Bill Barrett Corporation Reports First Quarter 2016 Financial and Operating Results

DENVER, May 5, 2016 /PRNewswire/ -- Bill Barrett Corporation (the "Company") (NYSE: BBG) reports first quarter of 2016 financial and operating results, including these highlights:

• Production sales volumes of 1.4 MMBoe (65% oil), at the high-end of first quarter guidance range
• Capital expenditures of $46 million, 20% below the mid-point of the first quarter guidance range
• 2016 capital expenditures reduced to $90-$135 million from $100-$150 million as a result of lower well costs
• Reported discretionary cash flow of $0.50 per share and EBITDAX of $39 million
• Affirmed borrowing base at $335 million with no change to terms or conditions
• Exited the first quarter of 2016 with $106 million of cash and an undrawn credit facility
• Executed agreement to divest a portion of Uinta Basin assets for approximately $30 million

Chief Executive Officer and President Scot Woodall commented, "Our team continues to execute and we posted another solid quarter of operational and financial results. The positive results were due in part to production coming in at the upper end of our guidance range, tightening oil differentials, and a 26% year-over-year decrease in per unit LOE. In addition, G&A expense declined 17% compared to the first quarter of 2015. We continue to maintain a capital disciplined approach as first quarter spending was 20% below the mid-point of our guidance range as we captured further XRL well cost savings. This gives us the confidence to lower our full-year 2016 capital expenditure guidance, while reaffirming our production guidance. The second quarter is off to a good start and we continue to be encouraged by the results of our XRL development program and the associated contribution to our increasing production profile this year. We are in the process of completing and placing on initial flowback the remainder of the wells that have been drilled. Our balance sheet remains strong as we ended the quarter with a cash position of $106 million, an undrawn credit facility, and a favorable hedge position which provides ample liquidity. The Uinta Basin non-core asset sale will further bolster our balance sheet by increasing our cash position."

OPERATING AND FINANCIAL RESULTS

Discretionary cash flow, adjusted net income (loss) and EBITDAX are non-GAAP (Generally Accepted Accounting Principles) measures. Please reference the reconciliations to GAAP financial statements at the end of this release.

Discretionary cash flow in the first quarter of 2016 was $24.4 million, or $0.50 per share, compared to $48.1 million, or $1.00 per share, in the first quarter of 2015. Discretionary cash flow in the first quarter of 2016 compared to 2015 was impacted by lower revenues due to a 14% decline in production volumes as a result of asset sales and a 17% decline in realized oil prices including hedges.

Adjusted net loss for the first quarter of 2016 was $13.7 million, or $0.28 per share, compared with adjusted net loss for the first quarter of 2015 of $5.9 million, or $0.12 per share. Adjusted net income (loss) removes the effect of unrealized derivative gains and losses and non-recurring charges such as impairment expenses, property sales and certain one-time items.

EBITDAX was $39.4 million for the first quarter of 2016 compared to $63.2 million for the first quarter of 2015. Lower EBITDAX is primarily a result of lower commodity prices and a decline in production volumes as a result of asset sales, as discussed above.

Oil, natural gas and natural gas liquids ("NGL") production from the Denver-Julesburg ("DJ") Basin and Uinta Oil Program ("UOP") totaled 1.4 million barrels of oil equivalent ("MMBoe") in the first quarter of 2016, which was at the high-end of the Company's guidance range of 1.3-1.4 MMBoe. Lower production sales volumes to the comparable 2015 period were primarily the result of non-core asset sales in the DJ Basin and UOP that were completed during 2015.

First quarter of 2016 production was 65% oil, 20% natural gas and 15% NGLs, which was consistent with guidance.

Cash operating costs (lease operating expense ("LOE"), gathering, transportation and processing costs and production tax expense) were $6.81 per Boe in the first quarter of 2016 compared to $6.54 per Boe in the fourth quarter of 2015 and $10.92 per Boe in the first quarter of 2015. Higher cash operating costs on a per unit basis compared to the fourth quarter of 2015 were primarily a result of lower production sales volumes due to asset sales and higher seasonal operating costs during the first quarter of 2016. Cash operating costs were lower compared to the first quarter of 2015 primarily as a result of improved operational efficiencies and lease operating cost reductions in both the DJ Basin and the UOP.

The decrease in production tax expense in the first quarter of 2016 is related to an annual adjustment of Colorado ad valorem tax based on actual assessments and of the related Colorado severance tax credit adjustment based on the annual severance tax calculation. Normalized production taxes are expected to approximate 9% of pre-hedge revenue for the remainder of 2016.

Uinta Basin Asset Sale

The Company announced on May 2, 2016, that it entered into an agreement with an unaffiliated third party to sell certain non-core assets located in the UOP for cash proceeds of approximately $30 million. The transaction is expected to close on or before June 30, 2016, and is subject to customary closing conditions. The assets produced approximately 1,000 Boe/d (63% oil) during the first quarter of 2016 and had estimated proved reserves of 2 MMBoe (87% proved developed) as of December 31, 2015. Based on the Company's internal estimates, the expected 2016 operating cash flow from the divested properties will be less than $2 million based on current strip pricing.

Debt and Liquidity

At March 31, 2016, the principal balance of long-term debt was $803.2 million and cash and cash equivalents were $105.6 million, resulting in net debt (principal balance of debt outstanding less the cash and cash equivalents balance) of $697.6 million.

The Company's semi-annual borrowing base review was completed in April 2016 with the bank group setting a borrowing base of $335 million, an 11% reduction from the previous borrowing base of $375 million. There were no changes to the terms or conditions of the credit facility and there are no borrowings outstanding. The revolving credit facility has $309 million in available capacity, after taking into account a $26 million letter of credit.

The next regularly scheduled borrowing base redetermination will occur on or about October 1, 2016.

Capital Expenditures

The Company exhibited continued capital discipline during the first quarter of 2016 as capital expenditures ("capex") totaled $45.8 million, which was 20% below the mid-point of the Company's guidance range of $55-$60 million. This was primarily due to recent XRL well costs being executed below forecast drilling and completion cost of $4.75 million.

Capex projects included spudding 4 XRL wells in the DJ Basin and completing 16 wells, including 15 XRL wells, which began initial flowback operations during the quarter. Capex included $42.4 million for drilling, $0.8 million for leaseholds, and $2.6 million for infrastructure and corporate assets. The Company did not spud any new wells in the UOP.

OPERATIONAL HIGHLIGHTS

DJ Basin

• Produced an average of 11,670 Boe/d, an increase of 15% from the first quarter of 2015, excluding production associated with non-core asset sales completed during 2015.
• The oil price differential averaged $5.61 per barrel less than WTI, a decrease from the fourth quarter of 2015 of $6.42 per barrel and a decrease from the first quarter of 2015 of $9.99 per barrel.
• Spud 4 XRL wells and placed 16 wells, including 15 XRL wells, on initial flowback.
• Expect to place 8 XRL wells on initial flowback during the second quarter of 2016.
• The Company continues to be encouraged with the initial results of the development program and has a total of 34 wells, including 32 XRL wells that are currently in various stages of flowback operations. Activity to date has included utilizing several modified drilling and completion concepts to determine the optimal drilling and completion techniques.
• As previously announced, due to the uncertainty of an oil price recovery during 2016, the Company elected to curtail drilling activity to preserve capital and released the sole drilling rig that was operating during the first quarter. Industry conditions will continue to be monitored to determine the appropriate time to resume drilling.
• Drilling and completion costs for XRL wells are currently forecast to average approximately $4.75 million per well, although wells on the most recent multi-well pad were completed 10-15% below this level.
• Drilling days for the recent XRL wells have consistently averaged approximately 8 days per well from spud to rig release, including a best-in-class well drilled in 6.5 days.

Uinta Oil Program

Given the outlook for commodity prices and a focus on its core DJ Basin assets, the Company has significantly reduced activity in the UOP and did not drill or complete any wells during the first quarter of 2016. Operations continue to be focused on improving operational efficiencies, and associated cost reductions have been realized as a result of lower lease operating costs.

2016 OPERATING GUIDANCE

The Company is providing the following update to its 2016 operating guidance. In addition, the Company intends to update 2016 operating guidance upon closing of the UOP asset sale.  See "Forward-Looking Statements" below.

• Capital expenditures of $90-$135 million, reduced from $100-$150 million as a result of lower XRL well costs.
  • Second quarter capital expenditures are expected to total approximately $30-$35 million
• Production of 5.8-6.2 MMBoe, unchanged.
  • Second quarter production sales volumes are expected to approximate 1.4 MMBoe

COMMODITY HEDGES UPDATE

Generally, it is the Company's strategy to hedge 50%-70% of production on a forward 12-month to 18-month basis to reduce the risks associated with unpredictable future commodity prices to provide certainty for a portion of its cash flow and to support its capital expenditure program.

The following table summarizes hedge positions as of May 5, 2016:

Realized sales prices will reflect basis differentials from the index prices to the sales location.

UPCOMING EVENTS

First Quarter Conference Call and Webcast

The Company plans to host a conference call on Friday, May 6, 2016, to discuss the results and management's outlook for the future. The call is scheduled at 10:00 a.m. Eastern time (8:00 a.m. Mountain time). Please join the webcast conference call live or for replay via the Internet at www.billbarrettcorp.com, accessible from the home page. To join by telephone, call (855) 760-8152 ((631) 485-4979 international callers) with passcode 90845487. The webcast will remain on the Company's website for approximately 30 days and a replay of the call will be available through May 13, 2016 at (855) 859-2056 ((404) 537-3406 international) with passcode 90845487.

DISCLOSURE STATEMENTS

Forward-Looking Statements

All statements in this press release, other than statements of historical fact, may be deemed to be 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. Words such as expects, forecast, guidance, anticipates, intends, plans, believes, seeks, estimates and similar expressions or variations of such words are intended to identify forward-looking statements herein; however, these are not the exclusive means of identifying forward-looking statements. In particular, the Company is providing "2016 Operating Guidance," which contains projections for certain 2016 operational and financial metrics. Additional forward-looking statements in this release relate to, among other things, the closing of, and proceeds from the planned asset sale and future capital expenditures, projects and opportunities.

These and other forward-looking statements in this press release are based on management's judgment as of the date of this release and are subject to numerous risks and uncertainties. Actual results may vary significantly from those indicated in the forward-looking statements. Please refer to the Company's Annual Report on Form 10-K for the year ended December 31, 2015 filed with the SEC, and other filings, including our Current Reports on Form 8-K and Quarterly Reports on Form 10-Q, all of which are incorporated by reference herein, for further discussion of risk factors that may affect the forward-looking statements. The Company encourages you to consider the risks and uncertainties associated with projections and other forward-looking statements and to not place undue reliance on any such statements. In addition, the Company assumes no obligation to publicly revise or update any forward-looking statements based on future events or circumstances.

ABOUT BILL BARRETT CORPORATION

Bill Barrett Corporation (NYSE: BBG), headquartered in Denver, Colorado, develops oil and natural gas in the Rocky Mountain region of the United States. Additional information about the Company may be found on its website  www.billbarrettcorp.com.

Discretionary cash flow, adjusted net income (loss) and EBITDAX are non-GAAP measures. These measures are presented because management believes that they provide useful additional information to investors for analysis of the Company's ability to internally generate funds for exploration, development and acquisitions as well as adjusting net income (loss) for one-time or unusual items to allow for a more consistent comparison from period to period. In addition, the Company believes that these measures are widely used by professional research analysts and others in the valuation, comparison and investment recommendations of companies in the oil and gas exploration and production industry, and that many investors use the published research of industry research analysts in making investment decisions.

These measures should not be considered in isolation or as a substitute for net income, income from operations, net cash provided by operating activities or other income, profitability, cash flow or liquidity measures prepared in accordance with GAAP. Because discretionary cash flow, adjusted net income (loss) and EBITDAX exclude some, but not necessarily all, items that affect net income (loss) and may vary among companies, the amounts presented may not be comparable to similarly titled measures of other companies.

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