant and Equipment, Net [Abstract]
 
 
Property plant and equipment gross
81,404 
80,837 
Pipelines [Member]
 
 
Property, Plant and Equipment, Net [Abstract]
 
 
Property plant and equipment gross
479,749 
451,341 
Compressors [Member]
 
 
Property, Plant and Equipment, Net [Abstract]
 
 
Property plant and equipment gross
30,506 
24,548 
Dock [Member]
 
 
Property, Plant and Equipment, Net [Abstract]
 
 
Property plant and equipment gross
8,105 
8,072 
Tanks, truck rack and piping [Member]
 
 
Property, Plant and Equipment, Net [Abstract]
 
 
Property plant and equipment gross
32,826 
30,079 
Equipment [Member]
 
 
Property, Plant and Equipment, Net [Abstract]
 
 
Property plant and equipment gross
9,474 
8,855 
Computer software [Member]
 
 
Property, Plant and Equipment, Net [Abstract]
 
 
Property plant and equipment gross
3,856 
3,490 
Property plant and equipment in useful life
5 years 
 
Property, Plant And Equipment [Member]
 
 
Property, Plant and Equipment, Net [Abstract]
 
 
Property plant and equipment gross
$ 752,103 
$ 698,017 
Maximum [Member] |
Buildings and improvements [Member]
 
 
Property, Plant and Equipment, Net [Abstract]
 
 
Property plant and equipment in useful life
40 years 
 
Maximum [Member] |
Processing and treating plants [Member]
 
 
Property, Plant and Equipment, Net [Abstract]
 
 
Property plant and equipment in useful life
40 years 
 
Maximum [Member] |
Pipelines [Member]
 
 
Property, Plant and Equipment, Net [Abstract]
 
 
Property plant and equipment in useful life
40 years 
 
Maximum [Member] |
Compressors [Member]
 
 
Property, Plant and Equipment, Net [Abstract]
 
 
Property plant and equipment in useful life
20 years 
 
Maximum [Member] |
Dock [Member]
 
 
Property, Plant and Equipment, Net [Abstract]
 
 
Property plant and equipment in useful life
40 years 
 
Maximum [Member] |
Tanks, truck rack and piping [Member]
 
 
Property, Plant and Equipment, Net [Abstract]
 
 
Property plant and equipment in useful life
40 years 
 
Maximum [Member] |
Equipment [Member]
 
 
Property, Plant and Equipment, Net [Abstract]
 
 
Property plant and equipment in useful life
20 years 
 
Minimum [Member] |
Buildings and improvements [Member]
 
 
Property, Plant and Equipment, Net [Abstract]
 
 
Property plant and equipment in useful life
4 years 
 
Minimum [Member] |
Processing and treating plants [Member]
 
 
Property, Plant and Equipment, Net [Abstract]
 
 
Property plant and equipment in useful life
8 years 
 
Minimum [Member] |
Pipelines [Member]
 
 
Property, Plant and Equipment, Net [Abstract]
 
 
Property plant and equipment in useful life
3 years 
 
Minimum [Member] |
Compressors [Member]
 
 
Property, Plant and Equipment, Net [Abstract]
 
 
Property plant and equipment in useful life
4 years 
 
Minimum [Member] |
Dock [Member]
 
 
Property, Plant and Equipment, Net [Abstract]
 
 
Property plant and equipment in useful life
20 years 
 
Minimum [Member] |
Tanks, truck rack and piping [Member]
 
 
Property, Plant and Equipment, Net [Abstract]
 
 
Property plant and equipment in useful life
20 years 
 
Minimum [Member] |
Equipment [Member]
 
 
Property, Plant and Equipment, Net [Abstract]
 
 
Property plant and equipment in useful life
8 years 
 
Property, Plant and Equipment (Details Textual) (USD $)
3 Months Ended 6 Months Ended
Jun. 30, 2015
Jun. 30, 2014
Jun. 30, 2015
Jun. 30, 2014
Jun. 30, 2015
AlaTenn system [Member]
Dec. 31, 2014
AlaTenn system [Member]
Property, Plant and Equipment [Line Items]
 
 
 
 
 
 
Property plant and equipment gross
 
 
 
 
$ 104,400,000 
$ 101,900,000 
Capitalized interest
500,000 
100,000 
700,000 
200,000 
 
 
Depreciation
$ 7,600,000 
$ 4,700,000 
$ 15,500,000 
$ 11,100,000 
 
 
Goodwill and Intangible Assets, Net (Details) (USD $)
3 Months Ended 6 Months Ended
Jun. 30, 2015
Mar. 31, 2015
Jun. 30, 2014
Jun. 30, 2015
Jun. 30, 2014
Dec. 31, 2014
Segment Reporting Information [Line Items]
 
 
 
 
 
 
Goodwill
$ 134,853,000 
 
 
$ 134,853,000 
 
$ 142,236,000 
Acquisition Working Capital Adjustment
7,200,000 
200,000 
 
 
 
 
Amortization of Intangible Assets
1,500,000 
 
1,200,000 
3,100,000 
2,100,000 
 
Gathering And Processing [Member]
 
 
 
 
 
 
Segment Reporting Information [Line Items]
 
 
 
 
 
 
Goodwill
118,600,000 
 
 
118,600,000 
 
125,900,000 
Terminals [Member]
 
 
 
 
 
 
Segment Reporting Information [Line Items]
 
 
 
 
 
 
Goodwill
$ 16,300,000 
 
 
$ 16,300,000 
 
$ 16,300,000 
Minimum [Member]
 
 
 
 
 
 
Segment Reporting Information [Line Items]
 
 
 
 
 
 
Finite-Lived Intangible Asset, Useful Life
 
 
 
0 years 5 months 0 days 
 
 
Maximum [Member]
 
 
 
 
 
 
Segment Reporting Information [Line Items]
 
 
 
 
 
 
Finite-Lived Intangible Asset, Useful Life
 
 
 
30 years 
 
 
Goodwill and Intangible Assets, Net Schedule of Intangible Assets (Details) (USD $)
3 Months Ended 6 Months Ended
Jun. 30, 2015
Jun. 30, 2014
Jun. 30, 2015
Jun. 30, 2014
Dec. 31, 2014
Finite-Lived Intangible Assets [Line Items]
 
 
 
 
 
Amortization of Intangible Assets
$ 1,500,000 
$ 1,200,000 
$ 3,100,000 
$ 2,100,000 
 
Goodwill
134,853,000 
 
134,853,000 
 
142,236,000 
Gross carrying amount:
118,851,000 
 
118,851,000 
 
118,851,000 
Accumulated amortization:
(15,623,000)
 
(15,623,000)
 
(12,545,000)
Net carrying amount:
103,228,000 
 
103,228,000 
 
106,306,000 
Customer Contracts [Member]
 
 
 
 
 
Finite-Lived Intangible Assets [Line Items]
 
 
 
 
 
Gross carrying amount:
12,101,000 
 
12,101,000 
 
12,101,000 
Accumulated amortization:
(12,013,000)
 
(12,013,000)
 
(11,110,000)
Net carrying amount:
88,000 
 
88,000 
 
991,000 
Customer Relationships [Member]
 
 
 
 
 
Finite-Lived Intangible Assets [Line Items]
 
 
 
 
 
Gross carrying amount:
53,400,000 
 
53,400,000 
 
53,400,000 
Accumulated amortization:
(1,815,000)
 
(1,815,000)
 
(553,000)
Net carrying amount:
51,585,000 
 
51,585,000 
 
52,847,000 
Dedicated Acreage [Member]
 
 
 
 
 
Finite-Lived Intangible Assets [Line Items]
 
 
 
 
 
Gross carrying amount:
53,350,000 
 
53,350,000 
 
53,350,000 
Accumulated amortization:
(1,795,000)
 
(1,795,000)
 
(882,000)
Net carrying amount:
$ 51,555,000 
 
$ 51,555,000 
 
$ 52,468,000 
Accrued Expenses and Other Current Liabilities (Details) (USD $)
In Thousands, unless otherwise specified
Jun. 30, 2015
Dec. 31, 2014
Other Liabilities Disclosure [Abstract]
 
 
Accrued capital expenditures
$ 8,225 
$ 17,134 
Accrued expenses
5,587 
7,036 
Gas imbalances payable
895 
1,069 
Other
3,850 
561 
Accrued expenses and other current liabilities
$ 18,557 
$ 25,800 
Debt Obligations (Details) (USD $)
Jun. 30, 2015
Dec. 31, 2014
Debt Disclosure [Abstract]
 
 
Line of Credit Facility, Amount Outstanding Limit
$ 500,000,000 
 
Revolving credit facility
387,100,000 
372,950,000 
Other debt
737,000 
2,908,000 
Total debt
387,837,000 
375,858,000 
Less: current portion
737,000 
2,908,000 
Long-term debt
$ 387,100,000 
$ 372,950,000 
Debt Obligations (Details Textual) (USD $)
6 Months Ended
Jun. 30, 2015
Dec. 31, 2014
Jun. 30, 2014
Debt Instrument [Line Items]
 
 
 
Line of Credit Facility, Amount Outstanding Limit
$ 500,000,000 
 
 
Long-Term Debt (Textual) [Abstract]
 
 
 
Letter of credit outstanding
1,600,000 
1,600,000 
 
Revolving credit facility
387,100,000 
372,950,000 
 
Ratio of Indebtedness to Net Capital
5.00 
 
 
Line of Credit Facility, Unused Capacity, Commitment Fee Percentage
0.50% 
 
 
Debt Instrument, Interest Coverage Ratio
8.48 
 
 
Debt, Weighted Average Interest Rate
3.90% 
 
4.18% 
Proceeds from (Payments for) Other Financing Activities
3,300,000 
 
 
Debt Instrument, Periodic Payment
$ 400,000 
 
 
Maximum [Member]
 
 
 
Long-Term Debt (Textual) [Abstract]
 
 
 
Ratio of Indebtedness to Net Capital
4.75 
 
 
Ratio of indebtedness to net capital, after permitted acquisition
5.25 
 
 
Minimum [Member]
 
 
 
Long-Term Debt (Textual) [Abstract]
 
 
 
Debt Instrument, Interest Coverage Ratio
2.50 
 
 
Federal Funds [Member]
 
 
 
Long-Term Debt (Textual) [Abstract]
 
 
 
Debt Instrument, Interest Rate, Stated Percentage
0.50% 
 
 
Eurodollar [Member]
 
 
 
Long-Term Debt (Textual) [Abstract]
 
 
 
Debt Instrument, Interest Rate, Stated Percentage
1.00% 
 
 
Insurance Premium Financing [Member]
 
 
 
Long-Term Debt (Textual) [Abstract]
 
 
 
Debt Instrument, Interest Rate, Stated Percentage
3.95% 
 
 
Fiscal Quarter Ending December 31, 2014 [Member] |
Debt Instrument, Fourth Amendment [Member] |
Base Rate [Member] |
Maximum [Member]
 
 
 
Long-Term Debt (Textual) [Abstract]
 
 
 
Debt Instrument, Basis Spread on Variable Rate
3.25% 
 
 
Fiscal Quarter Ending December 31, 2014 [Member] |
Debt Instrument, Fourth Amendment [Member] |
Base Rate [Member] |
Minimum [Member]
 
 
 
Long-Term Debt (Textual) [Abstract]
 
 
 
Debt Instrument, Basis Spread on Variable Rate
2.00% 
 
 
Fiscal Quarter Ending December 31, 2014 [Member] |
Debt Instrument, Fourth Amendment [Member] |
Eurodollar [Member] |
Maximum [Member]
 
 
 
Long-Term Debt (Textual) [Abstract]
 
 
 
Debt Instrument, Basis Spread on Variable Rate
2.25% 
 
 
Fiscal Quarter Ending December 31, 2014 [Member] |
Debt Instrument, Fourth Amendment [Member] |
Eurodollar [Member] |
Minimum [Member]
 
 
 
Long-Term Debt (Textual) [Abstract]
 
 
 
Debt Instrument, Basis Spread on Variable Rate
1.00% 
 
 
Partners' Capital (Details) (USD $)
3 Months Ended 6 Months Ended 3 Months Ended 6 Months Ended 3 Months Ended 6 Months Ended 3 Months Ended 6 Months Ended 3 Months Ended 6 Months Ended 3 Months Ended 6 Months Ended
Jun. 30, 2015
Jun. 30, 2014
Jun. 30, 2015
Jun. 30, 2014
Aug. 7, 2015
Dec. 31, 2014
Jan. 29, 2014
Dec. 31, 2014
AIM Midstream Holdings No. of units outstanding [Member]
Jun. 30, 2015
Series B [Member]
Jun. 30, 2014
Series B [Member]
Jun. 30, 2015
Series B [Member]
Jun. 30, 2014
Series B [Member]
Aug. 7, 2015
Series B [Member]
Dec. 31, 2014
Series B [Member]
Jun. 30, 2015
Limited Partner Series B Convertible Units [Member]
Dec. 31, 2014
Limited Partner Series B Convertible Units [Member]
Jun. 30, 2015
Limited Partner Common Units [Member]
Dec. 31, 2014
Limited Partner Common Units [Member]
Jun. 30, 2015
Limited Partner [Member]
Jun. 30, 2014
Limited Partner [Member]
Jun. 30, 2015
Limited Partner [Member]
Jun. 30, 2014
Limited Partner [Member]
Jun. 30, 2015
General Partner [Member]
Jun. 30, 2014
General Partner [Member]
Jun. 30, 2015
General Partner [Member]
Jun. 30, 2014
General Partner [Member]
Jun. 30, 2015
General Partner, Incentive Distribution Rights [Member]
Jun. 30, 2014
General Partner, Incentive Distribution Rights [Member]
Jun. 30, 2015
General Partner, Incentive Distribution Rights [Member]
Jun. 30, 2014
General Partner, Incentive Distribution Rights [Member]
Jun. 30, 2015
Series A [Member]
Preferred Partner [Member]
Jun. 30, 2014
Series A [Member]
Preferred Partner [Member]
Jun. 30, 2015
Series A [Member]
Preferred Partner [Member]
Jun. 30, 2014
Series A [Member]
Preferred Partner [Member]
Jul. 27, 2015
Subsequent Event [Member]
CallRightdefinedacquisitionvalue
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
$ 100,000,000 
Unitholder distributions
 
 
 
 
 
 
 
 
413,000 
560,000 
833,000 
1,052,000 
 
 
 
 
 
 
10,753,000 
5,152,000 
21,466,000 
10,049,000 
159,000 
76,000 
317,000 
148,000 
1,293,000 
527,000 
2,581,000 
937,000 
0 
1,338,000 
0 
2,658,000 
 
Limited Partners' Capital Account, Units Issued
 
 
 
 
 
 
3,400,000 
 
 
 
 
 
 
 
1,301,000 
1,255,000 
22,757,000 
22,670,000 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Series A convertible preferred, units, outstanding
8,682,000 
 
8,682,000 
 
8,682,271 
5,745,000 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
General partner interest units
411,000 
 
411,000 
 
 
392,000 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Limited Partners' Capital Account, units outstanding
 
 
 
 
 
 
 
22,670,000 
 
 
 
 
1,301,282 
1,255,000 
1,301,000 
1,255,000 
22,757,000 
22,670,000 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Limited partner subordinated units
 
 
 
 
 
 
 
392,000 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Sale of Stock, Price Per Share
 
 
 
 
 
 
$ 26.75 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Issuance of common units, net of offering costs
 
 
 
86,900,000 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Payments of Capital Distribution
$ 12,205,000 
$ 7,093,000 
$ 24,364,000 
$ 13,792,000 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Partners Capital (Details Textual) (USD $)
0 Months Ended 6 Months Ended 6 Months Ended 3 Months Ended 6 Months Ended 0 Months Ended 6 Months Ended
Feb. 21, 2014
Jun. 30, 2015
Jun. 30, 2014
Feb. 21, 2014
Feb. 5, 2014
Jan. 29, 2014
Dec. 31, 2014
Partnership Interest [Member]
Jun. 30, 2015
Limited Partner [Member]
Jun. 30, 2014
Limited Partner [Member]
Jun. 30, 2015
General Partner [Member]
Jun. 30, 2014
General Partner [Member]
Jun. 30, 2015
Series B [Member]
Jun. 30, 2014
Series B [Member]
Jun. 30, 2015
Series B [Member]
Jun. 30, 2014
Series B [Member]
Jul. 27, 2015
Subsequent Event [Member]
Jul. 27, 2015
Subsequent Event [Member]
Jun. 30, 2015
Issuance of Preferred Units [Member]
Series A [Member]
Magnolia Infrastructure Partners, LLC [Member]
Subsidiary, Sale of Stock [Line Items]
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Warrants Not Settleable in Cash, Fair Value Disclosure
$ 23.89 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Unitholder distributions
 
 
 
 
 
 
 
$ 29,800,000 
$ 18,093,000 
$ 3,004,000 
$ 1,192,000 
$ 413,000 
$ 560,000 
$ 833,000 
$ 1,052,000 
 
 
 
Partners Capital (Textual) [Abstract]
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
General partner interest
 
1.20% 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest
 
98.80% 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Partners' Capital Account, Units, Sold in Private Placement
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
2,571,430 
Partners' Capital Account, Private Placement of Units
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
45,000,000 
Limited Partners' Capital Account, Units Issued
 
 
 
 
 
3,400,000 
 
 
 
 
 
 
 
 
 
 
 
 
Other Ownership Interests, Units Outstanding
 
 
 
 
 
 
392,000 
 
 
 
 
 
 
 
 
 
 
 
Sale of Stock, Price Per Share
 
 
 
 
 
$ 26.75 
 
 
 
 
 
 
 
 
 
 
 
 
Issuance of common units, net of offering costs
 
 
86,900,000 
 
 
 
 
 
86,904,000 
 
 
 
 
 
 
 
 
 
Class of Warrant or Right, Number of Securities Called by Warrants or Rights
 
 
 
300,000 
300,000 
 
 
 
 
 
 
 
 
 
 
 
 
 
Issuance and exercise of warrant
7,200,000 
 
 
 
 
 
 
 
7,164,000 
 
(7,164,000)
 
 
 
 
 
 
 
Class of Warrant or Right, Exercise Price of Warrants or Rights
 
 
 
 
$ 0.01 
 
 
 
 
 
 
 
 
 
 
 
 
 
Fair Value, Paid In Kind Distributions, Aggregate
 
4,200,000 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Preferred Stock, Call or Exercise Features
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
$ 17.50 
 
 
CallRightdefinedacquisitionvalue
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
$ 100,000,000 
 
Partners' Capital (Calculation of Net Income (Loss) Per Limited Partner Unit) (Details) (USD $)
In Thousands, except Per Share data, unless otherwise specified
3 Months Ended 6 Months Ended
Jun. 30, 2015
Jun. 30, 2014
Jun. 30, 2015
Jun. 30, 2014
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
 
 
 
 
Net income (loss)
$ (2,033)
$ (1,601)
$ (1,192)
$ (1,093)
Income (loss) from discontinued operations, net of tax
(31)
(506)
(26)
(556)
Net income (loss) from continuing operations
(2,002)
(1,095)
(1,166)
(537)
Less: Comprehensive income (loss) attributable to noncontrolling interests
32 
66 
46 
174 
Income (Loss) from Continuing Operations Attributable to Parent
(2,034)
(1,161)
(1,212)
(711)
Temporary Equity, Dividends, Adjustment
4,196 
3,917 
7,607 
7,098 
General Partners' Capital Account, Period Undistributed Income (Loss) From Continuing Operations, Amount
(234)
(149)
(422)
(262)
Net income (loss) from continuing operations available to limited partners
(7,861)
(6,092)
(12,129)
(9,684)
Net income (loss) from discontinued operations available to limited partners
(31)
(499)
(26)
(549)
Net income (loss) available to limited partners
(7,892)
(6,591)
(12,155)
(10,233)
Weighted average number of units used in computation of limited partners’ net (loss) income per unit (basic and diluted)
22,757 
11,139 
22,730 
10,496 
Income (Loss) from Continuing Operations, Per Outstanding Limited Partnership Unit, Basic, Net of Tax
$ (0.35)
$ (0.55)
$ (0.53)
$ (0.92)
Income (loss) from discontinued operations
$ 0.00 
$ (0.04)
$ 0.00 
$ (0.05)
Net Income (Loss), Per Outstanding Limited Partnership Unit, Basic, Net of Tax
$ (0.35)
$ (0.59)
$ (0.53)
$ (0.97)
Series B [Member]
 
 
 
 
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
 
 
 
 
General partner's distribution
(413)
(560)
(833)
(1,052)
General Partner [Member]
 
 
 
 
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
 
 
 
 
General partner's distribution
 
 
(3,004)
(1,192)
Dividend Declared [Member] |
General Partner [Member]
 
 
 
 
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
 
 
 
 
General partner's distribution
$ (1,452)
$ (603)
$ (2,899)
$ (1,085)
Long-Term Incentive Plan (Details) (USD $)
3 Months Ended 6 Months Ended
Jun. 30, 2015
Jun. 30, 2014
Jun. 30, 2015
Jun. 30, 2014
Dec. 31, 2014
Unit-Based Award
 
 
 
 
 
Equity compensation expense
$ 550,000 
$ 435,000 
$ 2,248,000 
$ 795,000 
 
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Available for Grant
399,832 
 
399,832 
 
688,976 
Grants Issued Under Long Term Incentive Plan
25.00% 
 
25.00% 
 
 
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Fair Value
 
 
2,300,000 
800,000 
 
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized
$ 6,000,000 
$ 3,800,000 
$ 6,000,000 
$ 3,800,000 
 
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercisable, Weighted Average Exercise Price
$ 16.82 
 
$ 16.82 
 
$ 19.85 
Table Summarizes Unit Based Awards
 
 
 
 
 
Outstanding, Beginning period
 
 
201,132,000 
 
 
Granted
 
 
336,613,000 
 
 
Share-based Compensation Arrangements by Share-based Payment Award, Options, Grants in Period, Weighted Average Exercise Price
 
 
$ 15.78 
 
 
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period
 
 
(8,297,000)
 
 
Share-based Compensation Arrangement by Share-based Payment Award, Options, Forfeitures and Expirations in Period, Weighted Average Exercise Price
 
 
$ 17.24 
 
 
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period
 
 
(126,897,000)
 
 
LTIP vesting, Shares
 
 
$ (18.84)
 
 
Outstanding, Ending period
402,551,000 
 
402,551,000 
 
 
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized, Period for Recognition
 
 
3 years 2 months 
 
 
Income Tax (Details) (USD $)
In Thousands, unless otherwise specified
3 Months Ended 6 Months Ended
Jun. 30, 2015
Jun. 30, 2014
Jun. 30, 2015
Jun. 30, 2014
Income Tax Disclosure [Abstract]
 
 
 
 
Income tax (expense) benefit
$ (317)
$ (149)
$ (473)
$ (138)
Effective Income Tax Rate, Continuing Operations
(18.80%)
(15.80%)
(68.30%)
(34.60%)
Commitments and Contingencies Commitments and Contingencies (Details)
0 Months Ended 6 Months Ended
Jun. 29, 2015
mi
Jun. 30, 2015
mi
in
Commitments and Contingencies Disclosure [Abstract]
 
 
Circumferenceofpipe
 
12 
Length Of Pipeline
50 
3,000 
Related- Party Transactions (Details Textual) (USD $)
In Millions, unless otherwise specified
3 Months Ended 6 Months Ended
Jun. 30, 2015
Jun. 30, 2014
Jun. 30, 2015
Jun. 30, 2014
Related Party Transaction [Line Items]
 
 
 
 
Proceeds from Sale of Other Assets
$ 1.1 
 
$ 3.9 
 
Management Fees Revenue
0.4 
 
0.9 
0.2 
American Midstream, L.L.C [Member]
 
 
 
 
Related Party Transaction [Line Items]
 
 
 
 
General and Administrative Expense
7.4 
5.1 
15.0 
10.1 
Business Development
$ 0.5 
$ 0.2 
$ 0.9 
$ 0.7 
Reporting Segments (Details) (USD $)
In Thousands, unless otherwise specified
3 Months Ended 6 Months Ended
Jun. 30, 2015
Jun. 30, 2014
Jun. 30, 2015
Jun. 30, 2014
Dec. 31, 2014
Segment Reporting, Revenue Reconciling Item [Line Items]
 
 
 
 
 
Segment assets:
$ 936,647 
 
$ 936,647 
 
$ 916,644 
Segment information
 
 
 
 
 
Revenue
67,198 
77,873 
131,660 
158,241 
 
Gain (loss) on commodity derivatives, net
311 
(193)
458 
(323)
 
Total revenue
67,509 
77,680 
132,118 
157,918 
 
Purchases of natural gas, NGLs and condensate
33,334 
53,818 
62,311 
109,039 
 
Direct operating expenses
13,967 
11,044 
27,834 
20,005 
 
Selling, general and administrative expenses
5,571 
5,637 
12,506 
11,230 
 
Equity compensation expense
550 
435 
2,248 
795 
 
Depreciation, amortization and accretion expense
9,250 
6,012 
18,939 
13,644 
 
Total operating expenses
62,672 
76,946 
123,838 
154,713 
 
Gain (loss) on sale of assets, net
(2,970)
0 
(2,978)
(21)
 
Income (loss) from discontinued operations, net of tax
(31)
(506)
(26)
(556)
 
Interest expense
(3,556)
(1,680)
(6,166)
(3,583)
 
Earnings in unconsolidated affiliates
4 
0 
171 
0 
 
Income tax (expense) benefit
(317)
(149)
(473)
(138)
 
Net income (loss)
(2,033)
(1,601)
(1,192)
(1,093)
 
Less: Comprehensive income (loss) attributable to noncontrolling interests
32 
66 
46 
174 
 
Net income (loss) attributable to the Partnership
(2,065)
(1,667)
(1,238)
(1,267)
 
Segment gross margin
32,304 
22,167 
66,081 
45,248 
 
Gathering And Processing [Member]
 
 
 
 
 
Segment Reporting, Revenue Reconciling Item [Line Items]
 
 
 
 
 
Segment assets:
684,359 
 
684,359 
 
686,395 
Transmission [Member]
 
 
 
 
 
Segment Reporting, Revenue Reconciling Item [Line Items]
 
 
 
 
 
Segment assets:
128,291 
 
128,291 
 
132,767 
Gathering and Processing reporting segment [Member]
 
 
 
 
 
Segment information
 
 
 
 
 
Revenue
50,439 
50,015 
98,888 
101,641 
 
Gain (loss) on commodity derivatives, net
311 
(193)
458 
(323)
 
Total revenue
50,750 
49,822 
99,346 
101,318 
 
Purchases of natural gas, NGLs and condensate
30,272 
39,238 
57,590 
80,359 
 
Direct operating expenses
9,130 
5,746 
18,223 
9,914 
 
Segment gross margin
20,219 
10,481 
41,265 
20,610 
 
Transmission reporting segment [Member]
 
 
 
 
 
Segment information
 
 
 
 
 
Revenue
12,423 
23,960 
24,171 
49,088 
 
Gain (loss) on commodity derivatives, net
0 
0 
0 
0 
 
Total revenue
12,423 
23,960 
24,171 
49,088 
 
Purchases of natural gas, NGLs and condensate
3,062 
14,580 
4,721 
28,680 
 
Direct operating expenses
3,253 
3,736 
6,432 
6,854 
 
Segment gross margin
9,333 
9,350 
19,394 
20,363 
 
Terminals [Member]
 
 
 
 
 
Segment Reporting, Revenue Reconciling Item [Line Items]
 
 
 
 
 
Segment assets:
83,766 
 
83,766 
 
71,180 
Segment information
 
 
 
 
 
Total revenue
4,336 
3,898 
8,601 
7,512 
 
Terminals reporting segment [Member]
 
 
 
 
 
Segment information
 
 
 
 
 
Revenue
4,336 
3,898 
8,601 
7,512 
 
Gain (loss) on commodity derivatives, net
0 
0 
0 
0 
 
Purchases of natural gas, NGLs and condensate
0 
0 
0 
0 
 
Direct operating expenses
1,584 
1,562 
3,179 
3,237 
 
Segment gross margin
2,752 
2,336 
5,422 
4,275 
 
Other Segments [Member]
 
 
 
 
 
Segment Reporting, Revenue Reconciling Item [Line Items]
 
 
 
 
 
Segment assets:
$ 40,231 
 
$ 40,231 
 
$ 26,302 
Reporting Segments (Details Textual)
6 Months Ended
Jun. 30, 2015
segment
Segment Reporting [Abstract]
 
Number of Operating Segments
3 
Subsequent Events (Details) (USD $)
In Thousands, except Share data, unless otherwise specified
3 Months Ended 6 Months Ended 0 Months Ended 1 Months Ended
Jun. 30, 2015
Jun. 30, 2014
Jun. 30, 2015
Jun. 30, 2014
Dec. 31, 2014
Jul. 23, 2015
Subsequent Event [Member]
Jul. 31, 2015
Subsequent Event [Member]
Business Acquisition [Line Items]
 
 
 
 
 
 
 
Unitholder contributions
 
 
 
 
 
 
$ 400 
General Partners' Capital Account, Units Issued
411,000 
 
411,000 
 
392,000 
 
21,975 
Distribution declared per common unit (a)
$ 0.4725 1
$ 0.4625 1
$ 0.9450 1
$ 0.9150 1
 
$ 0.4725 
 
Distribution Made to Limited Partner, Distributions Declared, Per Unit, Annualized Basis
 
 
 
 
 
$ 1.89