TULSA, Feb. 28, 2017 (GLOBE NEWSWIRE) -- Mid-Con Energy Partners, LP (NASDAQ:MCEP) ("Mid-Con Energy" or the "Partnership") announces financial and operating results for the fourth quarter and full year ended December 31, 2016. Also included within the release is the Partnership's guidance for the full year ended December 31, 2017.
"I would like to acknowledge the operational success our team delivered during 2016 in light of challenging market conditions for most in the oil industry," commented Jeff Olmstead, Chief Executive Officer. "In response to lower oil prices, we continued our efforts to reduce costs in the field and office. Cash operating expenses, consisting of lease operating expenses ("LOE"), production taxes, cash general and administrative ("G&A"), and cash interest expense were $25.36/Boe for the full year 2016 and $24.01/Boe during the fourth quarter of 2016. On a per Boe basis, these cash costs declined 11.7% and 13.9% for the comparable periods year-over year, respectively. Full year and fourth quarter 2016 LOE per Boe decreased 21.5% and 23.0% year-over-year, respectively.
"We reduced borrowings outstanding by approximately one-third, or $58.0 million, during the year as a result of cost reductions, combined with assets sales and net proceeds from our preferred equity raise in excess of acquisitions. We ended the year with $18.0 million in accessible borrowings under our revolving credit facility which had a borrowing base of $140.0 million at December 31, 2016. We have positioned Mid-Con Energy for continued success in 2017 and established plans to accelerate key waterflood developments in our Permian and Northeastern Oklahoma core areas."
FULL YEAR 2016 SUMMARY
- Average daily production of 4,038 Boe/d was in-line with the mid-point of full year guidance.
- LOE averaged $15.35/Boe, a decrease of 21.5% year-over-year.
- Realized revenues, inclusive of cash settlements from matured derivatives, inclusive of net premiums, averaged $45.83/Boe, a decrease of 16.9% year-over-year.
- Full year net loss of $24.8 million in 2016 compared to net loss of $95.5 million in 2015.
- Adjusted EBITDA, a Non-GAAP measure, was $45.9 million, a decrease of 16.5% year-over-year.
- Completed non-scheduled redetermination of our borrowing base in August 2016, increasing the conforming borrowing base from $105.0 million to $140.0 million, which was subsequently reaffirmed by the lender group in October 2016 during the fall 2016 redetermination.
- Reduced total debt outstanding by $58.0 million, or 32.2%, during 2016 to $122.0 million as of December 31, 2016. Compliance Total Leverage, as calculated per our credit agreement, was approximately 2.6x as of December 31, 2016.
- Divested Hugoton core area on July 28, 2016, receiving net proceeds of $17.6 million, including post-closing adjustments, used to reduce borrowings outstanding under the revolving credit facility.
- Acquired oil and natural gas properties in Nolan County, Texas ("Permian Bolt-On") on August 11, 2016, for $18.7 million after post-closing adjustments.
- Funded Permian Bolt-On with $25.0 million private offering of Class A Convertible Preferred Units ("Preferred Units") on August 11, 2016, to investors led by John Goff and including, among others, Mid-Con Energy III, LLC, an affiliate of Mid-Con Energy's general partner, Bonanza Capital, and Swank Capital.
The following table reflects selected financial and operating results for the fourth quarter and full year ended December 31, 2016, compared to the previous year. The Partnership’s unaudited consolidated financial statements are included at the end of this press release.
| Three Months Ended | Year Ended | |||||||||||||||
| December 31, | December 31, | |||||||||||||||
| ($ in thousands, unaudited) | 2016 | 2015 | 2016 | 2015 | ||||||||||||
| Average net daily production (Boe/d)(1) | 3,837 | 4,772 | 4,038 | 4,707 | ||||||||||||
| Oil & natural gas sales plus cash settlements from matured derivatives, inclusive of premiums, net(2) | $ | 16,412 | $ | 22,073 | $ | 67,741 | $ | 94,779 | ||||||||
| Net Loss | $ | (3,311 | ) | $ | (57,961 | ) | $ | (24,814 | ) | $ | (95,495 | ) | ||||
| Adjusted EBITDA(3) | $ | 9,002 | $ | 18,993 | $ | 45,901 | $ | 54,982 | ||||||||
| Distributable Cash Flow(3) | $ | 6,242 | $ | 15,462 | $ | 34,417 | $ | 39,892 | ||||||||
| (1) Production volumes in Boe equivalents calculated at a 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 measures. Please refer to the related disclosure and reconciliation of net loss to Adjusted EBITDA and Distributable Cash Flow included in this press release. | ||||||||||||||||
FOURTH QUARTER 2016 RESULTS
Production - Production for the fourth quarter of 2016 was 353 MBoe, or 3,837 Boe/d. On a daily basis, this represents a 3.0% decrease from the third quarter of 2016 and a 19.6% decrease year-over-year. The decrease in sequential volumes was primarily due to disposition of the Hugoton core area in July 2016, declines in select Permian properties under primary production and recent commitments to add injection in our Permian and Northeastern Oklahoma core areas. During the quarter, the Partnership adjusted the target injection formation for two wells and converted six wells from producers to injectors, effectively sacrificing near-term production to benefit the waterflood response in future periods. In addition to the divestiture of the Hugoton core area, the decrease in year-over-year volumes reflected cost savings initiatives implemented in early 2016 that resulted in the temporary shut-in of 184 uneconomic wells in response to lower oil pricing.
Price Realizations - Oil and natural gas sales were $15.6 million in the fourth quarter of 2016, or $44.31/Boe. This represents an 11.9% increase from the third quarter of 2016 and a 19.8% increase year-over-year, on a per Boe basis. Cash settlements from matured derivatives, inclusive of net premiums, were $0.8 million in the fourth quarter of 2016, or $2.18/Boe. Cash settlements from matured derivatives, inclusive of net premiums, for the third quarter of 2016 and the fourth quarter of 2015 were $3.25/Boe and $13.29/Boe, respectively. The resulting realized prices, including cash settlements from matured derivatives, were $46.49/Boe for the fourth quarter of 2016, $42.84/Boe for the third quarter of 2016, and $50.28/Boe for the fourth quarter of 2015.
Operating Revenues - Operating revenues, which include cash settlements from matured derivatives, inclusive of net premiums, were $16.4 million, or $46.49/Boe in the fourth quarter of 2016. This was up 8.5% from the previous quarter and down 7.5% from the fourth quarter of 2015, on a per Boe basis. The positive sequential variance was due to 11.9% higher prices, partially offset by lower production. On a year-over-year basis, the negative variance per Boe was the result of lower production and lower cash settlements from matured derivatives, inclusive of net premiums.
Lease Operating Expenses - LOE was $5.1 million, or $14.56/Boe, in the fourth quarter of 2016, a 7.1% decrease from the third quarter of 2016 and a 23.0% decrease from the fourth quarter of 2015, on a per Boe basis. In addition to ongoing cost reduction initiatives, the decrease in average LOE per Boe, on a sequential and year-over-year basis, reflected the full quarter impact of the divestiture of our higher cost Hugoton core area and lower cost Permian Bolt-On acquisition on a relative basis.
Production Taxes - Production taxes in the fourth quarter of 2016 were $0.8 million, or $2.31/Boe, reflecting an effective tax rate of 5.2%. The effective tax rates for the third quarter of 2016 and the fourth quarter of 2015 were 5.2% and 5.3%, respectively.
Depreciation, Depletion, and Amortization Expenses (“DD&A”) - DD&A for the fourth quarter of 2016 was $5.5 million, or $15.65/Boe. On a per Boe basis, fourth quarter of 2016 was flat compared to the previous quarter and decreased 19.0% from the fourth quarter of 2015. The decrease in DD&A per Boe year-over-year was primarily due to the overall decreased book value of the underlying assets in our portfolio due to an impairment charge incurred during the fourth quarter of 2015.
General and Administrative Expenses - G&A during the fourth quarter of 2016 was $1.6 million, or $4.56/Boe, and included $0.2 million in non-cash equity-based compensation expense related to the Partnership’s long-term incentive program. G&A during the third quarter of 2016 was $1.7 million, or $4.71/Boe, and included $0.3 million in non-cash equity-based compensation expense. G&A during the fourth quarter of 2015 was $1.9 million, or $4.28/Boe, and included $0.2 million in non-cash equity-based compensation expense. The sequential decrease in G&A was primarily due to lower professional fees, public reporting expenses, and a reduction in rent expense as the result of the relocation of our Dallas, Texas, headquarters to Tulsa, Oklahoma, in an effort to consolidate office space. The year-over-year decrease in aggregate G&A of $0.3 million was attributable to non-recurring legal and professional expenses in the fourth quarter of 2015, and corporate cost savings that included headcount reductions, office space consolidation, and successful reductions in discretionary G&A spending.
Net Interest Expense - Net interest expense for the fourth quarter of 2016 was $1.5 million, or $4.25/Boe, a 10.3% decrease from the third quarter of 2016 and a 1.6% decrease from the fourth quarter of 2015, on a per Boe basis. The sequential and year-over-year decrease in net interest expense was the result of material reductions in borrowings outstanding under the revolving credit facility, partially offset by lower production and a higher average effective interest rate. The Partnership reduced total debt by $5.9 million during the fourth quarter of 2016 and by $58.0 million during the year ended 2016. The average effective interest rate was approximately 3.8% in the fourth quarter of 2016 compared to 3.7% in the third quarter of 2016 and 3.3% in the fourth quarter of 2015.
Net Loss - For the fourth quarter of 2016, Mid-Con Energy reported a net loss of $3.3 million, or $0.14 per limited partner unit (basic and diluted), based on an average of 29.9 million limited partner units outstanding during the fourth quarter of 2016. Net loss for the third quarter of 2016 was $2.4 million, or $0.09 per limited partner unit (basic and diluted), based on an average of 29.9 million limited partner units outstanding during the period. For the fourth quarter of 2015, net loss was $58.0 million, or $1.93 per limited partner unit (basic and diluted), based on an average of 29.7 million limited partner units outstanding during the period. The negative sequential variance was primarily attributable to lower cash settlements received from matured derivatives and changes in the mark-to-market value of our unsettled derivatives. Additionally, the Partnership recorded a $63.0 million non-cash impairment charge during the fourth quarter of 2015.
Adjusted EBITDA - Adjusted EBITDA, a Non-GAAP measure, for the fourth quarter of 2016 was $9.0 million, a 24.2% decrease sequentially and a 52.6% decrease compared to the fourth quarter of 2015. On a per Boe basis, Adjusted EBITDA for the fourth quarter of 2016 was $25.50/Boe compared to $32.62/Boe in the third quarter of 2016 and $43.26/Boe in the fourth quarter of 2015. Sequentially and year-over-year, the variance on a per Boe basis was driven by lower production and lower cash settlements from derivatives, inclusive of net premiums, partially offset by lower LOE and G&A.
Distributable Cash Flow (“DCF”) - DCF, a Non-GAAP measure, for the fourth quarter of 2016 was $6.2 million after subtracting $1.1 million in cash interest expense, $1.1 million in estimated maintenance capital expenditures, and $0.5 million in distributions to preferred unitholders from Adjusted EBITDA. Relative to the third quarter of 2016 and the fourth quarter of 2015, DCF decreased 31.4% and 59.6%, respectively.
YEAR END 2016 ESTIMATED NET PROVED RESERVES
Mid-Con Energy’s year end 2016 estimated net proved reserves were 19.2 MMBoe, representing an approximate 13.9% decrease compared to year end 2015 estimated net proved reserves of 22.3 MMBoe. Reserves at year end 2016 were categorized as approximately 95% oil and approximately 65% proved developed, both on a per Boe basis.
At December 31, 2016, the standardized measure of the Partnership’s estimated net proved reserves was $157.3 million. The standardized measure represents the present value of estimated future net revenue to be generated from the production of proved reserves, determined in accordance with the rules and regulations of the SEC, without giving effect to non-property related expenses, such as general and administrative expenses, debt service and future federal income tax expense, or to depreciation, depletion and amortization, and then discounted using an annual rate of 10 percent. Given Mid-Con Energy’s status as a limited partnership, the calculation of standardized measure does not include any provision for federal income tax expense.
The following table shows estimated proved reserves as of December 31, 2016, as prepared by the Partnership’s internal reserve engineers and audited by Cawley, Gillespie & Associates, Inc., independent petroleum engineers.
| Core Area | Oil (MBbl) | Gas (MMcf) | Total(1) (MBoe) | % Total | % Oil | % Proved Developed | |||||||||
| Northeastern Oklahoma | 8,135 | 1,382 | 8,366 | 44% | 97% | 66% | |||||||||
| Permian | 6,983 | 4,698 | 7,766 | 40% | 90% | 59% | |||||||||
| Southern Oklahoma | 2,713 | 44 | 2,720 | 14% | 100% | 74% | |||||||||
| Other | 379 | — | 379 | 2% | 100% | 76% | |||||||||
| Total | 18,210 | 6,124 | 19,231 | 100% | 95% | 65% | |||||||||
| (1) Reserve volumes in Boe equivalents calculated at a rate of six Mcf per Bbl. | |||||||||||||||
2017 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 2017 Guidance as of 02/28/17 | 2017 | |
| Net production (Boe/d)(1) | 3,500 - 3,900 | |
| Lease operating expenses per Boe | $14.50 - $16.50 | |
| Production taxes (% of total revenue) | 5.1% - 5.5% | |
| Estimated capital expenditures | $13.0 MM | |
| (1) Production volumes in Boe equivalents calculated at a rate of six Mcf per Bbl. | ||
HEDGING SUMMARY
Mid-Con Energy enters into various commodity derivative contracts intended to achieve more predictable cash flows by reducing the Partnership's exposure to short-term fluctuations in the prices of oil and natural gas. We believe this risk management strategy will serve to secure a baseline portion of our revenues and, by retaining some opportunity to participate in upward price movements, may also enable us to realize higher revenues during periods when prices rise.
As of February 28, 2017, the following table reflects volumes of Mid-Con Energy's production hedged by commodity derivative contracts, with the corresponding prices at which the production is hedged:
| Oil Hedges | 1Q17 | 2Q17 | 3Q17 | 4Q17 | 1Q18 | 2Q18 | 3Q18 | 4Q18 | 1Q19 | 2Q19 | 3Q19 | 4Q19 | ||||||||||||||||||||||||||||||||||||||||||||||||
| WTI Collar Volume (Bbl/d) | 667 | 659 | 652 | 652 | 1,500 | 1,484 | 1,141 | 1,141 | 433 | 429 | 424 | 424 | ||||||||||||||||||||||||||||||||||||||||||||||||
| Call Strike Price ($/Bbl) | $ | 49.00 | $ | 50.15 | $ | 51.22 | $ | 52.35 | $ | 57.39 | $ | 57.91 | $ | 52.42 | $ | 53.13 | $ | 60.52 | $ | 60.52 | $ | 60.52 | $ | 60.52 | ||||||||||||||||||||||||||||||||||||
| Put Strike Price ($/Bbl) | $ | 40.00 | $ | 45.00 | $ | 45.00 | $ | 45.00 | $ | 45.00 | $ | 45.00 | $ | 43.57 | $ | 43.57 | $ | 50.00 | $ | 50.00 | $ | 50.00 | $ | 50.00 | ||||||||||||||||||||||||||||||||||||
| Put Volume (Bbl/d)(1) | 2,000 | 1,978 | 1,957 | 1,793 | — | — | 326 | 326 | — | — | — | — | ||||||||||||||||||||||||||||||||||||||||||||||||
| Put Strike Price ($/Bbl)(1) | $ | 50.00 | $ | 50.00 | $ | 50.00 | $ | 50.00 | — | — | $ | 45.00 | $ | 45.00 | — | — | — | — | ||||||||||||||||||||||||||||||||||||||||||
| Total Hedged (Bbl/d) | 2,667 | 2,637 | 2,609 | 2,446 | 1,500 | 1,484 | 1,467 | 1,467 | 433 | 429 | 424 | 424 | ||||||||||||||||||||||||||||||||||||||||||||||||
| Floor Strike Price ($/Bbl) | $ | 47.50 | $ | 48.75 | $ | 48.75 | $ | 48.67 | $ | 45.00 | $ | 45.00 | $ | 43.89 | $ | 43.89 | $ | 50.00 | $ | 50.00 | $ | 50.00 | $ | 50.00 | ||||||||||||||||||||||||||||||||||||
| % Hedged(2) | 77 | % | 77 | % | 76 | % | 71 | % | 44 | % | 43 | % | 43 | % | 43 | % | 13 | % | 12 | % | 12 | % | 12 | % | ||||||||||||||||||||||||||||||||||||
| (1) Deferred premium puts include premiums that are to be paid monthly as the contracts settle (refer to our SEC filing for additional details). | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| (2) Estimated percent hedged calculated based on the mid-point of 2017 Boe production guidance multiplied by a 93% oil weighting based on fourth quarter 2016 reported production volumes. | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
LIQUIDITY AND BORROWING BASE SUMMARY
As of December 31, 2016, the Partnership’s total liquidity of $20.4 million included $2.4 million in cash and cash equivalents and $18.0 million of accessible borrowings under the revolving credit facility based on a borrowing base of $140.0 million. During the October 2016 redetermination, our borrowing base was reaffirmed at $140.0 million. As of December 31, 2016, total borrowings outstanding were $122.0 million. As of February 28, 2017, the Partnership had total borrowings outstanding of $121.5 million and approximately $3.0 million in cash and cash equivalents. The next regularly scheduled borrowing base redetermination is estimated to occur on or around April 30, 2017.
FOURTH QUARTER 2016 CONFERENCE CALL
As announced on February 14, 2017, Mid-Con Energy’s management will host a conference call on Wednesday, March 1, 2017, at 9:30 a.m. ET. Interested parties are invited to participate via telephone by dialing 1-877-847-5946 (Conference ID: 68790057) 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 March 8, 2017, by dialing 1-855-859-2056 (Conference ID: 68790057). Additionally, a webcast archive will be available at www.midconenergypartners.com.
UPCOMING CONFERENCE
Mid-Con Energy's management team is scheduled to participate in the EnerCom Dallas Conference on March 2, 2017 in Dallas, Texas. Corresponding presentation slides will be made available no later than the morning of the event by clicking on “Events & Presentations” in the investor relations section of the Mid-Con Energy website at www.midconenergypartners.com.
ANNUAL REPORT ON FORM 10-K AND UNITHOLDERS' SCHEDULE K-1
Certain financial results included in this press release and related footnotes are preliminary and are therefore subject to change prior to filing Mid-Con Energy's audited December 31, 2016, Annual Report on Form 10-K, which will be filed on or about February 28, 2017.
Additionally, our unitholders’ Schedule K-1 for the tax year 2016 will be available for download on the Mid-Con Energy website during the week of March 7, 2017. Any questions related to Schedule K-1 should be directed to Mid-Con Energy Tax Package Support at 1-855-886-9760.
ABOUT MID-CON ENERGY PARTNERS LP
Mid-Con Energy is a publicly held Delaware limited partnership formed in July 2011 to own, acquire, exploit and develop producing oil and natural gas properties in North America, with a focus on Enhanced Oil Recovery. Mid-Con Energy's core areas of operation are located in Southern Oklahoma, Northeastern Oklahoma, and the Permian. For more information, please visit Mid-Con Energy's website at www.midconenergypartners.com.
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" and "Risk Factors" sections of our Annual Report on Form 10-K for the year ended December 31, 2016, and in other documents and reports we file from time to time with the SEC.
| Mid-Con Energy Partners, LP and subsidiaries Consolidated Balance Sheets (in thousands, except number of units) (Unaudited) | |||||||
| December 31, | December 31, | ||||||
| 2016 | 2015 | ||||||
| ASSETS | |||||||
| Current assets: | |||||||
| Cash and cash equivalents | $ | 2,359 | $ | 615 | |||
| Accounts receivable: | |||||||
| Oil and natural gas sales | 5,302 | 4,551 | |||||
| Other | 233 | 5,009 | |||||
| Derivative financial instruments | — | 24,419 | |||||
| Prepaids and other | 662 | 623 | |||||
| Total current assets | 8,556 | 35,217 | |||||
| Property and Equipment: | |||||||
| Oil and natural gas properties, successful efforts method: | |||||||
| Proved properties | 441,479 | 518,916 | |||||
| Other property and equipment | 289 | — | |||||
| Accumulated depletion, depreciation, amortization and impairment | (176,551 | ) | (232,008 | ) | |||
| Total property and equipment, net | 265,217 | 286,908 | |||||
| Derivative financial instruments | — | 1,144 | |||||
| Other assets | 2,513 | 3,817 | |||||
| Total assets | $ | 276,286 | $ | 327,086 | |||
| LIABILITIES, CONVERTIBLE PREFERRED UNITS AND EQUITY | |||||||
| Current liabilities: | |||||||
| Accounts payable: | |||||||
| Trade | $ | 2,554 | $ | 3,185 | |||
| Related parties | 1,133 | 559 | |||||
| Derivative financial instruments | 5,314 | — | |||||
| Accrued liabilities | 146 | 165 | |||||
| Current maturities of long-term debt | — | 30,000 | |||||
| Total current liabilities | 9,147 | 33,909 | |||||
| Derivative financial instruments | 2,495 | — | |||||
| Long-term debt | 122,000 | 150,000 | |||||
| Other long-term liabilities | 93 | — | |||||
| Asset retirement obligations | 11,331 | 12,679 | |||||
| Commitments and contingencies | |||||||
| Class A convertible preferred units - 11,627,906 and 0 issued and outstanding, respectively | 19,570 | — | |||||
| EQUITY, per accompanying statements: | |||||||
| Partnership equity: | |||||||
| General partner interest | (248 | ) | 47 | ||||
| Limited partners - 29,912,230 and 29,724,890 units issued and outstanding, respectively | 111,898 | 130,451 | |||||
| Total equity | 111,650 | 130,498 | |||||
| Total liabilities, convertible preferred units and equity | $ | 276,286 | $ | 327,086 | |||
| Mid-Con Energy Partners, LP and subsidiaries Consolidated Statements of Operations (in thousands, except per unit data) (Unaudited) | |||||||||||||||
| Three Months Ended | Year Ended | ||||||||||||||
| December 31, | December 31, | ||||||||||||||
| 2016 | 2015 | 2016 | 2015 | ||||||||||||
| Revenues: | |||||||||||||||
| Oil sales | $ | 15,208 | $ | 15,845 | $ | 54,773 | $ | 72,520 | |||||||
| Natural gas sales | 434 | 394 | 1,325 | 1,394 | |||||||||||
| (Loss) gain on derivatives, net | (4,238 | ) | 9,822 | (12,202 | ) | 22,366 | |||||||||
| Total revenues | 11,404 | 26,061 | 43,896 | 96,280 | |||||||||||
| Operating costs and expenses: | |||||||||||||||
| Lease operating expenses | 5,141 | 8,298 | 22,692 | 33,591 | |||||||||||
| Oil and natural gas production taxes | 816 | 853 | 2,893 | 3,487 | |||||||||||
| Impairment of proved oil and natural gas properties | — | 63,018 | 895 | 103,938 | |||||||||||
| Impairment of proved oil and natural gas properties sold | — | — | 3,578 | — | |||||||||||
| Depreciation, depletion and amortization | 5,524 | 8,482 | 23,074 | 34,174 | |||||||||||
| Accretion of discount on asset retirement obligations | 134 | 156 | 577 | 432 | |||||||||||
| General and administrative | 1,609 | 1,880 | 6,890 | 9,411 | |||||||||||
| Total operating costs and expenses | 13,224 | 82,687 | 60,599 | 185,033 | |||||||||||
| Loss on sales of oil and natural gas properties, net | (43 | ) | — | (560 | ) | — | |||||||||
| Loss from operations | (1,863 | ) | (56,626 | ) | (17,263 | ) | (88,753 | ) | |||||||
| Other (expense) income: | |||||||||||||||
| Interest income | 3 | 2 | 12 | 11 | |||||||||||
| Interest expense | (1,506 | ) | (1,897 | ) | (7,487 | ) | (7,258 | ) | |||||||
| Other income (expense) | 55 | 548 | (76 | ) | 547 | ||||||||||
| Gain (loss) on settlement of ARO | — | 12 | — | (42 | ) | ||||||||||
| Total other expense | (1,448 | ) | (1,335 | ) | (7,551 | ) | (6,742 | ) | |||||||
| Net Loss | (3,311 | ) | (57,961 | ) | (24,814 | ) | (95,495 | ) | |||||||
| Less: Distributions to preferred unitholders | 809 | — | 1,249 | — | |||||||||||
| Less: General partner's interest in net loss | (39 | ) | (695 | ) | (295 | ) | (1,146 | ) | |||||||
| Limited partners’ interest in net loss | $ | (4,081 | ) | $ | (57,266 | ) | $ | (25,768 | ) | $ | (94,349 | ) | |||
| Net loss per limited partner unit: | |||||||||||||||
| Basic and diluted | $ | (0.14 | ) | $ | (1.93 | ) | $ | (0.86 | ) | $ | (3.18 | ) | |||
| Weighted average limited partner units outstanding: | |||||||||||||||
| Limited partner units (basic and diluted) | 29,912 | 29,725 | 29,834 | 29,642 | |||||||||||
| Mid-Con Energy Partners, LP and subsidiaries Consolidated Statements of Cash Flows (in thousands) (Unaudited) | |||||||
| Year Ended December 31, | |||||||
| 2016 | 2015 | ||||||
| Cash Flows from Operating Activities: | |||||||
| Net loss | $ | (24,814 | ) | $ | (95,495 | ) | |
| Adjustments to reconcile net loss to net cash provided by operating activities: | |||||||
| Depreciation, depletion and amortization | 23,074 | 34,174 | |||||
| Debt issuance costs amortization | 1,372 | 1,156 | |||||
| Accretion of discount on asset retirement obligations | 577 | 432 | |||||
| Impairment of proved oil and natural gas properties | 895 | 103,938 | |||||
| Impairment of proved oil and natural gas properties sold | 3,578 | — | |||||
| Loss on settlement of ARO | — | 42 | |||||
| Cash paid for settlements of ARO | — | (82 | ) | ||||
| Mark to market on derivatives: | |||||||
| Loss (gain) on derivatives, net | 12,202 | (22,366 | ) | ||||
| Cash settlements received for matured derivatives | 20,511 | 28,543 | |||||
| Cash settlements received for early terminations and modifications of derivatives, net | 5,820 | 11,069 | |||||
| Cash premiums paid for derivatives, net | (5,161 | ) | (15,765 | ) | |||
| Loss on sales of oil and natural gas properties, net | 560 | — | |||||
| Non-cash equity-based compensation | 1,184 | 3,204 | |||||
| Changes in operating assets and liabilities: | |||||||
| Accounts receivable | (751 | ) | 3,500 | ||||
| Other receivables | 4,935 | (566 | ) | ||||
| Prepaids and other | (39 | ) | 29 | ||||
| Accounts payable and accrued liabilities | (7 | ) | (3,388 | ) | |||
| Net cash provided by operating activities | 43,936 | 48,425 | |||||
| Cash Flows from Investing Activities: | |||||||
| Additions to oil and natural gas properties | (7,223 | ) | (13,893 | ) | |||
| Additions to other property and equipment | (165 | ) | — | ||||
| Acquisitions of oil and natural gas properties | (18,722 | ) | (1 | ) | |||
| Proceeds from sales of oil and natural gas properties | 17,635 | — | |||||
| Net cash used in investing activities | (8,475 | ) | (13,894 | ) | |||
| Cash Flows from Financing Activities: | |||||||
| Proceeds from line of credit | — | 28,000 | |||||
| Payments on line of credit | (58,000 | ) | (53,000 | ) | |||
| Offering costs | (16 | ) | (194 | ) | |||
| Distributions to common units | — | (11,266 | ) | ||||
| Debt issuance costs | (68 | ) | (688 | ) | |||
| Proceeds from sale of convertible preferred units, net of offering costs | 24,646 | — | |||||
| Distributions to preferred units | (279 | ) | — | ||||
| Net cash used in financing activities | (33,717 | ) | (37,148 | ) | |||
| Net increase (decrease) in cash and cash equivalents | 1,744 | (2,617 | ) | ||||
| Beginning cash and cash equivalents | 615 | 3,232 | |||||
| Ending cash and cash equivalents | $ | 2,359 | $ | 615 | |||
NON-GAAP FINANCIAL MEASURES
This press release, the 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 (loss), 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;
- (Gain) loss on derivatives, net;
- Cash settlements received (paid) for matured derivatives, net;
- Cash settlements received for early terminations and modifications of derivatives, net;
- Cash premiums received (paid) upon settlement for derivatives, net;
- Cash premiums paid at inception of derivatives, net;
- Impairment of proved oil and natural gas properties;
- Impairment of proved oil and natural gas properties sold;
- Non-cash equity-based compensation;
- (Gain) loss on sales of oil and natural gas properties, net.
Distributable Cash Flow is defined as Adjusted EBITDA less:
- Cash interest expense;
- Estimated maintenance capital expenditures;
- Other non-operating cash (income) expense; and
- Distributions to preferred unitholders.
| Mid-Con Energy Partners, LP and subsidiaries | ||||||||||||||||
| Reconciliation of Net Loss to Adjusted EBITDA and Distributable Cash Flow | ||||||||||||||||
| (in thousands) | ||||||||||||||||
| (Unaudited) | ||||||||||||||||
| Three Months Ended | Year Ended | |||||||||||||||
| December 31, | December 31, | |||||||||||||||
| 2016 | 2015 | 2016 | 2015 | |||||||||||||
| Net loss | $ | (3,311 | ) | $ | (57,961 | ) | $ | (24,814 | ) | $ | (95,495 | ) | ||||
| Interest expense, net | 1,502 | 1,895 | 7,475 | 7,248 | ||||||||||||
| Depreciation, depletion and amortization | 5,524 | 8,482 | 23,074 | 34,174 | ||||||||||||
| Accretion of discount on asset retirement obligations | 134 | 156 | 577 | 432 | ||||||||||||
| Loss (gain) on derivatives, net | 4,238 | (9,822 | ) | 12,202 | (22,366 | ) | ||||||||||
| Cash settlements received for matured derivatives, net | 2,044 | 12,977 | 20,511 | 28,543 | ||||||||||||
| Cash settlements received for early terminations and modifications of derivatives, net | — | — | 5,820 | 11,069 | ||||||||||||
| Cash premiums received (paid) upon settlement for derivatives, net | (1,274 | ) | 1 | (5,040 | ) | (1,701 | ) | |||||||||
| Cash premiums paid at inception of derivatives, net | (121 | ) | — | (121 | ) | (14,064 | ) | |||||||||
| Impairment of proved oil and natural gas properties | — | 63,018 | 895 | 103,938 | ||||||||||||
| Impairment of proved oil and natural gas properties sold | — | — | 3,578 | — | ||||||||||||
| Non-cash equity-based compensation | 223 | 247 | 1,184 | 3,204 | ||||||||||||
| Loss on sales of oil and natural gas properties, net | 43 | — | 560 | — | ||||||||||||
| Adjusted EBITDA | $ | 9,002 | $ | 18,993 | $ | 45,901 | $ | 54,982 | ||||||||
| Less: | ||||||||||||||||
| Cash interest expense | 1,135 | 1,464 | 6,198 | 6,070 | ||||||||||||
| Estimated maintenance capital expenditures | 1,123 | 1,520 | 4,473 | 8,473 | ||||||||||||
| Other non-operating cash income | — | 547 | 34 | 547 | ||||||||||||
| Distributions to preferred unitholders | 502 | — | 779 | — | ||||||||||||
| Distributable Cash Flow | $ | 6,242 | $ | 15,462 | $ | 34,417 | $ | 39,892 | ||||||||