SRC Energy Inc. Reports Second Quarter 2019 Financial Results


DENVER, July 31, 2019 (GLOBE NEWSWIRE) -- SRC Energy Inc. (NYSE American: SRCI) (“SRC”, the “Company”, “we”, “us” or “our”), a U.S. oil and gas exploration and production company with operations focused on the Wattenberg Field in the Denver-Julesburg Basin, reports its financial results for the three and six months ended June 30, 2019.

Second Quarter 2019 Highlights

  • Revenues were $162.6 million and $352.1 million for the three and six months ended June 30, 2019, respectively
  • Net income was $54.5 million or $0.22 per diluted share and $104.2 million or $0.43 per diluted share for the three and six months ended June 30, 2019, respectively
  • Adjusted EBITDA was $127.9 million and $287.5 million for the three and six months ended June 30, 2019, respectively (see further discussion regarding the presentation of adjusted EBITDA in "About Non-GAAP Financial Measures" below)
  • Drilling and completion capital expenditures of $91 million and $201 million for the three and six months ended June 30, 2019, respectively, were funded from EBITDA
  • Reduced the balance outstanding on SRC's revolving credit facility by $30 million

Second Quarter 2019 Financial Results
The following table presents certain per unit metrics that compare results of the corresponding reporting periods:

  Three Months Ended Six Months Ended
Net Volumes 6/30/2019 3/31/2019 % Chg. 6/30/2018 % Chg. 6/30/2019 6/30/2018 % Chg.
Crude Oil (MBbls)  2,441  2,967 (18)%  1,846 32%  5,408  3,887 39%
NGL (MBbls)  1,111  1,054 5%  992 12%  2,165  1,750 24%
Natural Gas (MMcf)  11,905  11,391 5%  8,987 32%  23,296  16,706 39%
Sales Volumes: (MBOE)  5,536  5,919 (6)%  4,336 28%  11,455  8,422 36%
Average Daily Volumes                
Daily Production (BOE)  60,833  65,771 (8)%  47,646 28%  63,288  46,528 36%
Product Price Received                
Crude Oil ($/Bbl) (1) $52.75 $48.33 9% $61.22 (14)% $50.32 $58.48 (14)%
Natural Gas Liquids ($/Bbl) $9.39 $12.59 (25)% $17.65 (47)%  10.95  18.30 (40)%
Natural Gas ($/Mcf) (1) $1.58 $2.52 (37)% $1.64 (4)% $2.04 $1.87 9%
Avg. Sales Price ($/BOE) (1) $28.53 $31.32 (9)% $33.50 (15)% $29.97 $34.50 (13)%
Per Unit Cost Information ($/BOE)      
Lease Operating Expense $2.39 $2.93 (18)% $2.68 (11)% $2.67 $2.31 16%
Production Tax $2.38 $1.20 98% $3.47 (31)% $1.77 $3.38 (48)%
DD&A Expense $10.48 $10.29 2% $9.66 8% $10.38 $9.38 11%
Net G&A Expense (2) $1.67 $1.60 4% $2.17 (23)% $1.64 $2.26 (27)%
Gross G&A Expense (3) $2.30 $2.22 4% $2.93 (22)% $2.26 $3.02 (25)%
(1) - Includes transportation and gathering expense  (2) - Net of capitalized portion  (3) - Gross of capitalized portion

Revenues for the three months ended June 30, 2019 decreased 14% compared to the three months ended March 31, 2019 and increased 11% compared to the three months ended June 30, 2018.  While sales volumes decreased 8% quarter-over-quarter, 9% lower average realized prices compounded the revenue decline in a quarter-over-quarter comparison.  The year-over-year increase in revenues was driven by growth in sales volumes.  Natural gas liquids pricing during the quarter ended June 30, 2019 was impacted by generally weaker product pricing for ethane, propane and other components of the NGL stream in US markets.

The Company's 2019 second quarter net income totaled $54.5 million, or $0.22 per diluted share, compared to net income of $49.8 million, or $0.20 per diluted share, in the first quarter of 2019 and $49.6 million, or $0.20 per diluted share, in the second quarter of 2018.

Midstream Operations Update
Gas gathering and processing constraints have continued to limit activity and have ultimately impacted well productivity within the DJ Basin.  DCP Midstream’s system-wide producer allocation remains in effect with an intent of stabilizing line pressures. Despite the allocation limitation, we encountered significant planned and unplanned downtime which further reduced system capacity throughout the 2nd quarter.  This resulted in consistently high line pressures, restricting our ability to maintain consistent production levels.

As DCP Midstream's O'Connor II plant commissioning phase is finalized and throughput ramps up over the upcoming weeks, we expect some improvement in line pressure as the system balances out over the remainder of the year.  DCP’s recent announcement of its agreement with Western Midstream Partners, including the Latham II plant, should help further relieve constraints by mid-2020.

Management Comment
Lynn A. Peterson, Chairman and CEO of SRC Energy Inc. commented, "While our operations were mostly in line with guidance as set out earlier, we continue to face significant ongoing operational challenges stemming from a lack of gas processing capacity and timing of associated expansions.  The second quarter was hindered by several midstream interruptions which impacted our production volume and the composition of our production."

Mr. Peterson continued, "Our 2019 budget was built around anticipated midstream constraints and in the second quarter we began to reduce our activity level, in line with our 2019 budget.  We released our completion crew in mid-May, which is reflected in lower capital expenditures for the quarter.  In addition, we will release one of our drilling rigs in the third quarter.  We expect to continue with one drilling rig throughout the balance of 2019 and into 2020.  In an ongoing effort to reduce gas emissions and be a leader in the communities where we operate, we will test a new electric hydraulic stimulation fleet, designed by Halliburton, in the third quarter."

Mr. Peterson concluded, "Despite the operational issues, SRC generated positive free cash flow for the three and six months ended June 30, 2019, allowing us to reduce the amount outstanding under our revolving line of credit.”

Conference Call
The Company will host a conference call on Thursday, August 1, 2019 at 10:00 a.m. Eastern time (8:00 a.m. Mountain time) to discuss the results.  The call will be conducted by Chairman and CEO Lynn A. Peterson, CFO James Henderson, Chief Development Officer Nick Spence, Chief Operations Officer Mike Eberhard, Vice President of Midstream and Marketing Jo Ann Stockton and Manager of Investor Relations John Richardson.  A Q&A session will immediately follow the discussion of the results for the quarter.  Please refer to SRC's website at for the most recent corporate presentation and other news and information.

To participate in this call please dial:
Domestic Dial-in Number:  (877) 407-9122
International Dial-in Number:  (201) 493-6747


Replay Information:
Conference ID #:  13692888
Replay Dial-In (Toll Free US & Canada):  877-660-6853
Replay Dial-In (International):  201-612-7415
Expiration Date:  8/15/19

Upcoming Investor Conferences
Presentations provided in conjunction with these events will be available on SRC's website at the morning of the respective presentation.  Members of SRC senior management will participate in the following hosted investor events, please refer to the Company’s website for specific presentation dates:

Barclays CEO Energy-Power Conference - September 3-5, 2019 - New York, NY

About SRC Energy Inc.

SRC Energy Inc. is a Denver based oil and natural gas exploration and production company. SRC's core area of operations is in the Greater Wattenberg Field of the Denver-Julesburg Basin of Colorado. More company news and information about SRC is available at

Important Cautions Regarding Forward Looking Statements

This press release contains forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995.  All statements other than statements of historical fact are forward-looking statements.  The use of words such as "believes", "expects", "anticipates", "intends", "plans", "estimates", "should", "likely", “guidance” or similar expressions indicates a forward-looking statement.  Forward-looking statements in the release relate to, among other things, future development activities, production and midstream matters.  These statements are subject to risks and uncertainties and are based on the beliefs and assumptions of management, and information currently available to management. The actual results could differ materially from a conclusion, forecast or projection in the forward-looking information. Certain material factors or assumptions were applied in drawing a conclusion or making a forecast or projection as reflected in the forward-looking information. The identification in this press release of factors that may affect the Company's future performance and the accuracy of forward-looking statements is meant to be illustrative and by no means exhaustive. All forward-looking statements should be evaluated with the understanding of their inherent uncertainty. Factors that could cause the Company's actual results to differ materially from those expressed or implied by forward-looking statements include, but are not limited to: risks associated with the construction of new midstream facilities, the impact of those facilities and other risks associated with the availability of adequate midstream infrastructure; the success of the Company's exploration and development efforts; the price of oil and gas; worldwide economic situation; change in interest rates or inflation; willingness and ability of third parties to honor their contractual commitments; the Company's ability to raise additional capital, as it may be affected by current conditions in the stock market and competition in the oil and gas industry for risk capital; the Company's capital costs, which may be affected by delays or cost overruns; costs of production; environmental and other regulations, as the same presently exist or may later be amended; the Company's ability to identify, finance and integrate any future acquisitions; the volatility of the Company's stock price; and the other factors described in the “Risk Factors” sections of the Company’s filings with the Securities and Exchange Commission, all of which are incorporated by reference in this release.  Please see our Quarterly Report on Form 10-Q for the quarter ended March 31, 2019 for discussion of the potential effects on our business of SB19-181, which was passed by the Colorado General Assembly in April 2019.

Reconciliation of Non-GAAP Financial Measure
We define adjusted EBITDA, a non-GAAP financial measure, as net income adjusted to exclude the impact of the items set forth in the table below.  We exclude those items because they can vary substantially from company to company within our industry depending upon accounting methods and book values of assets, capital structures, and the method by which the assets were acquired.  We believe that adjusted EBITDA is widely used in our industry as a measure of operating performance and may also be used by investors to measure our ability to meet debt covenant requirements.  The following table presents a reconciliation of adjusted EBITDA to net income, its nearest GAAP measure:

(unaudited, in thousands)
 Three Months Ended June 30, Six Months Ended June 30,
 2019 2018 2019 2018
Adjusted EBITDA:       
Net income$54,468  $49,624  $104,219  $115,420 
Depreciation, depletion, and accretion58,027  41,877  118,945  78,958 
Stock-based compensation expense3,142  3,146  6,825  5,942 
Mark-to-market of commodity derivative contracts:       
Total (gain) loss on commodity derivatives contracts(8,285) 14,294  14,628  20,075 
Cash settlements on commodity derivative contracts3,089  (4,566) 7,715  (6,121)
Cash premiums paid for commodity derivative contracts(658)   (977)  
Interest income(92) (5) (161) (14)
Income tax expense18,237  3,347  36,271  9,158 
Adjusted EBITDA$127,928  $107,717  $287,465  $223,418 

Condensed Consolidated Financial Statements
Condensed consolidated financial statements are included below. Additional financial information, including footnotes that are considered an integral part of the condensed consolidated financial statements, can be found in SRC's Quarterly Report on Form 10-Q for the period ended June 30, 2019, which is available at

(unaudited; in thousands)
ASSETSJune 30, 2019 December 31, 2018
Current assets:   
Cash and cash equivalents$27,839  $49,609 
Other current assets121,789  182,831 
Total current assets149,628  232,440 
Oil and gas properties and other equipment2,623,634  2,518,700 
Other assets11,824  3,574 
Total assets$2,785,086  $2,754,714 
Current liabilities264,999  353,833 
Revolving credit facility165,000  195,000 
Notes payable, net of issuance costs539,977  539,360 
Asset retirement obligations38,609  40,052 
Other liabilities78,884  40,177 
Total liabilities1,087,469  1,168,422 
Shareholders' equity:   
Common stock and paid-in capital1,499,456  1,492,350 
Retained earnings198,161  93,942 
Total shareholders' equity1,697,617  1,586,292 
Total liabilities and shareholders' equity$2,785,086  $2,754,714 

(unaudited; in thousands)
 Six Months Ended June 30,
 2019 2018
Cash flows from operating activities:   
Net income$104,219  $115,420 
Adjustments to reconcile net income to net cash provided by operating activities:   
Depletion, depreciation, and accretion118,945  78,958 
Provision for deferred taxes36,271  9,158 
Other, non-cash items23,715  15,807 
Changes in operating assets and liabilities18,433  16,419 
Net cash provided by operating activities301,583  235,762 
Cash flows from investing activities:   
Acquisitions of oil and gas properties and leaseholds116  (16,402)
Capital expenditures for drilling and completion activities(276,095) (213,906)
Other capital expenditures(28,566) (25,404)
Proceeds from sales of oil and gas properties and other12,802  766 
Net cash used in investing activities(291,743) (254,946)
Cash flows from financing activities:   
Equity financing activities(1,126) 3,025 
Debt financing activities(30,484) 22,857 
Net cash provided by (used in) financing activities(31,610) 25,882 
Net increase in cash and cash equivalents(21,770) 6,698 
Cash and cash equivalents at beginning of period49,609  48,772 
Cash and cash equivalents at end of period$27,839  $55,470 

(unaudited; in thousands, except share and per share data)
 Three Months Ended June 30, Six Months Ended June 30,
 2019 2018 2019 2018
Oil, natural gas, and NGL revenues$162,602  $147,087  $352,057  $294,320 
Lease operating expenses13,230  11,612  30,590  19,508 
Transportation and gathering4,664  1,880  8,718  3,735 
Production taxes13,185  15,058  20,271  28,501 
Depreciation, depletion, and accretion58,027  41,877  118,945  78,958 
General and administrative9,243  9,406  18,712  19,006 
Total expenses98,349  79,833  197,236  149,708 
Operating income64,253  67,254  154,821  144,612 
Other income (expense):       
Commodity derivatives gain (loss)8,285  (14,294) (14,628) (20,075)
Interest expense, net of amounts capitalized       
Interest income92  5  161  14 
Other income75  6  136  27 
Total other income (expense)8,452  (14,283) (14,331) (20,034)
Income before income taxes72,705  52,971  140,490  124,578 
Income tax expense18,237  3,347  36,271  9,158 
Net income$54,468  $49,624  $104,219  $115,420 
Net income per common share:       
Basic$0.22  $0.20  $0.43  $0.48 
Diluted$0.22  $0.20  $0.43  $0.47 
Weighted-average shares outstanding:       
Basic243,404,917  242,255,724  243,348,141  242,005,211 
Diluted244,130,245  244,464,776  243,709,915  243,954,673 


Contact Data