Press Release
Natural gas volume throughput averaged 1,523 million cubic feet per day ("MMcf/d") in the first quarter of 2016 compared to 1,605 MMcf/d in the first quarter of 2015 and 1,397 MMcf/d in the fourth quarter of 2015. Crude oil and produced water volume throughput in the first quarter of 2016 averaged 95.0 thousand barrels per day ("Mbbl/d") compared to 53.4 Mbbl/d in the first quarter of 2015 and 86.2 Mbbl/d in the fourth quarter of 2015. Volume throughput metrics, as reported, exclude our proportionate share of volume throughput from Ohio Gathering.
SMLP's financial results for the first quarters of 2016 and 2015 include the historical financial results from its
Our financial results were driven largely by our 2016 Drop Down transaction which was transformational for SMLP and enables us to significantly expand our operating footprint. In addition to creating greater scale, the 2016 Drop Down diversifies our customer exposure, broadens our geographic reach into the high-growth
We achieved a number of operational accomplishments during the first quarter of 2016 including the commissioning of the Stampede Lateral crude oil transmission pipeline and the completion of the Little Muddy transmission pipeline in the Williston. These projects provide our customers on the Polar and
Looking forward, we believe our business is well positioned to perform in the ongoing challenging commodity price environment due to our fixed-fee business model and cash flow support from our minimum volume commitments. We are reaffirming our 2016 adjusted EBITDA guidance of
First Quarter 2016 Segment Results
Summit
Segment adjusted EBITDA for the first quarter of 2016 totaled
Volume throughput on the Summit Utica system averaged 132 MMcf/d in the first quarter of 2016 compared to 12 MMcf/d in the first quarter of 2015 and 75 MMcf/d in the fourth quarter of 2015. Volume throughput for the first quarter of 2016 increased due to our continued buildout of the Summit Utica gathering system and our customers' commissioning of new wells throughout 2015 and into the first quarter of 2016.
The Bison Midstream, Polar and
Segment adjusted EBITDA for the
Liquids volumes and natural gas volumes in the first quarter of 2016 were up 10.2% and flat, respectively, compared to the fourth quarter of 2015.
Piceance/DJ Basins
The
Segment adjusted EBITDA totaled
Barnett Shale
The DFW Midstream system provides our midstream services for the
Segment adjusted EBITDA for the
A DFW Midstream customer has an 11-well pad site that we expect will begin producing in the second quarter of 2016. The same customer recently finished drilling six new wells on an existing pad site in our service area, which we expect to begin production in the second half of 2016.
Marcellus Shale
The Mountaineer Midstream system provides our midstream services for the
Segment adjusted EBITDA for the
Relative to the fourth quarter of 2015, volume throughput on the Mountaineer Midstream system in the first quarter of 2016 was up 23.8% as a result of new wells commissioned during the first quarter of 2016, together with our customer's decision to discontinue curtailment activities in late
Segment adjusted EBITDA in the first quarter of 2016 was also negatively impacted by higher operation and maintenance expense associated with repairs to rights-of-way.
The following table presents average daily throughput by reportable segment:
Three months ended March 31, |
|||||
2016 |
2015 |
||||
Average daily throughput (MMcf/d) (1): |
|||||
Utica Shale (2) |
132 |
12 |
|||
Williston Basin |
25 |
21 |
|||
Piceance/DJ Basins |
572 |
622 |
|||
Barnett Shale |
341 |
403 |
|||
Marcellus Shale |
453 |
547 |
|||
Aggregate average daily throughput |
1,523 |
1,605 |
|||
Average daily throughput (Mbbl/d) (1): |
|||||
Williston Basin |
95.0 |
53.4 |
|||
Average daily throughput |
95.0 |
53.4 |
______
(1) Prior periods have been recast to include the incremental historical volumes from the 2016 Drop Down. |
(2) Exclusive of volume throughput for Ohio Gathering. |
MVC Shortfall Payments
SMLP billed its customers
For the first quarter of 2016, SMLP recognized
The net impact of SMLP's MVC shortfall payment mechanisms increased adjusted EBITDA by
Three months ended March 31, 2016 |
||||||||||||||||
MVC billings |
Gathering revenue |
Adjustments to MVC shortfall payments |
Net impact to adjusted EBITDA |
|||||||||||||
(In thousands) |
||||||||||||||||
Net change in deferred revenue related to MVC shortfall payments: |
||||||||||||||||
Utica Shale |
$ |
— |
$ |
— |
$ |
— |
$ |
— |
||||||||
Williston Basin |
235 |
— |
235 |
235 |
||||||||||||
Piceance/DJ Basins |
3,960 |
2,722 |
1,238 |
3,960 |
||||||||||||
Barnett Shale |
— |
— |
— |
— |
||||||||||||
Marcellus Shale |
— |
— |
— |
— |
||||||||||||
Total net change |
$ |
4,195 |
$ |
2,722 |
$ |
1,473 |
$ |
4,195 |
||||||||
MVC shortfall payment adjustments: |
||||||||||||||||
Utica Shale |
$ |
— |
$ |
— |
$ |
— |
$ |
— |
||||||||
Williston Basin |
— |
— |
3,301 |
3,301 |
||||||||||||
Piceance/DJ Basins |
284 |
284 |
6,279 |
6,563 |
||||||||||||
Barnett Shale |
264 |
264 |
89 |
353 |
||||||||||||
Marcellus Shale |
796 |
796 |
— |
796 |
||||||||||||
Total MVC shortfall payment adjustments |
$ |
1,344 |
$ |
1,344 |
$ |
9,669 |
$ |
11,013 |
||||||||
Total |
$ |
5,539 |
$ |
4,066 |
$ |
11,142 |
$ |
15,208 |
Capital Expenditures
SMLP recorded total capital expenditures of
Capital & Liquidity
As of
Through
2016 Drop Down Deferred Payment
The consideration for the 2016 Drop Down consisted of (i) an initial
The Deferred Payment will be equal to: (a) six-and-one-half (6.5) multiplied by the average adjusted EBITDA of the Drop Down Assets for 2018 and 2019; less (b) the Initial Payment; less (c) all capital expenditures incurred for the Drop Down Assets between Initial Close and December 31, 2019; plus (d) all adjusted EBITDA from the Drop Down Assets between Initial Close and December 31, 2019. SMLP currently estimates that the Deferred Payment will be approximately $800.0 million to $900.0 million.
Upon settlement of the Deferred Payment, total consideration (the Initial Payment plus the Deferred Payment) is expected to represent a 6.5x multiple of the Drop Down Assets' 2018 and 2019 average EBITDA.
2016 SMLP Financial Guidance
SMLP is reaffirming its 2016 adjusted EBITDA guidance of
Quarterly Distribution
On
First Quarter 2016 Earnings Call Information
SMLP will host a conference call at
A replay of the conference call will be available until
Members of SMLP's senior management team will participate in
Use of Non-GAAP Financial Measures
We report financial results in accordance with U.S. generally accepted accounting principles ("GAAP"). We also present EBITDA, adjusted EBITDA, distributable cash flow and adjusted distributable cash flow. We define EBITDA as net income or loss, plus interest expense, deferred purchase price obligation expense, income tax expense, and depreciation and amortization, less interest income and income tax benefit. We define adjusted EBITDA as EBITDA plus our proportional adjusted EBITDA for equity method investees, adjustments related to MVC shortfall payments, impairments and other noncash expenses or losses, less income (loss) from equity method investees and other noncash income or gains. We define distributable cash flow as adjusted EBITDA plus cash interest received and cash taxes received, less cash interest paid, senior notes interest adjustment, cash taxes paid and maintenance capital expenditures. We define adjusted distributable cash flow as distributable cash flow plus or minus other unusual or non-recurring expenses or income. Our definitions of these non-GAAP financial measures may differ from the definitions of similar measures used by other companies. Management uses these non-GAAP financial measures in making financial, operating and planning decisions and in evaluating our financial performance. Furthermore, management believes that these non-GAAP financial measures may provide users with additional meaningful comparisons between current results and results of prior periods as they are expected to be reflective of our core ongoing business. These measures have limitations, and investors should not consider them in isolation or as a substitute for analysis of our results as reported under GAAP. Reconciliations of GAAP to non-GAAP financial measures are attached to this release.
Comparability Related to Drop Down Transactions
With respect to drop down transactions, SMLP's historical results of operations may not be comparable to its future results of operations. In
About
SMLP is a growth-oriented limited partnership focused on developing, owning and operating midstream energy infrastructure assets that are strategically located in the core producing areas of unconventional resource basins, primarily shale formations, in the continental
About
As of
Forward-Looking Statements
This press release includes certain statements concerning expectations for the future that are forward-looking within the meaning of the federal securities laws. Forward-looking statements contain known and unknown risks and uncertainties (many of which are difficult to predict and beyond management's control) that may cause SMLP's actual results in future periods to differ materially from anticipated or projected results. Forward-looking statements in this press release include statements regarding the necessity of accessing the debt and equity capital markets, financial guidance with respect to distribution growth, distribution coverage ratios, adjusted EBITDA, expected commodity prices and adjusted distributable cash flow, and the expected amount of the Deferred Payment. An extensive list of specific material risks and uncertainties affecting SMLP is contained in its 2015 Annual Report on Form 10-K filed with the
SUMMIT MIDSTREAM PARTNERS, LP AND SUBSIDIARIES |
|||||||
UNAUDITED CONDENSED CONSOLIDATED BALANCE SHEETS |
|||||||
March 31, 2016 |
December 31, 2015 |
||||||
(In thousands) |
|||||||
Assets |
|||||||
Current assets: |
|||||||
Cash and cash equivalents |
$ |
13,087 |
$ |
21,793 |
|||
Accounts receivable |
49,550 |
89,581 |
|||||
Other current assets |
2,887 |
3,573 |
|||||
Total current assets |
65,524 |
114,947 |
|||||
Property, plant and equipment, net |
1,833,765 |
1,812,783 |
|||||
Intangible assets, net |
452,667 |
461,310 |
|||||
Goodwill |
16,211 |
16,211 |
|||||
Investment in equity method investees |
757,869 |
751,168 |
|||||
Other noncurrent assets |
8,847 |
8,253 |
|||||
Total assets |
$ |
3,134,883 |
$ |
3,164,672 |
|||
Liabilities and Partners' Capital |
|||||||
Current liabilities: |
|||||||
Trade accounts payable |
$ |
18,783 |
$ |
40,808 |
|||
Due to affiliate |
395 |
1,149 |
|||||
Deferred revenue |
677 |
677 |
|||||
Ad valorem taxes payable |
4,288 |
10,271 |
|||||
Accrued interest |
7,733 |
17,483 |
|||||
Accrued environmental remediation |
6,687 |
7,900 |
|||||
Other current liabilities |
12,523 |
13,297 |
|||||
Total current liabilities |
51,086 |
91,585 |
|||||
Long-term debt |
1,312,158 |
1,267,270 |
|||||
Deferred purchase price obligation |
514,890 |
— |
|||||
Deferred revenue |
46,959 |
45,486 |
|||||
Noncurrent accrued environmental remediation |
5,764 |
5,764 |
|||||
Other noncurrent liabilities |
7,440 |
7,268 |
|||||
Total liabilities |
1,938,297 |
1,417,373 |
|||||
Common limited partner capital |
1,155,650 |
744,977 |
|||||
Subordinated limited partner capital |
— |
213,631 |
|||||
General partner interests |
29,631 |
25,634 |
|||||
Noncontrolling interest |
11,305 |
— |
|||||
Summit Investments' equity in contributed subsidiaries |
— |
763,057 |
|||||
Total partners' capital |
1,196,586 |
1,747,299 |
|||||
Total liabilities and partners' capital |
$ |
3,134,883 |
$ |
3,164,672 |
SUMMIT MIDSTREAM PARTNERS, LP AND SUBSIDIARIES |
|||||||
UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS |
|||||||
Three months ended March 31, |
|||||||
2016 |
2015 |
||||||
(In thousands, except per-unit amounts) |
|||||||
Revenues: |
|||||||
Gathering services and related fees |
$ |
78,100 |
$ |
68,440 |
|||
Natural gas, NGLs and condensate sales |
7,588 |
12,613 |
|||||
Other revenues |
4,883 |
5,034 |
|||||
Total revenues |
90,571 |
86,087 |
|||||
Costs and expenses: |
|||||||
Cost of natural gas and NGLs |
6,290 |
9,441 |
|||||
Operation and maintenance |
25,842 |
22,791 |
|||||
General and administrative |
12,879 |
11,599 |
|||||
Transaction costs |
1,174 |
110 |
|||||
Depreciation and amortization |
27,728 |
25,530 |
|||||
Gain on asset sales |
(63) |
— |
|||||
Total costs and expenses |
73,850 |
69,471 |
|||||
Other income |
22 |
1 |
|||||
Interest expense |
(15,882) |
(14,904) |
|||||
Deferred purchase price obligation expense |
(7,463) |
— |
|||||
Loss before income taxes |
(6,602) |
1,713 |
|||||
Income tax benefit (expense) |
77 |
(430) |
|||||
Income (loss) from equity method investees |
2,860 |
(3,768) |
|||||
Net loss |
$ |
(3,665) |
$ |
(2,485) |
|||
Less: |
|||||||
Net income (loss) attributable to Summit Investments |
2,745 |
(4,152) |
|||||
Net income attributable to noncontrolling interest |
44 |
— |
|||||
Net (loss) income attributable to SMLP |
(6,454) |
1,667 |
|||||
Less net (loss) income attributable to general partner, including IDRs |
1,810 |
1,568 |
|||||
Net (loss) income attributable to limited partners |
$ |
(8,264) |
$ |
99 |
|||
(Loss) earnings per limited partner unit: |
|||||||
Common unit – basic and diluted |
$ |
(0.12) |
$ |
0.00 |
|||
Subordinated unit – basic and diluted |
$ |
0.00 |
|||||
Weighted-average limited partner units outstanding: |
|||||||
Common unit – basic |
66,493 |
34,439 |
|||||
Common unit – diluted |
66,493 |
34,585 |
|||||
Subordinated unit – basic and diluted |
24,410 |
SUMMIT MIDSTREAM PARTNERS, LP AND SUBSIDIARIES |
|||||||
UNAUDITED OTHER FINANCIAL AND OPERATING DATA |
|||||||
Three months ended March 31, |
|||||||
2016 |
2015 |
||||||
(Dollars in thousands) |
|||||||
Other financial data: |
|||||||
EBITDA (1) |
$ |
47,446 |
$ |
38,629 |
|||
Adjusted EBITDA (1) |
$ |
70,009 |
$ |
61,556 |
|||
Capital expenditures |
$ |
61,326 |
$ |
49,470 |
|||
Contributions to equity method investees |
$ |
15,645 |
$ |
27,830 |
|||
Acquisitions of gathering systems (2) |
$ |
867,427 |
$ |
2,941 |
|||
Distributable cash flow (1) |
$ |
51,538 |
$ |
42,758 |
|||
Adjusted distributable cash flow |
$ |
52,712 |
$ |
42,971 |
|||
Distributions declared |
$ |
41,045 |
$ |
35,526 |
|||
Distribution coverage ratio (3) |
1.28x |
* |
|||||
Operating data: |
|||||||
Aggregate average throughput – gas (MMcf/d) |
1,523 |
1,605 |
|||||
Average throughput – liquids (Mbbl/d) |
95.0 |
53.4 |
__________
* Not considered meaningful |
(1) Includes transaction costs. These unusual expenses are settled in cash. |
(2) Reflects consideration paid and recognized, including working capital and capital expenditure adjustments paid (received), to fund acquisitions and/or drop downs. |
(3) Distribution coverage ratio calculation for the three months ended March 31, 2016 is based on distributions in respect of the first quarter of 2016. Represents the ratio of adjusted distributable cash flow to distributions declared. Due to the common control nature of drop down transactions and to the extent that common control existed during a given reporting period, our results are reported on an as-if pooled basis with no adjustment to distributions declared. As such, we only present the current quarter's distribution coverage ratio when a drop down, and its funding, impacts adjusted distributable cash flow and distributions declared. |
SUMMIT MIDSTREAM PARTNERS, LP AND SUBSIDIARIES |
|||||||
UNAUDITED RECONCILIATIONS TO NON-GAAP FINANCIAL MEASURES |
|||||||
Three months ended March 31, |
|||||||
2016 |
2015 |
||||||
(Dollars in thousands) |
|||||||
Reconciliations of Net Loss to EBITDA, Adjusted EBITDA, Distributable Cash Flow and Adjusted Distributable Cash Flow: |
|||||||
Net loss |
$ |
(3,665) |
$ |
(2,485) |
|||
Add: |
|||||||
Interest expense |
15,882 |
14,904 |
|||||
Deferred purchase price obligation expense |
7,463 |
— |
|||||
Income tax expense |
— |
430 |
|||||
Depreciation and amortization (1) |
27,865 |
25,781 |
|||||
Less: |
|||||||
Interest income |
22 |
1 |
|||||
Income tax benefit |
77 |
— |
|||||
EBITDA |
$ |
47,446 |
$ |
38,629 |
|||
Add: |
|||||||
Proportional adjusted EBITDA for equity method investees (2) |
12,388 |
5,263 |
|||||
Adjustments related to MVC shortfall payments (3) |
11,142 |
12,333 |
|||||
Unit-based and noncash compensation |
1,956 |
1,563 |
|||||
Less: |
|||||||
Income (loss) from equity method investees |
2,860 |
(3,768) |
|||||
Gain on asset sales |
63 |
— |
|||||
Adjusted EBITDA |
$ |
70,009 |
$ |
61,556 |
|||
Add: |
|||||||
Cash interest received |
22 |
1 |
|||||
Cash taxes received |
77 |
— |
|||||
Less: |
|||||||
Cash interest paid |
25,164 |
25,464 |
|||||
Senior notes interest adjustment (4) |
(9,750) |
(11,171) |
|||||
Maintenance capital expenditures |
3,156 |
4,506 |
|||||
Distributable cash flow |
$ |
51,538 |
$ |
42,758 |
|||
Add: |
|||||||
Transaction costs |
1,174 |
110 |
|||||
Regulatory compliance costs (5) |
— |
103 |
|||||
Adjusted distributable cash flow |
$ |
52,712 |
$ |
42,971 |
|||
Distributions declared |
$ |
41,045 |
$ |
35,526 |
|||
Distribution coverage ratio (6) |
1.28x |
* |
__________
* Not considered meaningful |
(1) Includes amortization of favorable and unfavorable gas gathering contracts reported in other revenues. |
(2) Reflects our proportionate share of Ohio Gathering adjusted EBITDA, based on a one-month lag. |
(3) Adjustments related to MVC shortfall payments account for (i) the net increases or decreases in deferred revenue for MVC shortfall payments and (ii) our inclusion of expected annual MVC shortfall payments. |
(4) Senior notes interest adjustment represents the net of interest expense accrued and paid during the period. Interest on the $300.0 million 5.5% senior notes is paid in cash semi-annually in arrears on February 15 and August 15 until maturity in August 2022. Interest on the $300.0 million 7.5% senior notes is paid in cash semi-annually in arrears on January 1 and July 1 until maturity in July 2021. |
(5) We incurred expenses associated with our adoption of the 2013 Internal Control-Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission ("COSO 2013"). These first-year COSO 2013 expenses are not expected to be incurred subsequent to completion of the 2014 integrated audit. |
(6) Distribution coverage ratio calculation for the three months ended March 31, 2016 is based on distributions in respect of the first quarter of 2016. Represents the ratio of adjusted distributable cash flow to distributions declared. Due to the common control nature of drop down transactions and to the extent that common control existed during a given reporting period, our results are reported on an as-if pooled basis with no adjustment to distributions declared. As such, we only present the current quarter's distribution coverage ratio when a drop down, and its funding, impacts adjusted distributable cash flow and distributions declared. |
SUMMIT MIDSTREAM PARTNERS, LP AND SUBSIDIARIES |
|||||||
UNAUDITED RECONCILIATION OF REPORTABLE SEGMENT ADJUSTED EBITDA |
|||||||
TO ADJUSTED EBITDA |
|||||||
Three months ended March 31, |
|||||||
2016 |
2015 |
||||||
(In thousands) |
|||||||
Reportable segment adjusted EBITDA: |
|||||||
Utica Shale |
$ |
15,577 |
$ |
5,206 |
|||
Williston Basin |
19,719 |
10,975 |
|||||
Piceance/DJ Basins |
24,816 |
28,702 |
|||||
Barnett Shale |
14,078 |
16,760 |
|||||
Marcellus Shale |
4,600 |
6,536 |
|||||
Total reportable segment adjusted EBITDA |
78,790 |
68,179 |
|||||
Allocated corporate expenses |
8,781 |
6,623 |
|||||
Adjusted EBITDA |
$ |
70,009 |
$ |
61,556 |
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SOURCE
Marc Stratton, Senior Vice President and Treasurer, 832-608-6166, ir@summitmidstream.com