HOUSTON, TX–(Marketwired – Apr 6, 2016) – Yuma Energy, Inc. (NYSE MKT: YUMA) (NYSE MKT: YUMA-PA) (the “Company” or “Yuma”) today announced that it is re-issuing its previous release that was made on March 30, 2016 to incorporate certain disclosures that are required under the NYSE MKT Company Guide Sections 401(h) and 610(b). Included below are these additional disclosures along with the previously disclosed financial results for the year ended December 31, 2015 and the operational overview relating to its properties.
Year End and Fourth Quarter 2015 Highlights
- Net average production was 1,802 Boe/d for the 4th quarter 2015, a 3 percent increase over 4th quarter 2014
- Lease operating expenses and workover costs were $2.2 million for the 4th quarter 2015, a 54 percent reduction when compared to 4th quarter 2014 results
- 2015 full year G&A costs were $9.7 million, a 16 percent reduction when compared to 2014
- Started discussions prior to year-end 2015 and an all-stock definitive merger agreement with Davis Petroleum Acquisition Corp. (“Davis”) was executed in February of 2016. The merger is expected to close in mid-2016. As of December 31, 2015, Davis had zero debt and $4.1 million in cash with proved reserves of 4.8 MMBoe. During the 4th quarter of 2015, Davis’ production averaged 1,533 barrels of oil equivalent per day (Boe/d).
- Commodity derivatives were entered into for calendar year 2016 representing 298,957 MMBtu of natural gas at an average price of $3.28 and 138,286 barrels of oil at an average price of $62.27 with a $40.00 floor sold price at year-end 2015
Management Comments
Sam L. Banks, Chairman, President and CEO of Yuma Energy, Inc., commented, “We are excited about the progress made during the year as well as the proposed merger with Davis Petroleum Acquisition Corp. (“Davis”). While the price of oil and natural gas has declined dramatically since mid-year 2014, we have taken the appropriate steps to reduce our capital spending, operating costs, and G&A and believe that with the completion of the merger we will be positioned to take advantage of the opportunities that will arise out of the current industry downturn, primarily through further consolidations and acquisitions. The merger with Davis allows us to increase our liquidity and improve our financial position, while at the same time nearly doubling our production and increasing our reserves. The transaction represents a significant opportunity for the shareholders of both companies to benefit from the combined strengths of Yuma and Davis, and creates a diversified Company with unconventional and conventional resource exposure in the onshore Gulf Coast region. In addition, we expect meaningful G&A synergies associated with the merger. We look forward to the successful completion of the merger and the creation of a unified company that is uniquely qualified to create value from the significant upside potential intrinsic to both companies.”
Operational Highlights
In 2015, we significantly reduced our capital spending and focused on low cost, high rate of return projects. We drilled and completed one new well in 2015 and completed another well that was drilled during the fourth quarter of 2014. Total 2015 capital expenditures on drilling, completions, re-completions, and capitalized workovers were approximately $5.7 million, a 70 percent ($13.4 million) reduction when compared to 2014.
In 2015, we also focused on reducing our controllable costs to offset lower commodity prices and increase our margins. Lease operating expenses and workover costs during the 4th quarter 2015 were approximately $2.2 million, a 54 percent ($2.6 million) reduction when compared to the 4th quarter 2014. For the full year of 2015, lease operating expenses and workover costs were approximately $12.0 million, or 25 percent ($3.9 million) lower than in 2014. We have reduced total operating expenses quarter after quarter in 2015 and will continue to look for ways to optimize our operations to withstand the lower price environment.
Net production averaged 1,802 Boe/d during the 4th quarter 2015, which was 3 percent (47 Boe/d) higher than the same quarter in the prior year. Net average production for the full year of 2015 was 1,792 Boe/d, down 16 percent (351 Boe/d) when compared to the full year of 2014, primarily due to the high production levels experienced at La Posada during the first two quarters of 2014.
Oil and Natural Gas Reserves
The table below summarizes our estimated proved reserves at December 31, 2015 based on the report prepared by Netherland, Sewell & Associates, Inc. (“NSAI”), an independent petroleum engineering firm. In preparing its report, NSAI evaluated 100% of our properties at December 31, 2015. The information in the following table does not give any effect to or reflect our commodity derivatives.
Oil (MBbls) |
Natural Gas Liquids (MBbls) |
Natural Gas (MMcf) |
Total (MBoe)(1) |
Present Value Discounted at 10% ($ in thousands)(2) |
||||||
Proved developed(3) | ||||||||||
Total proved developed | 1,802 | 316 | 8,553 | 3,543 | $44,072 | |||||
Proved undeveloped(3) | ||||||||||
Total proved undeveloped | 5,114 | 1,735 | 17,217 | 9,718 | $78,836 | |||||
Total proved (3) | 6,916 | 2,051 | 25,770 | 13,261 | $122,908 | |||||
(1) Barrels of oil equivalent have been calculated on the basis of six thousand cubic feet (Mcf) of natural gas equal to one barrel of oil equivalent (Boe).
(2) Present Value Discounted at 10% (“PV10”) is a Non-GAAP measure that differs from the GAAP measure “standardized measure of discounted future net cash flows” in that PV10 is calculated without regard to future income taxes. Management believes that the presentation of the PV10 value is relevant and useful to investors because it presents the estimated discounted future net cash flows attributable to our estimated proved reserves independent of our income tax attributes, thereby isolating the intrinsic value of the estimated future cash flows attributable to our reserves. Because many factors that are unique to each individual company impact the amount of future income taxes to be paid, we believe the use of a pre-tax measure provides greater comparability of assets when evaluating companies. For these reasons, management uses, and believes the industry generally uses, the PV10 measure in evaluating and comparing acquisition candidates and assessing the potential return on investment related to investments in oil and natural gas properties. PV10 does not necessarily represent the fair market value of oil and natural gas properties.
PV10 is not a measure of financial or operational performance under GAAP, nor should it be considered in isolation or as a substitute for the standardized measure of discounted future net cash flows as defined under GAAP. For a presentation of the standardized measure of discounted future net cash flows, see Note 25 – Supplementary Information on Oil and Natural Gas Exploration, Development and Production Activities (Unaudited) in the Notes to the Consolidated Financial Statements contained in our annual report on Form 10-K for the year ended December 31, 2015. The table below titled “Non-GAAP Reconciliation” provides a reconciliation of PV10 to the standardized measure of discounted future net cash flows.
Non-GAAP Reconciliation ($ in thousands)
The following table reconciles our direct interest in oil, natural gas and natural gas liquids reserves as of December 31, 2015:
Present value of estimated future net revenues (PV10) | $ 122,908 | |
Future income taxes discounted at 10% | (16,845) | |
Standardized measure of discounted future net cash flows | $ 106,063 | |
(3) Proved reserves were calculated using prices equal to the twelve-month unweighted arithmetic average of the first-day-of-the-month prices for each of the preceding twelve months, which were $50.28 per Bbl (WTI) and $2.59 per MMBtu (HH), for the year ended December 31, 2015. Adjustments were made for location and grade.
Financial Results
Production
The following table presents the net quantities of oil, natural gas and natural gas liquids produced and sold by us for the years ended December 31, 2015, 2014 and 2013, and the average sales price per unit sold.
Years Ended December 31, | |||||||
2015 | 2014 | 2013 | |||||
Production volumes: | |||||||
Crude oil and condensate (Bbl) | 247,177 | 231,816 | 184,349 | ||||
Natural gas (Mcf) | 1,993,842 | 2,714,586 | 1,580,468 | ||||
Natural gas liquids (Bbl) | 74,511 | 97,783 | 51,875 | ||||
Total (Boe) (1) | 653,995 | 782,030 | 499,635 | ||||
Average prices realized: | |||||||
Excluding commodity derivatives: | |||||||
Crude oil and condensate (per Bbl) | $48.07 | $93.98 | $104.26 | ||||
Natural gas (per Mcf) | $2.60 | $4.62 | $3.83 | ||||
Natural gas liquids (per Bbl) | $18.89 | $38.44 | $40.17 | ||||
Including commodity derivatives: | |||||||
Crude oil and condensate (per Bbl) | $65.20 | $101.98 | $104.39 | ||||
Natural gas (per Mcf) | $3.00 | $5.19 | $3.71 | ||||
Natural gas liquids (per Bbl) | $18.89 | $38.44 | $40.17 | ||||
(1) | Barrels of oil equivalent have been calculated on the basis of six thousand cubic feet (Mcf) of natural gas equal to one barrel of oil equivalent (Boe). |
Revenues
The following table presents our revenues for the years ended December 31, 2015, 2014 and 2013.
Years Ended December 31, | |||||||||||
2015 | 2014 | 2013 | |||||||||
Sales of natural gas and crude oil: | |||||||||||
Crude oil and condensate | $ | 11,881,626 | $ | 21,785,636 | $ | 19,220,185 | |||||
Natural gas | 5,181,715 | 12,542,671 | 6,049,500 | ||||||||
Natural gas liquids | 1,407,512 | 3,758,875 | 2,083,905 | ||||||||
Gain/(loss) on commodity derivatives | 5,038,826 | 3,398,518 | (159,810 | ) | |||||||
Gas marketing | 209,731 | 572,210 | 881,823 | ||||||||
Total revenues | $ | 23,719,410 | $ | 42,057,910 | $ | 28,075,603 | |||||
NON-GAAP FINANCIAL MEASURES
Adjusted EBITDA
The following table reconciles reported net income to Adjusted EBITDA for the periods indicated:
Years Ended December 31, | ||||||||||||
2015 | 2014 | 2013 | ||||||||||
Net Income (loss) | $ | (11,005,038 | ) | $ | (20,225,150 | ) | $ | (33,050,103 | ) | |||
Depreciation, depletion & amortization of property and equipment | 13,651,207 | 19,664,991 | 12,077,368 | |||||||||
Interest expense, net of interest income and amounts capitalized | 436,836 | 302,568 | 560,340 | |||||||||
Income tax benefit | (7,983,039 | ) | (2,553,854 | ) | 3,080,272 | |||||||
Goodwill impairment | 5,349,988 | – | – | |||||||||
Stock-based compensation net of capitalized cost | 2,289,311 | 3,388,321 | 452,058 | |||||||||
Unrealized (gains) losses on commodity derivatives | 949,967 | (4,724,985 | ) | 231,886 | ||||||||
Accretion of asset retirement obligation | 604,538 | 604,511 | 668,497 | |||||||||
Costs to obtain a public listing | – | 2,935,536 | 24,592 | |||||||||
Increase in value of preferred stock derivative liability | – | 15,676,842 | 26,258,559 | |||||||||
Bank mandated commodity derivative novation cost | – | – | 175,000 | |||||||||
Amortization of benefit from commodity derivatives sold | – | (93,750 | ) | (72,600 | ) | |||||||
Adjusted EBITDA | $ | 4,293,770 | $ | 14,975,030 | $ | 10,405,869 | ||||||
Adjusted EBITDA is used as a supplemental financial measure by our management and by external users of our financial statements, such as investors, commercial banks and others, to assess our operating performance compared to that of other companies in our industry, without regard to financing methods, capital structure or historical costs basis. It is also used to assess our ability to incur and service debt and fund capital expenditures.
Our Adjusted EBITDA should not be considered an alternative to net income (loss), operating income (loss), cash flow provided by (used in) operating activities or any other measure of financial performance or liquidity presented in accordance with GAAP. Our Adjusted EBITDA may not be comparable to similarly titled measures of another company because all companies may not calculate Adjusted EBITDA in the same manner. Adjusted EBITDA for the year ended December 31, 2015 decreased from 2014 by $10,681,260 (71.3%). Adjusted EBITDA for the year ended December 31, 2014 increased from 2013 by $4,569,161 (43.9%).
Commodity Derivative Instruments
Commodity derivative instruments open as of December 31, 2015 are provided below. Natural gas prices are NYMEX Henry Hub prices, and crude oil prices are NYMEX West Texas Intermediate (“WTI”), except for the oil swaps noted below that are based on LLS.
2016 | 2017 | |||
Settlement | Settlement | |||
NATURAL GAS (MMBtu): | ||||
Swaps | ||||
Volume | 298,957 | – | ||
Price (NYMEX) | $3.28 | – | ||
3-way collars | ||||
Volume | – | 67,361 | ||
Ceiling sold price (call) (NYMEX) | – | $4.03 | ||
Floor purchased price (put) (NYMEX) | – | $3.50 | ||
Floor sold price (short put) (NYMEX) | – | $3.00 | ||
CRUDE OIL (Bbls): | ||||
Put spread | ||||
Volume | 138,286 | – | ||
Floor purchased price (put) (LLS) | $62.27 | – | ||
Floor sold price (short put) (LLS) | $40.00 | – | ||
3-way collars | ||||
Volume | – | 113,029 | ||
Ceiling sold price (call) (WTI) | – | $77.00 | ||
Floor purchased price (put) (WTI) | – | $60.00 | ||
Floor sold price (short put) (WTI) | – | $45.00 | ||
Yuma Energy, Inc. | ||||||||
CONSOLIDATED BALANCE SHEETS | ||||||||
(Unaudited) | ||||||||
December 31, | ||||||||
2015 | 2014 | |||||||
ASSETS | ||||||||
CURRENT ASSETS: | ||||||||
Cash and cash equivalents | $ | 5,355,191 | $ | 11,558,322 | ||||
Short-term investments | – | 1,170,868 | ||||||
Accounts receivable, net of allowance for doubtful accounts: | ||||||||
Trade | 2,829,266 | 9,739,737 | ||||||
Officers and employees | 75,404 | 316,077 | ||||||
Other | 633,573 | 856,562 | ||||||
Commodity derivative instruments | 2,658,047 | 3,338,537 | ||||||
Prepayments | 704,523 | 782,234 | ||||||
Other deferred charges | 415,740 | 342,798 | ||||||
Total current assets | 12,671,744 | 28,105,135 | ||||||
OIL AND GAS PROPERTIES (full cost method): | ||||||||
Not subject to amortization | 14,288,716 | 25,707,052 | ||||||
Subject to amortization | 204,512,038 | 186,530,863 | ||||||
218,800,754 | 212,237,915 | |||||||
Less: accumulated depreciation, depletion and amortization | (117,304,945 | ) | (103,929,493 | ) | ||||
Net oil and gas properties | 101,495,809 | 108,308,422 | ||||||
OTHER PROPERTY AND EQUIPMENT: | ||||||||
Land, buildings and improvements | 2,795,000 | 2,795,000 | ||||||
Other property and equipment | 3,460,507 | 3,439,688 | ||||||
6,255,507 | 6,234,688 | |||||||
Less: accumulated depreciation and amortization | (2,174,316 | ) | (1,909,352 | ) | ||||
Net other property and equipment | 4,081,191 | 4,325,336 | ||||||
OTHER ASSETS AND DEFERRED CHARGES: | ||||||||
Commodity derivative instruments | 1,070,541 | 1,403,109 | ||||||
Deposits | 264,064 | 264,064 | ||||||
Goodwill | – | 5,349,988 | ||||||
Other noncurrent assets | 38,104 | 262,200 | ||||||
Total other assets and deferred charges | 1,372,709 | 7,279,361 | ||||||
TOTAL ASSETS | $ | 119,621,453 | $ | 148,018,254 |
Yuma Energy, Inc. | |||||||
CONSOLIDATED BALANCE SHEETS – CONTINUED | |||||||
(Unaudited) | |||||||
December 31, | |||||||
2015 | 2014 | ||||||
LIABILITIES AND EQUITY | |||||||
CURRENT LIABILITIES: | |||||||
Current maturities of debt | $ | 30,063,635 | $ | 282,843 | |||
Accounts payable, principally trade | 7,933,664 | 25,004,364 | |||||
Asset retirement obligations | 70,000 | – | |||||
Other accrued liabilities | 1,781,484 | 1,419,565 | |||||
Total current liabilities | 39,848,783 | 26,706,772 | |||||
LONG-TERM DEBT: | |||||||
Bank debt | – | 22,900,000 | |||||
OTHER NONCURRENT LIABILITIES: | |||||||
Asset retirement obligations | 8,720,498 | 12,487,770 | |||||
Deferred taxes | 6,797,166 | 14,773,306 | |||||
Restricted stock units | – | 71,569 | |||||
Other liabilities | 30,090 | 22,451 | |||||
Total other noncurrent liabilities | 15,547,754 | 27,355,096 | |||||
EQUITY: | |||||||
Preferred stock | 10,828,603 | 9,958,217 | |||||
Common stock, no par value (300 million shares authorized, 71,834,617 and 69,139,869 issued) | 141,858,946 | 137,469,772 | |||||
Accumulated other comprehensive income | – | 38,801 | |||||
Accumulated earnings (deficit) | (88,462,633 | ) | (76,410,404 | ) | |||
Total equity | 64,224,916 | 71,056,386 | |||||
TOTAL LIABILITIES AND EQUITY | $ | 119,621,453 | $ | 148,018,254 | |||
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