Mid-Con Energy Partners, LP Announces Third Quarter 2013 Results

DALLAS, Nov. 5, 2013 (GLOBE NEWSWIRE) -- Mid-Con Energy Partners, LP (Nasdaq:MCEP) ("Mid-Con Energy" or the "Partnership") announced today its financial and operating results for the third quarter ended September 30, 2013.

Mid-Con Energy highlighted the following results:
  • Increased production approximately 32% to 2,522 barrels of oil equivalent (Boe) per day on average in the third quarter of 2013, compared to 1,913 Boe per day on average in the third quarter of 2012. This represents a temporary decrease of approximately 71 Boe per day (or 3%) compared to the 2,593 Boe per day in the second quarter of 2013 due to the conversion of eight production wells to injection wells and ongoing completion operations for eight newly drilled wells.
  • Increased Adjusted EBITDA approximately 26% to $14.9 million in the third quarter of 2013, up $3.1 million from $11.8 million in the third quarter of 2012. Adjusted EBITDA was $16.1 million in the second quarter of 2013.
  • On October 23, 2013, the Board of Directors of Mid-Con Energy's general partner declared a quarterly cash distribution of $0.515 per unit, or $2.06 per unit on an annualized basis.
  • On November 5, 2013, Mid-Con Energy and its lender group executed an amendment to the credit agreement increasing the Partnership's borrowing base from $130.0 million to $150.0 million, extending the maturity approximately two years to November 2018, and adding the Bank of Nova Scotia to its lender group.

The following table reflects selected operating and financial results for the third quarter of 2013, compared to the third quarter of 2012 and second quarter of 2013. Mid-Con Energy's unaudited condensed consolidated financial statements can be found in the supplemental tables of this press release.
  Three Months Ended
  September 30, June 30,
  2013 2012 2013
  ($ in thousands)
Production:      
Oil (MBbl)  227  171  230
Natural gas (MMcf)  32  31  36
Total (MBoe) (1)  232  176  236
       
Average net daily production (Boe/d) (1)  2,522  1,913  2,593
       
Revenues, excluding net settlements on commodity derivatives  $ 22,982  $ 15,048  $ 21,110
Revenues, including net settlements on commodity derivatives  $ 21,689  $ 16,259  $ 21,819
Net income (loss)  $ 4,257  $ (1,137)  $ 10,538
Adjusted EBITDA (2)  $ 14,935  $ 11,830  $ 16,054
Distributable Cash Flow (2)  $ 12,043  $ 10,728  $ 12,776
       
(1) Production volumes in Boe equivalents calculated at a rate of six Mcf per Bbl.
(2) Non-GAAP financial measures. Please refer to the related disclosure and reconciliation of net income (loss) to Adjusted EBITDA and Distributable Cash Flow included in this press release.

Randy Olmstead, Chief Executive Officer and Director, commented, "We recognize the slight downturn in our daily production rate this quarter over the preceding quarter. Occasionally, we need to focus on injection at the expense of current production to increase reserves and future production over the life of the waterfloods. We continue to forecast increases in our proved non-producing reserves, as additional injection plans are executed. Most importantly, our current distribution coverage allows us to complete this work, which will benefit us in the long term, without impacting our current distribution."

Third Quarter 2013 Results

Production volumes for the third quarter of 2013 were 232 thousand barrels of oil equivalent (MBoe) or approximately 2,522 Boe per day on average. In comparison, Mid-Con Energy's production volumes for the third quarter of 2012 were 176 MBoe, or approximately 1,913 Boe per day on average. Positive variances compared to the prior year were attributable to (i) continued waterflood response, (ii) active drilling and workover programs in each core area, and (iii) Mid-Con Energy's acquisition of oil properties and additional working interests in 2012 and 2013.

Production volumes for the third quarter of 2013 decreased approximately 71 Boe per day (3%) compared to approximately 2,593 Boe per day on average during the second quarter of 2013. Oil production volumes decreased due to the conversion of eight production wells to injection wells. In addition, eight wells drilled in 2013 were not in service as of September 30, 2013, due to certain production wells undergoing completion operations (4 wells) and delays with injection permits (4 wells).

Oil sales, excluding the effect of commodity derivatives, were approximately $22.8 million in the third quarter of 2013 and resulted in an average realized oil price of $100.58 per barrel (Bbl). Oil sales in the third quarter of 2012 were approximately $14.9 million, or $87.36 per Bbl. Approximately 85% of Mid-Con Energy's oil production during the third quarter of 2013 was hedged at an average price of $98.18 per Bbl. Given the unfavorable variance between the average hedge price and NYMEX West Texas Intermediate (WTI), the Partnership paid $1.3 million for net settlements on commodity derivatives during the third quarter of 2013, or a negative $5.70 per Bbl. This is the cost of providing protection against significant downward movement in oil prices. On the other hand, during the third quarter of 2012, Mid-Con Energy received $1.2 million, or $7.08 per Bbl, for net settlements on commodity derivatives.

Lease operating expenses were $4.8 million, or $20.55 per Boe, in the third quarter of 2013, compared to $2.6 million, or $14.97 per Boe, in the third quarter of 2012. Lease operating expenses during the third quarter of 2013 were negatively impacted by approximately $0.5 million, or $2.16 per Boe, related to post-closing adjustments from the May 2013 acquisition, workovers in the Hugoton Basin core area, and an increase in administrative overhead rates for select properties.

Production taxes in the third quarter of 2013 were $1.0 million, or $4.34 per Boe, for an effective tax rate of approximately 4.4%. Production taxes in the third quarter of 2012 were $0.6 million, or $3.32 per Boe, for an effective tax rate of approximately 3.9%. A portion of Mid-Con Energy's wells in Oklahoma continue to receive a reduced production tax rate due to the state's Enhanced Recovery Project Gross Production Tax Exemption.

Total general and administrative expenses during the third quarter of 2013 were $1.6 million and included $0.7 million in non-cash equity-based compensation expense related to the Partnership's long-term incentive program. Comparatively, total general and administrative expenses during the third quarter of 2012 were $3.7 million and included $2.5 million in non-cash equity-based compensation expense.

Adjusted EBITDA for the third quarter of 2013 was $14.9 million, approximately 26% above Adjusted EBITDA for the third quarter of 2012 of $11.8 million. Distributable Cash Flow for the third quarter of 2013 was $12.0 million after subtracting $0.9 million in cash interest expense and $2.0 million in estimated maintenance capital expenditures.

Mid-Con Energy reported net income of $4.3 million, or $0.22 per limited partner unit, for the third quarter of 2013 which included a $5.5 million non-cash loss on unsettled derivative contracts. Net loss during the third quarter of 2012 was a negative $1.1 million, or $0.06 per limited partner unit, and included a $6.1 million non-cash loss on unsettled derivative contracts.

Quarterly Cash Distribution

On October 23, 2013, the Board of Directors of Mid-Con Energy's general partner declared a quarterly cash distribution of $0.515 per unit, or $2.06 per unit on an annualized basis, for the quarter ended September 30, 2013. This represented an approximate 6% increase over the third quarter of 2012 cash distribution rate of $0.485 per unit and no change to the second quarter of 2013 cash distribution rate of $0.515 per unit. The cash distribution will be paid November 14, 2013 to unitholders of record at the close of business on November 7, 2013.

Hedging Update

Mid-Con Energy enters into various commodity derivative contracts intended to achieve more predictable cash flows and to reduce its exposure to fluctuations in the price of oil. The Partnership's hedging program objective is to protect its ability to make current distributions, and to be better positioned to increase its quarterly distribution over time, while retaining some ability to participate in upward movements in oil prices. Mid-Con Energy uses a phased approach, looking approximately 36 months forward while targeting a higher hedged percentage in the near 12 month period.

Supplementing its primary hedging strategy described above, Mid-Con Energy also intends to enter into additional commodity derivative contracts in connection with material increases in its estimated production and at times when management believes market conditions or other circumstances suggest that it is prudent to do so, as opposed to entering into commodity derivative contacts at predetermined times or on prescribed terms.

As of November 5, 2013, the following table reflects volumes of Mid-Con Energy's production covered by commodity derivative contracts, and the average prices at which the production will be hedged:
  Oct-Dec 2013 2014 2015
Oil Derivative Contracts:      
A. Swap Contracts:      
Volume (Bbl/d) 1,859 1,973 164
Weighted Average Floor Price per Bbl $98.34 $93.56 $90.05
       
B. Put/Call Option Contracts (Collars):      
Volume (Bbl/d) 293 123
Weighted Average Floor/Ceiling Price per Bbl $97.67 - $108.08 $85.00 - $95.13
       
Total Oil Derivative Contracts (A+B):      
Volume (Bbl/d) 2,152 1,973 287
Weighted Average Floor Price per Bbl $98.25 $93.56 $87.89
       
% of Estimated Oil Production Hedged - Total Proved (1) 79.5% 70.3% 9.5%
       
(1) Based on total proved oil reserves reflected in December 31, 2012 reserve report audited by Cawley, Gillespie & Associates, Inc.

Liquidity Update and Borrowing Base Increase

As of September 30, 2013, the Partnership's total liquidity of $18.7 million included $0.7 million in cash and cash equivalents and $18.0 million of available borrowings under the revolving credit facility.

On November 5, 2013, as part of its regularly scheduled semi-annual redetermination, Mid-Con Energy's lender group unanimously agreed to increase the Partnership's borrowing base from $130.0 million to $150.0 million. In conjunction with this increase, the current maturity was extended by approximately two years to November 5, 2018, and the Bank of Nova Scotia was added to the lender group. There were no other material changes to the credit agreement. The next scheduled redetermination of the borrowing base will occur on or about April 30, 2014.

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, 2013 Quarterly Report on Form 10-Q, which will be filed on or around November 7, 2013.

Earnings Conference Call

As announced on October 24, 2013, Mid-Con Energy's management will host a conference call on Wednesday, November 6, 2013 at 11:00 a.m. ET (10:00 a.m. CT) to discuss operating and financial results. Interested parties are invited to participate via telephone by dialing 1-877-847-5946 (Conference ID: 87711872) 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 telephonic replay of the conference call will be available through November 13, 2013 by dialing 1-855-859-2056 (Conference ID: 87711872). Additionally, a webcast archive will be available at www.midconenergypartners.com.

About Mid-Con Energy Partners, LP

Mid-Con Energy is a 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 the Mid-Continent region of the United States. Mid-Con Energy's core areas of operation are located in Southern Oklahoma, Northeastern Oklahoma and parts of Oklahoma and Colorado within the Hugoton Basin.

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 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.

These forward–looking statements are subject to a number of risks and uncertainties, many of which are beyond our control, which may include statements about our:
  • business strategies;
  • ability to replace the reserves we produce through acquisitions and the development of our properties;
  • oil and natural gas reserves;
  • technology;
  • realized oil and natural gas prices;
  • production volumes;
  • lease operating expenses;
  • general and administrative expenses;
  • future operating results;
  • cash flow and liquidity;
  • availability of production equipment;
  • availability of oil field labor;
  • capital expenditures;
  • availability and terms of capital;
  • marketing of oil and natural gas;
  • general economic conditions;
  • competition in the oil and natural gas industry;
  • effectiveness of risk management activities;
  • environmental liabilities;
  • counterparty credit risk;
  • governmental regulation and taxation;
  • developments in oil producing and natural gas producing countries; and
  • plans, objectives, expectations and intentions.
 
Mid-Con Energy Partners, LP and subsidiaries
Condensed Consolidated Balance Sheets (Unaudited)
(in thousands)
     
  September 30, December 31,
  2013 2012
ASSETS    
CURRENT ASSETS:    
Cash and cash equivalents  $ 659  $ 1,053
Accounts receivable:    
Oil and gas sales  7,016  6,413
Other  --  603
Derivative financial instruments  101  3,679
Prepaids and other  282  25
 Total current assets  8,058  11,773
     
PROPERTY AND EQUIPMENT, at cost:    
Oil and gas properties, successful efforts method:    
Proved properties  212,892  167,036
Accumulated depletion, depreciation and amortization  (32,684)  (21,727)
 Total property and equipment, net  180,208  145,309
     
DERIVATIVE FINANCIAL INSTRUMENTS  57  858
     
OTHER ASSETS  524  650
 Total assets  $ 188,847  $ 158,590
     
LIABILITIES AND EQUITY    
CURRENT LIABILITIES:    
Accounts payable:    
Trade  $ 1,571  $ 2,168
Related parties  2,555  3,036
Derivative financial instruments  1,559  --
Accrued liabilities  113  315
 Total current liabilities  5,798  5,519
     
DERIVIATIVE FINANCIAL INSTRUMENTS  396  --
     
OTHER LONG-TERM LIABILITIES  88  --
     
LONG-TERM DEBT  112,000  78,000
     
ASSET RETIREMENT OBLIGATIONS  3,910  2,890
     
EQUITY:    
Partnership equity    
General partner interest  1,713  1,814
Limited partners – 19,288,562 and 18,990,849 units issued and outstanding as of September 30, 2013 and December 31, 2012, respectively  64,942  70,367
 Total equity  66,655  72,181
 Total liabilities and equity  $ 188,847  $ 158,590
 
 
Mid-Con Energy Partners, LP and subsidiaries
Condensed Consolidated Statements of Operations (Unaudited)
(in thousands, except per unit data)
         
  Three Months Ended Nine Months Ended
  September 30, September 30,
  2013 2012 2013 2012
Revenues:        
 Oil sales   $ 22,831  $ 14,939  $ 63,755  $ 43,937
 Natural gas sales   151  109  513  462
 Net settlements on derivatives   (1,293)  1,211  89  1,980
 Gain (loss) on unsettled derivatives, net   (5,501)  (6,103)  (6,334)  3,638
 Total revenues   16,188  10,156  58,023  50,017
         
Operating costs and expenses:        
 Lease operating expenses   4,768  2,634  11,859  7,359
 Oil and gas production taxes   1,007  585  2,670  1,298
 Impairment of proved oil and gas properties   --  1,255  1,578  1,255
 Depreciation, depletion and amortization   3,586  2,611  10,957  7,320
 Accretion of discount on asset retirement obligations   47  35  124  92
 General and administrative   1,630  3,714  9,667  8,583
 Total operating costs and expenses   11,038  10,834  36,855  25,907
 Income (loss) from operations   5,150  (678)  21,168  24,110
         
Other income (expense):        
 Interest income and other   2  2  6  7
 Interest expense   (895)  (461)  (2,320)  (1,164)
 Total other expense   (893)  (459)  (2,314)  (1,157)
         
Net income (loss)  $ 4,257  $ (1,137)  $ 18,854  $ 22,953
         
Computation of net income (loss) per limited partner unit:        
General partners' interest in net income (loss)  $ 77  $ (22)  $ 346  $ 455
Limited partners' interest in net income (loss)  $ 4,180  $ (1,115)  $ 18,508  $ 22,498
         
Net income (loss) per limited partner unit:        
Basic  $ 0.22  $ (0.06)  $ 0.96  $ 1.26
Diluted  $ 0.22 $ (0.06)  $ 0.96  $ 1.26
         
Weighted average limited partner units outstanding:        
Common limited partner units (basic) 19,269 17,933 19,213 17,790
Common limited partner units (diluted) 19,296  17,933 19,219 17,790
 
 
Mid-Con Energy Partners, LP and subsidiaries
Consolidated Statements of Cash Flows (Unaudited)
(in thousands)
  Nine Months Ended
  September 30,
  2013 2012
Cash Flows from Operating Activities:    
Net income   $ 18,854  $ 22,953
Adjustments to reconcile net income to net cash provided by operating activities:     
Depreciation, depletion and amortization   10,957  7,320
Debt placement fee amortization   126  81
Accretion of discount on asset retirement obligations   124  92
Impairment of proved oil and gas properties   1,578  1,255
Loss (gain) on unsettled derivative instruments, net   6,334  (3,638)
Equity-based compensation   5,419  5,194
Changes in operating assets and liabilities:     
Accounts receivable   (603)  (441)
Other receivables   603  (303)
Prepaids and other   (259)  2,300
Accounts payable and accrued liabilities   (648)  2,972
Net cash provided by operating activities   42,485  37,785
     
Cash Flows from Investing Activities:    
Additions to oil and gas properties   (19,146)  (17,031)
Acquisitions of oil properties   (28,022)  (16,577)
Net cash used in investing activities   (47,168)  (33,608)
     
Cash Flows from Financing Activities:    
 Proceeds from line of credit   87,000  27,000
 Payments on line of credit   (53,000)  (12,000)
 Distributions paid   (29,711)  (18,348)
 Net cash provided by (used in) financing activities   4,289  (3,348)
     
 Net (decrease) increase in cash and cash equivalents   (394)  829
     
Beginning cash and cash equivalents  1,053  228
     
Ending cash and cash equivalents  $ 659  $ 1,057
     
     
Supplemental Cash Flow Information:    
 Cash paid for interest   $ 2,200  $ 1,014
     
Non-Cash Investing and Financing Activities:    
 Accrued capital expenditures - oil and gas properties   $ 373  $ 785

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:
  • Income tax expense (benefit);
  • Interest expense;
  • Depreciation, depletion and amortization;
  • Accretion of discount on asset retirement obligations;
  • Net losses on unsettled derivatives;
  • Impairment expenses;
  • Dry hole costs and abandonments of unproved properties;
  • Equity-based compensation; and
  • Loss on sale of assets;

Less:
  • Interest income;
  • Net gains on unsettled derivatives; and
  • Gain on sale of assets.

Distributable Cash Flow is defined as Adjusted EBITDA

Less:
  • Cash income taxes;
  • Cash interest expense; and
  • Estimated maintenance capital expenditures.
 
 
Reconciliation of Net Income (Loss) to Adjusted EBITDA and Distributable Cash Flow
(in thousands)
 
   Three Months Ended   Nine Months Ended 
  September 30, September 30, June 30, September 30,
  2013 2012 2013 2013
         
 Net income (loss)   $ 4,257  $ (1,137)  $ 10,538  $ 18,854
 Interest expense   895  461  812  2,320
 Depreciation, depletion and amortization   3,586  2,611  3,908  10,957
 Accretion of discount on asset retirement obligations   47  35  39  124
 Loss (gain) on unsettled derivatives, net   5,501  6,103  (960)  6,334
 Impairment expense   --  1,255  1,578  1,578
 Equity-based compensation   651  2,504  142  5,419
 Interest income   (2)  (2)  (3)  (6)
 Adjusted EBITDA   $ 14,935  $ 11,830  $ 16,054  $ 45,580
         
Less:        
Cash interest expense  $ 861  $ 340  $ 779  $ 2,200
Estimated maintenance capital expenditures  2,031  762  2,499  6,548
Distributable Cash Flow  $ 12,043  $ 10,728  $ 12,776  $ 36,832
         
CONTACT: Jeff Olmstead         President and Chief Financial Officer         (972) 479-5980         jolmstead@midcon-energy.com                  Matthew Lewis         Associate         (972) 479-5984         mlewis@midcon-energy.com

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