Three Months EndedSeptember 30,June 30,September 30,($ in thousands)201520152014Average net daily production (Boe/d)(1)4,859 4,615 3,098 Oil & natural gas sales plus cash settlements from matured derivatives, inclusive of premiums, net(2)$26,867 $23,792 $25,413 Net income (loss)$(25,478)$(7,944)$17,002 Adjusted EBITDA(3)$15,744 $12,914 $15,253 Distributable Cash Flow(3)$12,433 $8,799 $11,528 (1) Production volumes in Boe equivalents calculated at a Btu conversion rate of six Mcf per Bbl.(2) Net premiums include those incurred previously or upon settlement that are attributable to instruments that settled in the period. (3) Non-GAAP financial measure. Please refer to the related disclosure and reconciliation of net income to Adjusted EBITDA and Distributable Cash Flow included in this press release.

EX-1.99.1 2 mcep-prx3q15earningspressr.htm EXHIBIT 1.99.1 Exhibit


Mid-Con Energy Partners, LP Announces Third Quarter 2015 Operating and Financial Results

DALLAS, November 2, 2015 – Mid-Con Energy Partners, LP (NASDAQ: MCEP) (“Mid-Con Energy” or the “Partnership”) announces operating and financial results for the third quarter ended September 30, 2015. "I believe the adversity our Partnership has faced during the past year has revealed the true character of Mid-Con Energy," commented Jeff Olmstead, President and CEO. "We are, and have always been, a conservative organization that works hard and focuses on our strengths. To this end, in response to low oil prices, we have been compelled to make tough decisions that look to the long-term value of the Partnership. I am extremely proud of our team's execution during the third quarter and year-to-date; in 2015, we have grown production 6.6% by spending approximately $11 million in capital while lowering per Boe cash operating costs by 23.7%, reducing our debt outstanding by 7.3%, and last but not least, adhering to our strategic focus. I commend the fine work of the entire Mid-Con Energy team who are working passionately to provide continued strong performance in the quarters ahead."


THIRD QUARTER 2015 HIGHLIGHTS
Production averaged 4,859 Boe/d, an increase of 5.3% sequentially and 56.8% year-over-year.
Prices, inclusive of cash settlements from matured derivatives and of net premiums, averaged $60.10/Boe, up 6.1% sequentially and down 32.6% year-over-year.
LOE averaged $19.60/Boe, an increase of 8.0% sequentially and a decrease of 18.4% year-over-year.
Adjusted EBITDA, a Non-GAAP measure, was $15.7 million, up 21.9% sequentially and 3.2% year-over-year.
Distributable Cash Flow, a Non-GAAP measure, was $12.4 million, up 41.3% sequentially and 7.9% year-over-year.

The following table reflects selected operating and financial results for the third quarter of 2015, compared to the second quarter of 2015 and third quarter of 2014. Mid-Con Energy’s unaudited condensed consolidated financial statements are included at the end of this press release.
 
 
Three Months Ended
 
 
September 30,
 
June 30,
 
September 30,
($ in thousands)
 
2015
 
2015
 
2014
Average net daily production (Boe/d)(1)
 
4,859

 
4,615

 
3,098

Oil & natural gas sales plus cash settlements from matured derivatives, inclusive of premiums, net(2)
 
$
26,867

 
$
23,792

 
$
25,413

Net income (loss)
 
$
(25,478
)
 
$
(7,944
)
 
$
17,002

Adjusted EBITDA(3)
 
$
15,744

 
$
12,914

 
$
15,253

Distributable Cash Flow(3)
 
$
12,433

 
$
8,799

 
$
11,528

(1) Production volumes in Boe equivalents calculated at a Btu conversion rate of six Mcf per Bbl.
 
 
(2) Net premiums include those incurred previously or upon settlement that are attributable to instruments that settled in the period.
(3) Non-GAAP financial measure. Please refer to the related disclosure and reconciliation of net income to Adjusted EBITDA and Distributable Cash Flow included in this press release.

1



THIRD QUARTER 2015 RESULTS
Production - Production for the third quarter of 2015 was 447 Mboe, or 4,859 Boe/d. On a daily basis, this represents a 5.3% increase from the second quarter of 2015 and a 56.8% increase year-over-year. The increase in sequential volumes was primarily attributable to development activities in the Northeastern Oklahoma and Permian core areas, while the year-over-year increase also reflected the impact of acquisitions of oil properties in the second half of 2014.

Price Realizations - Oil and natural gas sales were $18.5 million in the third quarter of 2015, or $41.37/Boe of production. On a Boe basis, this represents a 19.6% decrease from the second quarter of 2015 and a 55.0% decrease year-over-year. Cash settlements from matured derivatives, inclusive of net premiums were $8.4 million in the third quarter of 2015 or $18.73/Boe. Cash settlements for matured derivatives, inclusive of net premiums for the second quarter of 2015 and the third quarter of 2014 were $5.19/Boe and $(2.67)/Boe, respectively. For the third quarter of 2015, realized revenues including cash settlements from matured derivatives, inclusive of net premiums were $60.10/Boe, up 6.1% sequentially and down 32.6% year-over-year.

Operating Revenues - Operating revenues, which include cash settlements from matured derivatives, inclusive of net premiums, were $26.9 million, or $60.10/Boe in the third quarter of 2015. Total operating revenues increased 12.9% from the previous quarter and 5.7% from the third quarter of 2014. The positive sequential variance was attributable to 5.3% higher daily production and 6.1% higher realized prices. On a year-over-year basis, the positive variance was the result of 56.8% higher daily production partially offset by 32.6% lower realized prices.

Lease Operating Expenses (“LOE”) - LOE was $8.8 million, or $19.60/Boe, in the third quarter of 2015, an 8.0% increase from the second quarter of 2015 and an 18.4% decrease from the third quarter of 2014, on a per Boe basis. The sequential increase in costs per Boe was due to an increase in workover expenses, primarily in our Southern Oklahoma core area, and higher operating costs in our Hugoton core area. The year-over-year decrease in costs per Boe reflects higher production and the impact of the 2014 Permian acquisition which had and continues to have a significantly lower LOE/Boe profile.

Production Taxes - Production taxes in the third quarter of 2015 were $0.2 million, or $0.46/Boe, reflecting an effective tax rate of 1.1%. Production taxes for the second quarter of 2015 were $1.3 million, or $3.14/Boe, for an effective tax rate of 6.1%. Production taxes for the third quarter of 2014 were $1.8 million, or $6.47/Boe, reflecting an effective tax rate of 7.0%. The sequential and year-over-year decrease in the effective production tax rate was due to the approval by the Oklahoma Tax Commission of an Enhanced Oil Recovery ("EOR") Production Tax Exemption for one of our Northeastern Oklahoma units. Based on an effective date of April 2013, the Partnership recouped approximately $0.8 million in cash production taxes previously paid. The EOR Production Tax Exemption will extend through March 2018 for the mentioned Northeastern Oklahoma unit.

Impairment Expense - We review our long-lived assets to be held and used, including proved oil and natural gas properties, whenever events or circumstances indicate that the carrying value of those assets may not be recoverable. If the carrying amount exceeds the property's estimated fair value, we adjust the carrying amount of the property to fair value through a charge to impairment expense. For the three months ended September 30, 2015, we recorded approximately a $40.9 million non-cash impairment charge primarily in our Hugoton core area, Gulf Coast core area and also in our Permian core area. There was no impairment charge for the three months ended June 30, 2015. For the three months ended September 30, 2014, we recorded a $0.3 million non-cash impairment charge.

Depreciation, Depletion, and Amortization Expenses (“DD&A”) - DD&A for the third quarter of 2015 was $9.7 million, or $21.60/Boe. On a per Boe basis, third quarter 2015 results reflect a 10.8% increase over the previous quarter and a 10.6% increase over the third quarter of 2014. The sequential increase was due to modestly higher depletion rates at select properties while the year-over-year increase was attributable to the acquisition of oil properties in 2014.

General and Administrative Expenses (“G&A”) - G&A during the third quarter of 2015 was $2.3 million, or $5.04/Boe, and included $0.6 million in non-cash equity-based compensation expense related to the Partnership’s long-term incentive program. G&A for the second quarter of 2015 was $1.6 million, or $3.90/Boe, and included $0.4 million in non-cash equity-based compensation. G&A for the third quarter of 2014 was $2.6 million, or $9.13/Boe, and included $1.1 million in non-cash equity-based compensation. The sequential increase in G&A per Boe was due to higher legal and professional fees. The year-over-year decrease in G&A per Boe was due to higher production in the third quarter of 2015 and lower compensation costs related to our non-cash equity-based compensation plan resulting principally from the lower price of our common units.


2



Net Interest Expense - Net interest expense for the third quarter of 2015 was $1.8 million, or $4.03/Boe, a 7.4% decrease from the second quarter of 2015 and a 6.1% decrease from the third quarter of 2014, on a Boe basis. The decrease in net interest expense on a per Boe basis reflects higher production volumes quarter-over-quarter and year-over-year. The average effective interest rate approximated 2.95% for both the third quarter of 2015 and the second quarter of 2015 compared to 2.83% in the third quarter of 2014.
Net Income/(Loss) - For the third quarter of 2015, Mid-Con Energy reported a net loss of $25.5 million. Net loss as reported represents $0.85 per limited partner unit, based on an average of 29.7 million outstanding and fully diluted ("FD") limited partner units during the third quarter of 2015. Net loss for the second quarter of 2015 was $7.9 million, or $0.26 per limited partner unit, based on an average of 29.7 million outstanding and FD limited partner units during the period. For the third quarter of 2014, net income was $17.0 million, or $0.74 per limited partner unit (diluted), based on an average of 22.5 million FD limited partner units outstanding during the period. The negative sequential variance was primarily attributable to a $40.9 million non-cash impairment charge for the three months ended September 30, 2015.  On a year-over-year basis, lower oil prices drove the negative variance in addition to the non-cash impairment charge.

Adjusted EBITDA - Adjusted EBITDA, a Non-GAAP measure, for the third quarter of 2015 was $15.7 million, or $35.22/Boe. The third quarter of 2015 results were 14.5% above the previous quarter of $30.75/Boe and 34.2% below the third quarter of 2014 of $53.52/Boe. Adjusted EBITDA increased sequentially due to higher price realizations and higher production. On a year-over-year basis, the negative variance is attributable to lower oil and gas prices.

Distributable Cash Flow (“DCF”) - DCF, a Non-GAAP measure, for the third quarter of 2015 was $12.4 million after subtracting $1.6 million in cash interest expense and $1.7 million in estimated maintenance capital expenditures from Adjusted EBITDA. Relative to the second quarter of 2015 and the third quarter of 2014, DCF was up 41.3% and up 7.9%, respectively. Distributable Cash Flow per unit was $0.413, based on 29.7 million limited partner units and 360,000 general partner units outstanding as of September 30, 2015.


SUSPENSION OF DISTRIBUTION
On October 21, 2015, the Board of Directors of Mid-Con Energy’s general partner elected to suspend the Partnership's quarterly cash distribution. "We are very aware of the negative near-term impact this decision has on our unitholders, however, suspending distributions in this capital constrained environment maximizes the Partnership's financial flexibility," remarked Mid-Con Energy's CFO, Michael Peterson. "Until visibility on the timing and extent of a recovery in oil prices improves, the best way to protect long-term unitholder value is to preserve capital, delever the balance sheet and focus capital spending to include our best potential development opportunities."


2015 GUIDANCE
The following outlook is subject to all the cautionary statements and limitations described under the "Forward-Looking Statements" caption at the end of this press release.  These estimates and assumptions reflect management's best judgment based on current and anticipated market conditions and other factors.  Although we believe such estimates and assumptions to be reasonable, they are inherently uncertain and involve a number of risks and uncertainties that are beyond our control.


FY 2015 Guidance as of 11/02/2015
 
2015
Net production (Boe/d)(1)
 
4,650 - 4,750
Lease operating expenses per Boe
 
$19.00 - $21.00
Production taxes (% of total revenue)
 
5.7% - 6.1%
 
 
 
Estimated capital expenditures
 
$14.5 MM
 
 
 
(1) Production volumes in Boe equivalents calculated at a Btu conversion rate of six Mcf per Bbl.



3



HEDGING SUMMARY
Mid-Con Energy enters into various commodity derivative contracts intended to achieve more predictable cash flows by reducing the Partnership's exposure to short-term fluctuations in the price of oil and natural gas. We believe this risk management strategy will serve to secure a baseline portion of our revenues and, by retaining some opportunity to participate in upward price movements, may also enable us to realize higher revenues during periods when prices rise.

As of November 2, 2015, the following table reflects volumes of Mid-Con Energy's production hedged by commodity derivative contracts, with the corresponding prices at which the production is hedged:

OIL HEDGES
 
4Q15
 
1Q16
 
2Q16
 
3Q16
 
4Q16
WTI Swap Volume - Conventional (Bbl/d)
 
2,935
 
1,648
 
1,319
 
1,467
 
1,304
Price ($/Bbl)
 
$90.24
 
$90.02
 
$90.03
 
$90.00
 
$64.18
 
 
 
 
 
 
 
 
 
 
 
WTI Swap Volume - Synthetic(1) (Bbl/d)
 
 
1,319
 
1,648
 
1,467
 
Price ($/Bbl)
 
na
 
$50.00
 
$50.00
 
$50.00
 
na
 
 
 
 
 
 
 
 
 
 
 
WTI Swap Volume - Total (Bbl/d)
 
2,935
 
2,967
 
2,967
 
2,935
 
1,304
Price ($/Bbl)
 
$90.24
 
$72.23
 
$67.79
 
$70.00
 
$64.18
% Hedged(2)
 
66%
 
66%
 
66%
 
66%
 
29%
(1) Comprised of long deferred premium put options and short call options in equal volumes.
(2) Based on the midpoint of 2015 guidance at a 95% oil composition.


LIQUIDITY AND BORROWING BASE SUMMARY
As of September 30, 2015, Mid-Con Energy's total liquidity of $27.0 million was comprised of $1.0 million of available cash and $26.0 million of available borrowings under the Partnership's $220.0 million borrowing base from its revolving credit facility. Mid-Con Energy reduced debt outstanding by $6.0 million during the third quarter of 2015 and since quarter end, has paid down an additional $4.0 million to $190.0 million. We initiated our fall 2015 borrowing base redetermination in October 2015 and expect to finalize this process in late November 2015. We do expect that our borrowing base will be reduced as a result of continued declines in oil and natural gas prices, however, the precise amount of the reduction is unknown at this time.


THIRD QUARTER 2015 CONFERENCE CALL
As announced on October 22, 2015, Mid-Con Energy’s management will host a conference call on Tuesday, November 3, 2015 at 9:00 a.m. ET. Interested parties are invited to participate via telephone by dialing ###-###-#### (Conference ID: 55567324) at least five minutes prior to the scheduled start time of the call, or via webcast by clicking on “Events & Presentations” in the investor relations section of the Mid-Con Energy website at www.midconenergypartners.com.

A replay of the conference call will be available through November 10, 2015, by dialing ###-###-#### (Conference ID: 55567324). Additionally, a webcast archive will be available at www.midconenergypartners.com.


UPCOMING CONFERENCES
Mid-Con Energy's management team is scheduled to participate in the following conferences:
RBC Capital Markets' 2015 MLP Conference - Thursday, November 19, 2015, 8:35 a.m. CT in Dallas, TX.
Wells Fargo Securities 14th Annual Energy Symposium - Tuesday, December 8, 2015 - Wednesday, December 9, 2015, in New York, NY.
UBS MLP One-on-One Conference - Monday, January 11, 2016 - Wednesday, January 13, 2016, in Park City, UT.
Updated presentation slides will be made available no later than the morning of each event by clicking on "Events & Presentations" in the investor relations section of the Mid-Con Energy website at www.midconenergypartners.com.



4



QUARTERLY REPORT ON FORM 10-Q
Certain financial results included in this press release and related footnotes will be available in Mid-Con Energy’s September 30, 2015 Quarterly Report on Form 10-Q, which will be filed on or about November 3, 2015.


ABOUT MID-CON ENERGY PARTNERS LP
Mid-Con Energy is a publicly held Delaware limited partnership formed in July 2011 to own, operate, acquire, exploit and develop producing oil and natural gas properties in North America, with a focus on Enhanced Oil Recovery (“EOR”). Mid-Con Energy’s core areas of operation are located in Southern Oklahoma, Northeastern Oklahoma, the Gulf Coast, the Hugoton, and the Permian. For more information, please visit Mid-Con Energy's website at www.midconenergypartners.com.


WITHHOLDING INFORMATION
This release is intended to serve as qualified notice under Treasury Regulation Sections 1.1446-4(b) and (d).  Brokers and nominees should treat one hundred percent (100.0%) of Mid-Con Energy's distributions to foreign investors as being attributable to income that is effectively connected with a United States trade or business.  Accordingly, all of Mid-Con Energy's distributions to foreign investors are subject to federal income tax withholding at the highest effective tax rate for individuals or corporations, as applicable.  Nominees, and not Mid-Con Energy, are treated as withholding agents responsible for withholding on the distributions received by them on behalf of foreign investors.


FORWARD-LOOKING STATEMENTS
This press release includes "forward-looking statements" — that is, statements related to future, not past, events within meaning of the federal securities laws. Forward-looking statements are based on current expectations and include any statement that does not directly relate to a current or historical fact. In this context, forward-looking statements often address expected future business and financial performance, and often contain words such as "anticipate," "believe," “estimate,” "intend," "expect," "plan," “project,” “should,” “goal,” “forecast,” “guidance,” “could,” “may,” “continue,” “might,” “potential,” “scheduled,” or "will" or other similar words. These forward-looking statements involve certain risks and uncertainties and ultimately may not prove to be accurate. Actual results and future events could differ materially from those anticipated in such statements. For further discussion of risks and uncertainties, you should refer to Mid-Con Energy's filings with the Securities and Exchange Commission (“SEC”) available at www.midconenergypartners.com or www.sec.gov. Mid-Con Energy undertakes no obligation and does not intend to update these forward-looking statements to reflect events or circumstances occurring after this press release. You are cautioned not to place undue reliance on these forward-looking statements, which speak only as of the date of this press release. All forward-looking statements are qualified in their entirety by this cautionary statement and our SEC filings. Please see the risks and uncertainties detailed in the "Forward Looking Statements" of our public filings.



5



Mid-Con Energy Partners, LP and subsidiaries
Condensed Consolidated Balance Sheets
(in thousands, except number of units)
(Unaudited)

 
September 30,
2015
 
December 31,
2014
ASSETS

 

CURRENT ASSETS:

 

Cash and cash equivalents
$
961

 
$
3,232

Accounts receivable:

 

Oil and natural gas sales
6,192

 
8,051

Other
2,728

 
4,070

Derivative financial instruments
27,125

 
26,202

Prepaids and other
296

 
652

Total current assets
37,302

 
42,207

PROPERTY AND EQUIPMENT:

 

Oil and natural gas properties, successful efforts method:

 

Proved properties
511,861

 
501,191

Accumulated depletion, depreciation, amortization and impairment
(160,508
)
 
(93,896
)
Total property and equipment, net
351,353

 
407,295

DERIVATIVE FINANCIAL INSTRUMENTS
1,593

 
842

OTHER ASSETS
3,674

 
4,284

Total assets
$
393,922

 
$
454,628

LIABILITIES AND EQUITY

 

CURRENT LIABILITIES:

 

Accounts payable:

 

Trade
$
2,982

 
$
3,630

Related parties
910

 
3,989

Accrued liabilities
59

 
397

Total current liabilities
3,951

 
8,016

OTHER LONG-TERM LIABILITIES
107

 
107

LONG-TERM DEBT
194,000

 
205,000

ASSET RETIREMENT OBLIGATIONS
7,653

 
7,363

COMMITMENTS AND CONTINGENCIES

 

EQUITY

 

Partnership equity:

 

General partner interest
742

 
1,328

Limited partners- 29,726,289 and 29,166,112 units issued and outstanding as of September 30, 2015 and December 31, 2014, respectively.
187,469

 
232,814

Total equity
188,211

 
234,142

Total liabilities and equity
$
393,922

 
$
454,628


6



Mid-Con Energy Partners, LP and subsidiaries
Condensed Consolidated Statements of Operations
(in thousands, except per unit data)
(Unaudited)

 
Three Months Ended 
 September 30,
 
Nine Months Ended September 30,
 
2015
 
2014
 
2015
 
2014
Revenues:
 
 
 
 
 
 
 
Oil sales
$
18,137

 
$
26,011

 
$
56,675

 
$
71,865

Natural gas sales
356

 
162

 
1,000

 
450

Gain on derivatives, net
19,771

 
9,280

 
12,544

 
2,341

Total revenues
38,264

 
35,453

 
70,219

 
74,656

Operating costs and expenses:

 
 
 
 
 
 
Lease operating expenses
8,761

 
6,849

 
25,293

 
18,136

Oil and natural gas production taxes
206

 
1,845

 
2,634

 
4,694

Impairment of proved oil and natural gas properties
40,920

 
303

 
40,920

 
303

Depreciation, depletion and amortization
9,655

 
5,565

 
25,692

 
13,900

Accretion of discount on asset retirement obligations
91

 
64

 
276

 
175

General and administrative
2,253

 
2,602

 
7,531

 
11,958

Total operating costs and expenses
61,886

 
17,228

 
102,346

 
49,166

Income (loss) from operations
(23,622
)
 
18,225

 
(32,127
)
 
25,490

Other income (expense):

 
 
 
 
 
 
Interest income and other
2

 
3

 
8

 
7

Interest expense
(1,804
)
 
(1,226
)
 
(5,361
)
 
(3,087
)
Loss on settlement of ARO
(54
)
 

 
(54
)
 

Total other expense
(1,856
)
 
(1,223
)
 
(5,407
)
 
(3,080
)
Net income (loss)
$
(25,478
)
 
$
17,002

 
$
(37,534
)
 
$
22,410

Computation of net income (loss) per limited partner unit:

 
 
 
 
 
 
General partners’ interest in net income (loss)
$
(306
)
 
$
268

 
$
(451
)
 
$
375

Limited partners’ interest in net income (loss)
$
(25,172
)
 
$
16,734

 
$
(37,083
)
 
$
22,035

 


 
 
 
 
 
 
Net income (loss) per limited partner unit:
 
 
 
 
 
 
 
Basic
$
(0.85
)
 
$
0.75

 
$
(1.25
)
 
$
1.04

Diluted
$
(0.85
)
 
$
0.74

 
$
(1.25
)
 
$
1.04

 
 
 
 
 
 
 
 
Weighted average limited partner units outstanding:
 
 
 
 
 
 
 
Limited partner units (basic)
29,705

 
22,450

 
29,614

 
21,175

Limited partner units (diluted)
29,705

 
22,467

 
29,614

 
21,198

 
 
 
 
 
 
 
 

7



Mid-Con Energy Partners, LP and subsidiaries
Condensed Consolidated Statements of Cash Flows
(in thousands)
(Unaudited)

 
Nine Months Ended 
 September 30,
 
2015
 
2014
Cash Flows from Operating Activities:
 
 
 
Net income (loss)
$
(37,534
)
 
$
22,410

Adjustments to reconcile net income (loss) to net cash provided by operating activities:

 
 
Depreciation, depletion and amortization
25,692

 
13,900

Debt issuance costs amortization
839

 
144

Accretion of discount on asset retirement obligations
276

 
175

Impairment of proved oil and natural gas properties
40,920

 
303

Loss on settlement of ARO
54

 

Cash paid for settlement of ARO
(79
)
 

Mark-to-market on derivatives:
 
 
 
Gain on derivatives, net
(12,544
)
 
(2,341
)
Cash settlements received (paid) for matured derivatives, net
15,566

 
(3,753
)
Cash settlements received from early termination and modification of derivatives, net
11,069

 

Cash premiums paid for derivatives, net
(15,765
)
 

Non-cash equity-based compensation
2,957

 
6,900

Changes in operating assets and liabilities:

 
 
Accounts receivable
1,859

 
(1,717
)
Other receivables
1,342

 
(118
)
Prepaids and other
128

 
(95
)
Accounts payable and accrued liabilities
(3,446
)
 
3,772

Net cash provided by operating activities
31,334

 
39,580

Cash Flows from Investing Activities:
 
 
 
Additions to oil and natural gas properties
(11,250
)
 
(24,079
)
Acquisitions of oil and natural gas properties
(1
)
 
(38,834
)
Net cash used in investing activities
(11,251
)
 
(62,913
)
Cash Flows from Financing Activities:
 
 
 
Proceeds from line of credit
28,000

 
109,000

Payments on line of credit
(39,000
)
 
(53,000
)
Offering costs
(88
)
 

Distributions paid
(11,266
)
 
(32,361
)
Debt issuance costs

 
(170
)
Net cash (used in) provided by financing activities
(22,354
)
 
23,469

Net (decrease) increase in cash and cash equivalents
(2,271
)
 
136

Beginning cash and cash equivalents
3,232

 
1,434

Ending cash and cash equivalents
$
961

 
$
1,570

 
 
 
 
Supplemental Cash Flow Information:
 
 
 
Cash paid for interest
$
4,606

 
$
3,156

Non-Cash Investing and Financing Activities:
 
 
 
Accrued capital expenditures - oil and natural gas properties
$
658

 
$
1,043

Common units issued - acquisition of oil properties
$

 
$
86,001



8




NON-GAAP FINANCIAL MEASURES
This press release, financial tables and other supplemental information include “Adjusted EBITDA” and “Distributable Cash Flow”, each of which are non-generally accepted accounting principles (“Non-GAAP”) measures used by our management to describe financial performance with external users of our financial statements.

The Partnership believes the Non-GAAP financial measures described above are useful to investors because these measurements are used by many companies in its industry as a measurement of financial performance and are commonly employed by financial analysts and others to evaluate the financial performance of the Partnership and to compare the financial performance of the Partnership with the performance of other publicly traded partnerships within its industry.

Adjusted EBITDA and Distributable Cash Flow should not be considered an alternative to net income, net cash provided by operating activities or any other measure of financial performance or liquidity presented in accordance with GAAP.

Adjusted EBITDA is defined as net income (loss) plus:
Interest expense, net;
Depreciation, depletion and amortization;
Accretion of discount on asset retirement obligations;
Loss (gain) on derivatives, net;
Cash settlements received/(paid) for matured derivatives, net;
Cash settlements received for early terminations and modifications of derivatives, net;
Cash premiums paid for matured derivatives, net;
Cash premiums paid for unsettled derivatives, net;
Impairment of proved oil and natural gas properties;
Non-cash equity-based compensation;
Dry hole costs and abandonments of unproved properties; and
Loss (gain) on sale of asset, net.

Distributable Cash Flow is defined as Adjusted EBITDA less:
Cash interest expense; and
Estimated maintenance capital expenditures.
Reconciliation of Net Income to Adjusted EBITDA and Distributable Cash Flow
 
 
Three Months Ended
 
 
September 30,
 
June 30,
 
September 30,
(in thousands, unaudited)
 
2015
 
2015
 
2014
Net income (loss)
 
$
(25,478
)
 
$
(7,944
)
 
$
17,002

Interest expense, net
 
1,802

 
1,827

 
1,223

Depreciation, depletion and amortization
 
9,655

 
8,191

 
5,565

Accretion of discount on asset retirement obligations
 
91

 
93

 
64

Loss (gain) on derivatives, net
 
(19,771
)
 
8,871

 
(9,280
)
Cash settlements received/(paid) for matured derivatives, net
 
8,383

 
2,423

 
(760
)
Cash premiums paid for matured derivatives, net
 
(499
)
 
(919
)
 

Impairment of proved oil and natural gas properties
 
40,920

 

 
303

Non-cash equity based compensation
 
641

 
372

 
1,136

Adjusted EBITDA
 
$
15,744

 
$
12,914

 
$
15,253

Less:
 
 
 
 
 
 
Cash interest expense
 
$
1,567

 
$
1,597

 
$
1,333

Estimated maintenance capital expenditures
 
1,744

 
2,518

 
2,392

Distributable Cash Flow
 
$
12,433

 
$
8,799

 
$
11,528

INVESTOR RELATIONS CONTACT
Krista McKinney
Manager of Investor Relations
(972) 479-5980
***@***

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