Forest Oil Announces First Quarter 2013 Results

Forest Oil Announces First Quarter 2013 Results

First Quarter 2013 Average Net Sales Volumes of 243 MMcfe/d; 34% Liquids Compared to 32% Liquids in First Quarter 2012

First Quarter 2013 Average Net Sales Volumes of 214 MMcfe/d (37% Liquids) Pro Forma for South Texas Divestiture

First Quarter 2013 Average Net Oil Sales Volumes of 5.8 MBbls/d Pro Forma for Divestitures; Organically Increased 9% Compared to the First Quarter 2012

Executed on Strategic Goal of Accelerating Production Growth with Eagle Ford Shale Development Agreement

Eagle Ford Shale Gross Production in April Reached a Record High of 4,700 Boe/d

DENVER--(BUSINESS WIRE)-- Forest Oil Corporation (NYS: FST) (Forest or the Company) today announced financial and operational results for the first quarter of 2013.

Forest noted the following results for the three months ended March 31, 2013:

• Average net sales volumes of 243 MMcfe/d; 34% liquids compared to 32% liquids in the first quarter of 2012

• Average net oil sales volumes of 5.8 MBbls/d organically increased 9% from the first quarter of 2012 on a pro forma basis

• Adjusted net earnings of $3 million compared to $13 million in the corresponding 2012 period

• Adjusted EBITDA of $94 million compared to $126 million in the corresponding 2012 period

• Adjusted discretionary cash flow of $56 million compared to $95 million in the corresponding 2012 period

Due primarily to unrealized losses on derivatives of $38 million, a loss on debt extinguishment of $25 million and severance-related costs of $7 million, Forest reported a net loss of $68 million, or $(0.59) per share, for the three months ended March 31, 2013.

Patrick R. McDonald, President and CEO, stated, "We made progress during the first quarter in achieving our strategic goal of accelerating the development of our oil inventory by announcing an Eagle Ford Shale development agreement. This is an important transaction for our shareholders and our company as we believe it will accelerate development and production growth, bring forward significant economic value and generate notably more lease level income compared to our previous plan. Establishing a partnership with an industry leading service and technology company should allow us to optimize all facets of our drilling and completion operations, so that we can deliver the best possible results from this important oil asset. We also believe we are carrying momentum into this partnership, as our gross production from the Eagle Ford Shale in April reached a record high of 4,700 Boe/d.

"We see significant opportunities and attractive rates of return within the oil bearing zones of the Texas Panhandle Area in both Texas and Oklahoma. We currently have an inventory of over 500 identified locations within the Hogshooter, Tonkawa, Douglas and other proven oil horizons. The Texas Panhandle will remain an area of emphasis for Forest as we expect to maintain a two rig development program throughout 2013 to capture the significant value in this core asset. Additionally, we remain encouraged by the consistent drilling results within our East Texas oil and liquids-rich properties and plan to continue our efforts to develop these assets this year."

FIRST QUARTER 2013 RESULTS

For the three months ended March 31, 2013, Forest reported a net loss of $68 million, or $(0.59) per diluted share. This compares to Forest's net loss of $33 million, or $(0.29) per diluted share, in the corresponding 2012 period. Net loss for the first quarter of 2013 was affected by the following items:

• Unrealized losses on derivative instruments of $38 million ($24 million net of tax)

• Change in valuation allowance on deferred tax assets associated with net loss and adjusting items of $25 million ($25 million net of tax)

• Loss on debt extinguishment of $25 million ($16 million net of tax)

• Severance and stock-based compensation acceleration of $7 million ($4 million net of tax)

• Rig stacking costs of $3 million ($2 million net of tax)

Without the effect of these items, Forest's adjusted net earnings and earnings per share on a diluted basis for the three months ended March 31, 2013 would have been $3 million, or $0.03 per diluted share, compared to $13 million, or $0.11 per diluted share, in the corresponding 2012 period. Forest's adjusted EBITDA for the three months ended March 31, 2013 was $94 million compared to $126 million in the corresponding 2012 period. Forest's adjusted discretionary cash flow for the three months ended March 31, 2013 was $56 million compared to $95 million in the corresponding 2012 period.

Average Net Sales Volumes, Average Realized Prices, and Revenues

Forest's average net sales volumes for the three months ended March 31, 2013 were 243 MMcfe/d, a decrease of 28% and 21% from the corresponding 2012 period and from the fourth quarter of 2012, respectively. First quarter 2013 average net sales volumes were lower as a result of the South Louisiana property sale that closed on November 16, 2012, the South Texas property sale that closed on February 15, 2013, and a decline in natural gas volumes as the Company has deferred capital investment on its natural gas properties to focus on higher-margin oil opportunities. Net sales volumes were also negatively impacted by downtime associated with severe winter weather that hindered operations in both the Texas Panhandle and East Texas areas during the quarter. The following table details the components of average net sales volumes, average realized prices, and revenues for the three months ended March 31, 2013:

Forest's average net sales volumes for the first quarter of 2013 excluding production associated with divested properties in South Texas were 214 MMcfe/d (63% natural gas, 16% oil, 21% NGLs). Pro forma oil volumes of 5.8 MBbls/d organically increased 9% as compared to the first quarter of 2012.

Total Cash Costs

Forest's total cash costs for the first quarter of 2013 decreased 10% to $79 million, compared to $88 million in the corresponding 2012 period. Total cash costs per-unit for the first quarter of 2013 increased 26% to $3.61 per Mcfe, compared to $2.86 per Mcfe in the corresponding 2012 period.

Total cash costs per-unit for the first quarter of 2013 increased primarily due to increased general and administrative expense (excluding stock-based compensation) and interest expense, which in turn was spread over decreased sales volumes due to asset sales. General and administrative expense (excluding stock-based compensation) for the first quarter of 2013 includes one-time severance-related expense associated with the South Texas properties disposition of $6 million.

The following table details the components of total cash costs for the comparative periods:

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Total cash costs is a non-GAAP measure that is used by management to assess the Company's cash operating performance.Forest defines total cash costs as all cash operating costs, including production expense; general and administrative expense (excluding stock-based compensation); interest expense; and current income tax expense.

Depreciation and Depletion Expense

Forest's per-unit depreciation and depletion expense for the three months ended March 31, 2013 increased 2% to $2.22 per Mcfe compared to $2.18 per Mcfe in the corresponding 2012 period.

Total Capital Expenditures

Forest's exploration and development capital expenditures for the three months ended March 31, 2013 were $125 million, compared to $181 million in the corresponding 2012 period.

Forest's land and leasehold acquisition costs for the three months ended March 31, 2013 were $3 million, compared to $45 million in the corresponding 2012 period.

The following table summarizes total capital expenditures for the comparative periods (in thousands):

Second Quarter 2013 Guidance

Incorporating the projected impact of the recently announced Eagle Ford Shale development agreement, equivalent net sales volumes for the second quarter of 2013 are expected to be at approximately the same level as they were in the first quarter of 2013 on a pro forma basis. In addition, Forest's drilling activity is expected to increase during 2013 as the Eagle Ford Shale development program is expanded; however, net capital expenditures are forecasted to be significantly lower than the first quarter as the benefit of the drilling carry associated with the Eagle Ford Shale development agreement is realized into 2014. As such, second quarter net capital expenditures are expected to be between $70 million and $80 million and Forest anticipates maintaining this level of spending per quarter for the second half of 2013.

Except as indicated above as it relates to the second quarter of 2013, Forest reaffirms its full year 2013 guidance as detailed in the Company's press release dated February 20, 2013.

The Company's production and capital budget guidance remains subject to the cautionary statements and limitations contained in Forest's February 20, 2013 press release under the caption "2013 Guidance" as well as those stated below under the caption "Forward-Looking Statements."

OPERATIONAL PROJECT UPDATE

Eagle Ford Shale

Forest recently announced an Eagle Ford Shale development agreement with an industry partner that should meaningfully increase the play's growth profile, accelerate approximately $250 million of PV10 value and generate $75 million more in lease level income in 2014 as compared to the previous development plan. Forest maintains a large inventory of future drilling opportunities in the Eagle Ford Shale with 688 gross locations (344 net) identified based on 80-acre spacing and over 100 million barrels of unrisked resource potential on a net basis. In addition, net sales volumes from the Eagle Ford Shale are expected to increase to over 6,500 boe/d in 2014 from an average of 1,600 boe/d in 2012.

Net sales volumes from the Eagle Ford Shale averaged 1,900 Boe/d in the first quarter of 2013, which compares to fourth quarter of 2012 volumes of 2,300 Boe/d. The anticipated decline in first quarter sales volumes was a result of initiating multi-well pad drilling during the fourth quarter of 2012. Due to the timeline and sequence of drilling and completion operations associated with the pad drilling, the six gross (three net) wells drilled during the first quarter were brought online at various times during April. As such, the wells do not have sufficient production history to report a 30-day average initial production rate at this time. However, the six wells did have an average 24-hour maximum production rate of 634 Boe/d. In addition, Forest's total average gross sales volumes from the Eagle Ford Shale during April reached a record high of 4,700 Boe/d (2,640 Boe/d net).

Forest is currently moving a third drilling rig into the Eagle Ford Shale and is expected to increase to four drilling rigs by the end of the third quarter of 2013.

Texas Panhandle Area

Forest has an inventory of over 500 identified locations within the Hogshooter, Tonkawa, Douglas, and other proven oil intervals. The current focus of the Hogshooter drilling program is in Wheeler County, Texas, where Forest has identified over 100 potential development opportunities. Highlighting drilling activity since the last earnings release, two Missourian Wash (Hogshooter) wells were completed that had a 30-day average gross production rate of 1,800 Boe/d (80% oil).

Forest continues to operate two drilling rigs in the Texas Panhandle Area targeting oil horizons and expects to maintain this level of activity during 2013.

East Texas

Forest remains active in East Texas targeting higher-margin oil and liquids-rich development opportunities within the Cotton Valley and other prospective zones. Since the last earnings release, one horizontal Cotton Valley well was completed with a 30-day average gross production rate of 6 MMcfe/d (40% liquids or 400 Bbls/d).

The Company plans to continue a one-rig program targeting the liquids-rich Cotton Valley and other prospective zones in 2013.

NATURAL GAS AND OIL DERIVATIVES

As of May 6, 2013, Forest had natural gas and oil derivatives in place for the remainder of 2013 and through 2014 covering the aggregate average daily volumes and weighted average prices shown below:

In connection with several swaps shown in the table above, Forest granted swaption instruments to counterparties in exchange for Forest's receiving premium hedged prices on the swaps. The table below sets forth the outstanding swaptions as of May 6, 2013:

NON-GAAP FINANCIAL MEASURES

Adjusted Net Earnings

In addition to reporting net loss as defined under generally accepted accounting principles (GAAP), Forest also presents adjusted net earnings (adjusted net earnings), which is a non-GAAP performance measure. Adjusted net earnings consist of net loss after adjustment for those items shown in the table below. Adjusted net earnings does not represent, and should not be considered an alternative to, GAAP measurements such as net loss (its most comparable GAAP financial measure), and Forest's calculations thereof may not be comparable to similarly titled measures reported by other companies. By eliminating the items shown below, Forest believes that the measure is useful to investors because similar measures are frequently used by securities analysts, investors, and other interested parties in their evaluation of companies in the oil and gas industry. Forest's management does not view adjusted net earnings in isolation and also uses other measurements, such as net loss and revenues to measure operating performance. The following table provides a reconciliation of net loss, the most directly comparable GAAP measure, to adjusted net earnings for the periods presented (in thousands):

Adjusted EBITDA

In addition to reporting net loss as defined under GAAP, Forest also presents adjusted net earnings before interest, income taxes, depreciation, depletion, and amortization (adjusted EBITDA), which is a non-GAAP performance measure. Adjusted EBITDA consists of net loss after adjustment for those items shown in the table below. Adjusted EBITDA does not represent, and should not be considered an alternative to, GAAP measurements such as net loss (its most comparable GAAP financial measure), and Forest's calculations thereof may not be comparable to similarly titled measures reported by other companies. By eliminating the items shown below, Forest believes the measure is useful in evaluating its fundamental core operating performance. Forest also believes that adjusted EBITDA is useful to investors because similar measures are frequently used by securities analysts, investors, and other interested parties in their evaluation of companies in the oil and gas industry. Forest's management uses adjusted EBITDA to manage its business, including in preparing its annual operating budget and financial projections. Forest's management does not view adjusted EBITDA in isolation and also uses other measurements, such as net loss and revenues to measure operating performance. The following table provides a reconciliation of net loss, the most directly comparable GAAP measure, to adjusted EBITDA for the periods presented (in thousands):

Adjusted Discretionary Cash Flow

In addition to reporting net cash provided by operating activities as defined under GAAP, Forest also presents adjusted discretionary cash flow (adjusted discretionary cash flow), which is a non-GAAP liquidity measure. Adjusted discretionary cash flow consists of net cash provided by operating activities after adjustment for those items shown in the table below. This measure does not represent, and should not be considered an alternative to, GAAP measurements such as net cash provided by operating activities (its most comparable GAAP financial measure), and Forest's calculations thereof may not be comparable to similarly titled measures reported by other companies. Forest's management uses adjusted discretionary cash flow as a measure of liquidity and believes it provides useful information to investors because it assesses cash flow from operations before changes in operating assets and liabilities, which fluctuate due to the timing of collections of receivables and the settlements of liabilities, and other items. Forest's management uses adjusted discretionary cash flow to manage its business, including in preparing its annual operating budget and financial projections. This measure does not represent the residual cash flow available for discretionary expenditures. Fo