- First quarter production volumes averaged 17.6 MBoe per day
- Quarterly GAAP net loss of $1.91 per diluted share; adjusted net loss(1) of $0.00 per diluted share
- Quarterly GAAP cash provided by operating activities of $15.7 million; adjusted EBITDAX(1) of $26.3 million
- Expects to commence drilling and completion operations in the Wattenberg around June 1, 2017
(1) Non-GAAP measure, see attached Reconciliation Schedules.
DENVER, May 10, 2017 (GLOBE NEWSWIRE) -- Bonanza Creek Energy, Inc. BCEI (the "Company") today announces its first quarter 2017 financial and operating outlook.
First Quarter 2017 Results
For the first quarter of 2017, the Company reported average daily production of 17.6 MBoe per day, a 28% decrease from the first quarter of 2016, and a 4% sequential decrease from the fourth quarter of 2016. The reduction in production volumes is a result of having no drilling and completion activity during the previous four quarters. Product mix for the first quarter of 2017 was 52% oil, 22% NGLs, and 26% natural gas.
Net revenue for the first quarter of 2017 was $52.6 million, compared to $44.2 million for the first quarter of 2016. Crude oil accounted for approximately 76% of total revenue. Differentials for the Company's Rocky Mountain oil production during the quarter averaged approximately $4.47 per Bbl. Corporate average realized prices for the first quarter of 2017 are presented below.
| Average Realized Prices | |||
| Three Months Ended March 31, 2017 | |||
| Oil (per Bbl) | 48.59 | ||
| Gas (per Mcf) | 2.73 | ||
| NGL (per Bbl) | 17.01 | ||
| Boe (Per Boe) | 33.26 | ||
LOE for the first quarter of 2017 was $9.9 million, or $6.28 per Boe, compared to $13.3 million or $6.01 per Boe in the first quarter of 2016. Throughout 2016 and into 2017, the Company has executed on multiple cost saving initiatives, which have resulted in an absolute LOE reduction of 25%.
Below is a breakout of the Company's regional LOE and gas plant and midstream operating expense for the first quarter of 2017.
| Production Expense | |||||||||||||||||||||||
| Three Months Ended March 31, 2017 | |||||||||||||||||||||||
| Rocky Mountain | Mid-Continent | Total Company | |||||||||||||||||||||
| M | ($/Boe) | M | ($/Boe) | M | ($/Boe) | ||||||||||||||||||
| Lease operating expense | $ | 6,917 | $ | 5.47 | $ | 3,008 | $ | 9.56 | $ | 9,925 | $ | 6.28 | |||||||||||
| Gas plant and Midstream Operating Expense | $ | 1,281 | $ | 1.01 | $ | 1,424 | $ | 4.53 | 2,705 | $ | 1.71 | ||||||||||||
| Total | $ | 8,198 | $ | 6.48 | $ | 4,432 | $ | 14.09 | $ | 12,630 | $ | 7.99 | |||||||||||
The Company's general and administrative expense was $12.1 million for the first quarter of 2017, a 32% decrease from the first quarter of 2016. The decrease in expense from the prior year is due to a work-force reorganization in the first quarter of 2016 that resulted in reduced employee headcount.
As the Company emerged from Chapter 11 bankruptcy subsequent to the end of the quarter, Bonanza Creek's first quarter 2017 results will be the last full quarter of accounting reflecting the Company, pre-emergence. Fresh start accounting will begin on May 1, 2017 and will be reflected in the Company's second quarter results.
Operational Outlook
On April 28, 2017, the Company emerged from its Chapter 11 bankruptcy proceeding. As a part of the restructuring, the Company received $207.5 million in new capital from a rights offering and pursuant to a settlement agreement with certain equity holders. The new capital provided liquidity for the Company to resume its drilling and completion activities. The Company plans to commence drilling operations in June 2017. The Company also plans to begin completing four previously drilled, but uncompleted wells later this month. Upon approval of the 2017 capital program by the new Board of Directors, the Company will provide guidance for the remainder of 2017 and communicate additional details around its longer term development and strategy.
Regulatory Environment
As a result of a recent incident with a home explosion in Firestone, Colorado, the Colorado Oil and Gas Conservation Commission ("COGCC") issued additional regulations to document and inspect all flow lines and verify that all existing flow lines not in use are properly abandoned. In addition, flow lines within 1,000 feet of inhabited buildings must be pressure tested by the end of the second quarter of 2017. Due to the rural nature of the Company's acreage position, there are very few wells and flow lines that are proximate to inhabited structures. The Company's nearest well to an inhabited structure is approximately 400 feet and the Company has 44 wells within 1,000 feet of inhabited structures that would be affected by this new regulation. The Company confirmed that it has very few flow lines that have been abandoned and relocated on its acreage and does not have any subdivision development on or near any of its plugged and abandoned wells or flow lines. In addition, the Company annually tests its flow lines and successfully completed an audit of these results by the COGCC in 2016. The Company expects to meet or exceed all additional regulations to ensure the health and safety of the communities in which it operates.
Bonanza Creek has consistently been regarded as a best-in-class operator by the COGCC with regard to health and safety and was awarded an "outstanding operations" award by the Commission in both 2015 and 2016.
About Bonanza Creek Energy, Inc.
Bonanza Creek Energy, Inc. is an independent oil and natural gas company engaged in the acquisition, exploration, development and production of onshore oil and associated liquids-rich natural gas in the United States. The Company's assets and operations are concentrated primarily in the Rocky Mountain region in the Wattenberg Field, focused on the Niobrara and Codell formations, and in southern Arkansas, focused on oily Cotton Valley sands. The Company's common shares are listed for trading on the NYSE under the symbol: "BCEI." For more information about the Company, please visit www.bonanzacrk.com. Please note that the Company routinely posts important information about the Company under the Investor Relations section of its website.
Forward-Looking Statements
This press release contains forward-looking statements within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. All statements, other than statements of historical facts, included in this press release that address activities, events or developments that the Company expects, believes or anticipates will or may occur in the future are forward-looking statements. These statements are based on certain assumptions made by the Company based on management's experience, perception of historical trends and technical analyses, current conditions, anticipated future developments and other factors believed to be appropriate and reasonable by management. When used in this press release, the words "will," "potential," "believe," "estimate," "intend," "expect," "may," "should," "anticipate," "could," "plan," "predict," "project," "profile," "model" or their negatives, other similar expressions or the statements that include those words, are intended to identify forward-looking statements, although not all forward-looking statements contain such identifying words. These statements include statements regarding development and completion expectations and strategy; decreasing operating and capital costs; impact of the Company's reorganization; and updated 2017 guidance. Such statements are subject to a number of assumptions, risks and uncertainties, many of which are beyond the control of the Company, that may cause actual results to differ materially from those implied or expressed by the forward-looking statements, including the following: changes in natural gas, oil and NGL prices; general economic conditions, including the performance of financial markets and interest rates; drilling results; shortages of oilfield equipment, services and personnel; operating risks such as unexpected drilling conditions; ability to acquire adequate supplies of water; risks related to derivative instruments; access to adequate gathering systems and pipeline take-away capacity; and pipeline and refining capacity constraints. Further information on such assumptions, risks and uncertainties is available in the Company's SEC filings. We refer you to the discussion of risk factors in our Annual Report on Form 10-K for the year ended December 31, 2016, filed on March 16, 2017, and other filings submitted by us to the Securities Exchange Commission. The Company's SEC filings are available on the Company's website at www.bonanzacrk.com and on the SEC's website at www.sec.gov. All of the forward-looking statements made in this press release are qualified by these cautionary statements. Any forward-looking statement speaks only as of the date on which such statement is made, including guidance, and the Company undertakes no obligation to correct or update any forward-looking statement, whether as a result of new information, future events or otherwise, except as required by applicable law.
Schedule 1: Statement of Operations
(in thousands, expect for per share amounts, unaudited)
| Three Months Ended March 31, | |||||||||||||||
| 2017 | 2016 | ||||||||||||||
| Operating net revenues: | |||||||||||||||
| Oil and gas sales | $ | 52,559 | $ | 44,174 | |||||||||||
| Operating expenses: | |||||||||||||||
| Lease operating expense | 9,925 | 13,298 | |||||||||||||
| Gas plan and midstream operating expense | 2,705 | 3,789 | |||||||||||||
| Severance and ad valorem taxes | 4,319 | 3,154 | |||||||||||||
| Exploration | 3,407 | 266 | |||||||||||||
| Depreciation, depletion and amortization | 21,212 | 26,379 | |||||||||||||
| Impairment of oil and gas properties | — | 10,000 | |||||||||||||
| Abandonment and impairment of unproved properties | — | 6,906 | |||||||||||||
| Unused commitments | 993 | — | |||||||||||||
| General and administrative (including $1,725 and $3,004, respectively, of stock-based compensation) | 12,094 | 17,685 | |||||||||||||
| Total operating expenses | 54,655 | 81,477 | |||||||||||||
| Loss from operations | (2,096 | ) | (37,303 | ) | |||||||||||
| Other income (expense): | |||||||||||||||
| Derivative loss | — | (1,007 | ) | ||||||||||||
| Interest expense | (4,568 | ) | (14,547 | ) | |||||||||||
| Reorganization items, net | (89,003 | ) | — | ||||||||||||
| Gain on termination fee | — | 6,000 | |||||||||||||
| Other income (loss) | 1,391 | (380 | ) | ||||||||||||
| Total other expense | (92,180 | ) | (9,934 | ) | |||||||||||
| Net Loss | $ | (94,276 | ) | $ | (47,237 | ) | |||||||||
| Basic net loss per common share | $ | (1.91 | ) | $ | (0.96 | ) | |||||||||
| Diluted net loss per common share | $ | (1.91 | ) | $ | (0.96 | ) | |||||||||
| Basic weighted-average common shares outstanding | 49,452 | 49,131 | |||||||||||||
| Diluted weighted-average common shares outstanding | 49,452 | 49,131 | |||||||||||||
| • The Company follows the two-class method when computing the basic and diluted loss per share, which allocates earnings between common shareholders and participating securities. Please refer to Note 10 – Earnings per Share in the Form 10-Q, for a detailed calculation. | |||||||||||||||
Schedule 2: Statement of Cash Flows
(in thousands, unaudited)
| Three Months Ended March 31, | |||||||||||||||
| 2017 | 2016 | ||||||||||||||
| Cash flows from operating activities: | |||||||||||||||
| Net loss | $ | (94,276 | ) | $ | (47,237 | ) | |||||||||
| Adjustments to reconcile net loss to net cash provided by operating activities: | |||||||||||||||
| Depreciation, depletion and amortization | 21,212 | 26,379 | |||||||||||||
| Non-cash reorganization items | 57,341 | — | |||||||||||||
| Impairment of oil and gas properties | — | 10,000 | |||||||||||||
| Abandonment and impairment of unproved properties | — | 6,906 | |||||||||||||
| Well abandonment costs and dry hole expense | 2,701 | 232 | |||||||||||||
| Stock-based compensation | 1,725 | 3,004 | |||||||||||||
| Amortization of deferred financing costs and debt premium | — | 608 | |||||||||||||
| Derivative loss | — | 1,007 | |||||||||||||
| Derivative cash settlements | — | 7,508 | |||||||||||||
| Other | 383 | (116 | ) | ||||||||||||
| Changes in current assets and liabilities: | |||||||||||||||
| Accounts receivable | (3,814 | ) | 23,044 | ||||||||||||
| Prepaid expenses and other assets | (536 | ) | (1,622 | ) | |||||||||||
| Accounts payable and accrued liabilities | 31,092 | (3,141 | ) | ||||||||||||
| Settlement of asset retirement obligations | (176 | ) | (41 | ) | |||||||||||
| Net cash provided by operating activities | 15,652 | 26,531 | |||||||||||||
| Cash flows from investing activities: | |||||||||||||||
| Acquisition of oil and gas properties | (439 | ) | (532 | ) | |||||||||||
| Exploration and development of oil and gas properties | (3,425 | ) | (34,872 | ) | |||||||||||
| (Increase) decrease in restricted cash | 118 | (2,533 | ) | ||||||||||||
| (Additions) deletions to property and equipment - non oil and gas | (201 | ) | 47 | ||||||||||||
| Net cash used in investing activities | (3,947 | ) | (37,890 | ) | |||||||||||
| Cash flows from financing activities: | |||||||||||||||
| Proceeds from credit facility | — | 209,000 | |||||||||||||
| Payment of employee tax withholdings in exchange for the return of common stock | (335 | ) | (229 | ) | |||||||||||
| Deferred financing costs | — | (154 | ) | ||||||||||||
| Net cash (used in) provided by financing activities | (335 | ) | 208,617 | ||||||||||||
| Net change in cash and cash equivalents | 11,370 | 197,258 | |||||||||||||
| Cash and cash equivalents: | |||||||||||||||
| Beginning of period | 80,565 | 21,341 | |||||||||||||
| End of period | $ | 91,935 | $ | 218,599 | |||||||||||
Schedule 3: Condensed Balance Sheet
(in thousands, unaudited)
| March 31, | December 31, | ||||||||||
| 2017 | 2016 | ||||||||||
| ASSETS | |||||||||||
| Current assets | $ | 127,513 | $ | 112,428 | |||||||
| Total property and equipment, net | 1,004,915 | 1,018,968 | |||||||||
| Other noncurrent assets | 2,737 | 3,082 | |||||||||
| Total Assets | $ | 1,135,165 | $ | 1,134,478 | |||||||
| LIABILITIES AND STOCKHOLDERS' EQUITY | |||||||||||
| Current liabilities | 287,566 | 1,070,466 | |||||||||
| Liabilities subject to compromise | 873,292 | — | |||||||||
| Other long-term liabilities | 48,132 | 44,951 | |||||||||
| Total Liabilities | 1,208,990 | 1,115,417 | |||||||||
| Stockholders' Equity (Deficit) | (73,825 | ) | 19,061 | ||||||||
| Total Liabilities and Stockholders' Equity | $ | 1,135,165 | $ | 1,134,478 | |||||||
Schedule 4: Volumes and Realized Prices (Before and After the Effect of Commodity Hedges)
(unaudited)
| Three Months Ended March 31, | |||||||||||||||
| 2017 | 2016 | ||||||||||||||
| Wellhead Volumes and Prices | |||||||||||||||
| Crude Oil and Condensate Sales Volumes (Bbl/d) | |||||||||||||||
| Rocky Mountains | 7,197 | 11,665 | |||||||||||||
| Mid-Continent | 1,934 | 2,437 | |||||||||||||
| Total | 9,131 | 14,102 | |||||||||||||
| Crude Oil and Condensate Realized Prices ($/Bbl) | |||||||||||||||
| Rocky Mountains | $ | 47.80 | $ | 25.15 | |||||||||||
| Mid-Continent | $ | 51.55 | $ | 35.95 | |||||||||||
| Composite | $ | 48.59 | $ | 27.02 | |||||||||||
| Natural Gas Liquids Sales Volumes (Bbl/d) | |||||||||||||||
| Rocky Mountains | 3,290 | 3,416 | |||||||||||||
| Mid-Continent | 490 | 720 | |||||||||||||
| Total | 3,780 | 4,136 | |||||||||||||
| Natural Gas Liquids Realized Prices ($/Bbl) | |||||||||||||||
| Rocky Mountains | $ | 15.72 | $ | 13.12 | |||||||||||
| Mid-Continent | $ | 25.65 | $ | 12.33 | |||||||||||
| Composite | $ | 17.01 | $ | 12.98 | |||||||||||
| Natural Gas Sales Volumes (Mcf/d) | |||||||||||||||
| Rocky Mountains | 21,435 | 28,638 | |||||||||||||
| Mid-Continent | 6,433 | 7,853 | |||||||||||||
| Total | 27,868 | 36,491 | |||||||||||||
| Natural Gas Realized Prices ($/Mcf) | |||||||||||||||
| Rocky Mountains | $ | 2.57 | $ | 1.20 | |||||||||||
| Mid-Continent | $ | 3.24 | $ | 2.09 | |||||||||||
| Composite | $ | 2.73 | $ | 1.39 | |||||||||||
| Crude Oil Equivalent Sales Volumes (Boe/d) | |||||||||||||||
| Rocky Mountains | 14,060 | 19,854 | |||||||||||||
| Mid-Continent | 3,496 | 4,466 | |||||||||||||
| Total | 17,556 | 24,320 | |||||||||||||
| Crude Oil Equivalent Sales Prices ($/Boe) | |||||||||||||||
| Rocky Mountains | $ | 32.07 | $ | 18.77 | |||||||||||
| Mid-Continent | $ | 38.07 | $ | 25.27 | |||||||||||
| Composite | $ | 33.26 | $ | 19.96 | |||||||||||
| Total Sales Volumes (MBoe) | 1,580,011 | 2,213,109 | |||||||||||||
Schedule 5: Per unit operating margins
(unaudited)
| Three Months Ended March 31, | |||||||||||||||||||||||||
| 2017 | 2016 | Percent Change | |||||||||||||||||||||||
| Production | |||||||||||||||||||||||||
| Oil (MBbl) | 822 | 1,283 | (36 | )% | |||||||||||||||||||||
| Gas (MMcf) | 2,508 | 3,321 | (24 | )% | |||||||||||||||||||||
| NGL (MBbl) | 340 | 376 | (10 | )% | |||||||||||||||||||||
| Equivalent (MBoe) | 1,580 | 2,213 | (29 | )% | |||||||||||||||||||||
| Realized pricing (before derivatives) | |||||||||||||||||||||||||
| Oil ($/Bbl) | $ | 48.59 | $ | 27.02 | 80 | % | |||||||||||||||||||
| Gas ($/Mcf) | $ | 2.73 | $ | 1.39 | 96 | % | |||||||||||||||||||
| NGL ($/Bbl) | $ | 17.01 | $ | 12.98 | 31 | % | |||||||||||||||||||
| Equivalent ($/Boe) | $ | 33.26 | $ | 19.96 | 67 | % | |||||||||||||||||||
| Per Unit Costs ($/Boe) | |||||||||||||||||||||||||
| Realized price (before derivatives) | $ | 33.26 | $ | 19.96 | 67 | % | |||||||||||||||||||
| Lease operating expense | 6.28 | 6.01 | 4 | % | |||||||||||||||||||||
| Gas plant and midstream operating expense | 1.71 | 1.71 | — | % | |||||||||||||||||||||
| Severance and ad valorem | 2.73 | 1.43 | 91 | % | |||||||||||||||||||||
| Cash general and administrative | 6.56 | 6.63 | (1 | )% | |||||||||||||||||||||
| Total cash operating costs | $ | 17.28 | $ | 15.78 | 10 | % | |||||||||||||||||||
| Cash operating margin (before derivatives) | $ | 15.98 | $ | 4.18 | 282 | % | |||||||||||||||||||
| Derivative cash settlements | — | 3.39 | (100 | )% | |||||||||||||||||||||
| Cash operating margin (after derivatives) | $ | 15.98 | $ | 7.57 | 111 | % | |||||||||||||||||||
| Non-cash items | |||||||||||||||||||||||||
| Depreciation, depletion and amortization | $ | 13.43 | $ | 11.92 | 13 | % | |||||||||||||||||||
| Non-cash general and administrative | $ | 1.09 | $ | 1.36 | (20 | )% | |||||||||||||||||||
Schedule 6: Adjusted Net Loss
(in thousands, except per share amounts, unaudited)
Adjusted net loss is a supplemental non-GAAP financial measure that is used by management and external users of the Company's consolidated financial statements, such as industry analysts, investors, lenders and rating agencies. The Company defines adjusted net loss as net loss after adjusting first for (1) the impact of certain non-cash items, including unrealized gains and losses on unsettled derivative instruments, impairment of oil and gas properties, other similar non-cash charges and one-time transactions and then (2) the non-cash and one time items' impact on taxes based on a tax rate that approximates the Company's effective tax rate in each period. Adjusted net loss is not a measure of net income as determined by GAAP.
The following table presents a reconciliation of the GAAP financial measure of net loss to the non-GAAP financial measure of adjusted net loss.
| Three Months Ended March 31, | ||||||||||||||||||||||||
| 2017 | 2016 | |||||||||||||||||||||||
| Net loss | $ | (94,276 | ) | $ | (47,237 | ) | ||||||||||||||||||
| Adjustments to net loss: | ||||||||||||||||||||||||
| Derivative loss | — | 1,007 | ||||||||||||||||||||||
| Derivative cash settlements | — | 7,508 | ||||||||||||||||||||||
| Impairment of oil and gas properties | — | 10,000 | ||||||||||||||||||||||
| Abandonment and impairment of unproved properties | — | 6,906 | ||||||||||||||||||||||
| Well abandonment costs and dry hole expense | 2,701 | 232 | ||||||||||||||||||||||
| Gain on termination fee | — | (6,000 | ) | |||||||||||||||||||||
| Stock-based compensation | 1,725 | 3,004 | ||||||||||||||||||||||
| Cash severance costs (1) | — | 2,162 | ||||||||||||||||||||||
| Pre-petition advisor fees (1) | 683 | — | ||||||||||||||||||||||
| Reorganization items, net | 89,003 | — | ||||||||||||||||||||||
| Total adjustments before taxes | 94,112 | 24,819 | ||||||||||||||||||||||
| Income tax effect | — | — | ||||||||||||||||||||||
| Total adjustments after taxes | $ | 94,112 | $ | 24,819 | ||||||||||||||||||||
| Adjusted net loss | $ | (164 | ) | $ | (22,418 | ) | ||||||||||||||||||
| Adjusted net loss per diluted share | $ | — | $ | (0.46 | ) | |||||||||||||||||||
| Diluted weighted-average common shares outstanding | 49,452 | 49,131 | ||||||||||||||||||||||
| (1) Included as a portion of general and administrative expense on the consolidated statement of operations. | ||||||||||||||||||||||||
Schedule 7: Adjusted EBITDAX
(in thousands, unaudited)
Adjusted EBITDAX is a supplemental non-GAAP financial measure that is used by management and external users of the Company's consolidated financial statements, such as industry analysts, investors, lenders and rating agencies. The Company defines Adjusted EBITDAX as earnings before interest expense, income taxes, depreciation, depletion, amortization, impairment, exploration expenses and other similar non-cash and non-recurring charges. Adjusted EBITDAX is not a measure of net income or cash flows as determined by GAAP.
The following table presents a reconciliation of the GAAP financial measure of net loss to the non-GAAP financial measure of Adjusted EBITDAX.
| Three Months Ended March 31, | ||||||||||||||||||||||||
| 2017 | 2016 | |||||||||||||||||||||||
| Net Loss | $ | (94,276 | ) | $ | (47,237 | ) | ||||||||||||||||||
| Exploration | 3,407 | 266 | ||||||||||||||||||||||
| Depreciation, depletion and amortization | 21,212 | 26,379 | ||||||||||||||||||||||
| Impairment of oil and gas properties | — | 10,000 | ||||||||||||||||||||||
| Abandonment and impairment of unproved properties | — | 6,906 | ||||||||||||||||||||||
| Stock-based compensation | 1,725 | 3,004 | ||||||||||||||||||||||
| Cash severance costs (1) | — | 2,162 | ||||||||||||||||||||||
| Gain on termination fee | — | (6,000 | ) | |||||||||||||||||||||
| Interest expense | 4,568 | 14,547 | ||||||||||||||||||||||
| Derivative loss | — | 1,007 | ||||||||||||||||||||||
| Derivative cash settlements | — | 7,508 | ||||||||||||||||||||||
| Pre-petition advisory fees (1) | 683 | — | ||||||||||||||||||||||
| Reorganization items, net | 89,003 | — | ||||||||||||||||||||||
| Income tax benefit (expense) | — | — | ||||||||||||||||||||||
| Adjusted EBITDAX | $ | 26,322 | $ | 18,542 | ||||||||||||||||||||
| (1) Included as a portion of general and administrative expense on the consolidated statement of operations. | ||||||||||||||||||||||||
For further information, please contact: James R. Edwards Director - Investor Relations 720-440-6136 jedwards@bonanzacrk.com
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