Forest Oil Announces Fourth Quarter and Year-End 2012 Results
Fourth Quarter 2012 Average Net Sales Volumes of 309 MMcfe/d; 35% Liquids Compared to 30% Liquids in Fourth Quarter 2011
Fourth Quarter 2012 Average Oil Net Sales Volumes of 8.7 MBbls/d; 47% Increase Compared to Fourth Quarter 2011 Pro Forma for Divestitures
Fourth Quarter 2012 Average Liquids Net Sales Volumes of 17.9 MBbls/d; 21% Increase Compared to Fourth Quarter 2011 Pro Forma for Divestitures
2012 Average Equivalent Net Sales Volumes Increase 6% Compared to 2011 Pro Forma for Divestitures
2012 Average Oil Net Sales Volumes Increase 67% Compared to 2011 Pro Forma for Divestitures
2012 Estimated Proved Reserves of 1,363 Bcfe; Oil Reserves Increase 27% Compared to 2011 Pro Forma for Divestitures
2012 Drill Bit Reserve Replacement of 194% with Finding and Development Costs of $2.76 per Mcfe
DENVER--(BUSINESS WIRE)-- Forest Oil Corporation (NYS: FST) (Forest or the Company) today announced financial and operational results for the fourth quarter and full-year 2012 and provided year-end estimated proved reserves. References to pro forma results excludes asset sales completed during 2012 and the South Texas divestiture that closed on February 15, 2013.
Forest noted the following results for the three months ended December 31, 2012:
Average net sales volumes of 309 MMcfe/d; at the mid-point of previously provided guidance
Average oil net sales volumes of 8.7 MBbls/d; pro forma increase of 47% from the fourth quarter of 2011
Average liquids net sales volumes of 17.9 MBbls/d; pro forma increase of 21% from the fourth quarter of 2011
Adjusted net earnings of $17 million compared to $20 million in the corresponding 2011 period
Adjusted EBITDA of $132 million compared to $139 million in the corresponding 2011 period
Adjusted discretionary cash flow of $93 million compared to $104 million in the corresponding 2011 period
Due primarily to a non-cash ceiling test write-down of $279 million and debt extinguishment costs of $36 million, Forest reported a net loss of $287 million, or $(2.48) per share, for the three months ended December 31, 2012.
Patrick R. McDonald, President and CEO, stated, "Forest has made measurable progress in executing a strategic realignment of operational and financial priorities. On a pro forma basis, fourth quarter oil volumes increased 47% compared to the fourth quarter of 2011, liquids made up approximately 35% of our equivalent volumes, and we expect continued oil and liquids growth in 2013. Our estimated oil reserves increased 27% during 2012 and comprise 15% of estimated proved reserves at year-end 2012 as compared with 9% at year-end 2011 pro forma for divestitures.
"Our 2012 divestiture program was successful and the recently completed sale of our South Texas properties brought total divestiture proceeds to approximately $600 million since announcing our deleveraging plan last July. The proceeds are being used to pay down debt, which has improved and restored flexibility to our balance sheet.
"Our 2013 capital budget is designed to be near projected cash flow and will allow us to maintain ample financial liquidity. Forest entered the year with five rigs deployed on oil and liquids prospects within our core development areas. The 2013 capital plan is anchored by investments in our Panhandle Area and Eagle Ford Shale assets, which form the foundation of our oil portfolio. We believe that our planned 2013 activity in these assets will provide an expected 30% growth in our pro forma oil volumes. This is expected to result in our second half 2013 equivalent volumes being higher than the first half of 2013. In addition, we have hedges in place for all of our 2013 natural gas production at approximately $4.00 per MMBtu, which protects cash flows and the capital plan.
"Our strategy for 2013 is well defined and the Company is focused on oil and liquids projects. We will concentrate on capturing the value that is embedded within our large asset base, while maintaining spending near projected cash flow. While considerable progress has been made in restoring operational and financial flexibility, our challenge will be to accelerate the development of our asset base in 2013."
FOURTH QUARTER 2012 RESULTS
For the three months ended December 31, 2012, Forest reported a net loss of $287 million, or $(2.48) per diluted share. This compares to Forest's net earnings of $19 million, or $0.17 per diluted share, in the corresponding 2011 period. The net loss in the fourth quarter of 2012 was affected by the following items:
The effect of a ceiling test write-down of $279 million ($178 million net of tax)
An increase in the valuation allowance on deferred tax assets of $104 million ($104 million net of tax)
Loss on debt extinguishment of $36 million ($23 million net of tax)
Unrealized gain on derivative instruments of $7 million ($5 million net of tax)
Rig stacking costs of $4 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 December 31, 2012 was $17 million, or $0.14 per diluted share, compared to $20 million, or $0.18 per diluted share, in the corresponding 2011 period. Forest's adjusted EBITDA for the three months ended December 31, 2012 was $132 million compared to $139 million in the corresponding 2011 period. Forest's adjusted discretionary cash flow for the three months ended December 31, 2012 was $93 million compared to $104 million in the corresponding 2011 period. The decrease in each of the above metrics was primarily due to lower natural gas sales volumes and revenues, which was partially offset by an increase in oil sales volumes.
Average Net Sales Volumes, Average Realized Prices, and Revenues
Forest's average net sales volumes for the three months ended December 31, 2012 decreased 10% and 9% from the corresponding 2011 period and from the third quarter of 2012, respectively. Fourth quarter 2012 net sales volumes were lower as a result of the South Louisiana property sale that closed on November 16, 2012, and a decline in natural gas volumes due to the Company's decision to defer capital investment on its natural gas properties until it sees a more robust commodity price environment. The following table details the components of average net sales volumes, average realized prices, and revenues for the three months ended December 31, 2012:
Three Months Ended December 31, 2012
Average Net Sales Volumes
Average Realized Prices
Average realized prices not including realized derivative gains
Realized gains on NYMEX derivatives
Average realized prices including realized derivative gains
Revenues (in thousands)
Revenues not including realized derivative gains
Realized gains on NYMEX derivatives
Revenues including realized derivative gains
Average Net Sales Volumes Excluding Asset Sales
Forest's 2012 average net sales volumes excluding production associated with asset sales completed during 2012 and the recently completed sale of properties in South Texas were 244 MMcfe/d, which is a 6% increase over 2011 pro forma average net sales volumes of 231 MMcfe/d. The following table provides a reconciliation of the Company's 2012 and 2011 average net sales volumes excluding asset divestitures:
Year Ended December 31,
Reported Average Net Sales Volumes
Average Net Sales Volumes Associated with Asset Divestitures*
Pro Forma Average Net Sales Volumes
* Includes South Texas asset sale that closed on February 15, 2013
Total Cash Costs
Forest's total cash costs for the fourth quarter of 2012 decreased 6% to $84 million, compared to $89 million in the corresponding 2011 period. Total cash costs per-unit for the fourth quarter of 2012 increased 4% to $2.95 per Mcfe, compared to $2.83 per Mcfe in the corresponding 2011 period.
The following table details the components of total cash costs for the comparative periods:
Three Months Ended December 31,
(In thousands, except per-unit amounts)
General and administrative expense (excluding
Current income tax expense
Total cash costs
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 December 31, 2012 increased 15% to $2.35 per Mcfe, compared to $2.05 per Mcfe in the corresponding 2011 period. The increase was primarily the result of higher finding and development costs associated with Forest's oil- and liquids-focused capital expenditure program.
Ceiling Test Write-Down
Forest recorded a non-cash ceiling test write-down of $279 million in the fourth quarter of 2012 pursuant to the ceiling test limitation prescribed by the Securities and Exchange Commission for companies using the full cost method of accounting. The write-down was primarily a result of decreases in the natural gas and natural gas liquids prices used in the ceiling test calculation in the fourth quarter of 2012 compared to the third quarter of 2012.
Loss on Debt Extinguishment
Forest redeemed $300.0 million of the 8½% Senior Notes due 2014 at 110.24% of par value in October 2012. This redemption resulted in a recognized loss of $36.3 million, comprised of a $30.7 million call premium and a write-off of $5.6 million of unamortized discount and debt issuance costs.
Total Capital Expenditures
Forest's exploration and development capital expenditures for the three months and year ended December 31, 2012 were $103 million and $648 million, respectively, compared to $178 million and $683 million in the corresponding 2011 periods. The decrease was primarily the result of the Company's decision in July of 2012 to adjust the capital spending rate to be more aligned with projected cash flow.
Forest's land and leasehold acquisition costs for the three months and year ended December 31, 2012 were $3 million and $64 million, respectively, compared to $22 million and $205 million in the corresponding 2011 periods.
The following table summarizes total capital expenditures for the comparative periods (in thousands):
Three Months Ended
Exploration and development
Land and leasehold acquisitions - Cash
Land and leasehold acquisitions - Stock
ARO, capitalized interest, and capitalized equity compensation
Total capital expenditures
ESTIMATED PROVED RESERVES
Forest reported December 31, 2012 estimated proved reserves of 1,363 Bcfe, which were 69% proved developed, compared to 1,904 Bcfe at December 31, 2011, which were 55% proved developed. The decrease in estimated proved reserves was a result of 604 Bcfe of revisions primarily related to significantly lower natural gas prices and 52 Bcfe of asset divestitures offset by extensions and discoveries of 235 Bcfe in our core areas. With continued focus on oil and liquids-rich drilling, extensions and discoveries were comprised of 60% oil and natural gas liquids and 40% natural gas. The amount of estimated proved reserves comprised of oil and natural gas liquids at year-end 2012 increased to 33% compared to 24% at year-end 2011. The pricing utilized for estimated proved reserves at December 31, 2012 was based on a 12-month average of the 2012 first-day-of-the-month Henry Hub price for natural gas and West Texas Intermediate price for oil of $2.76 per MMbtu and $94.79 per barrel, respectively. This compares to the pricing utilized for estimated proved reserves at December 31, 2011 for natural gas and oil of $4.12 per MMbtu and $96.08 per barrel, respectively. Forest's estimated proved reserves were audited by DeGolyer and MacNaughton (D&M), an independent third party engineering firm. D&M's audit covered properties representing over 83% of the value of Forest's total estimated proved reserves at year-end 2012.
The following table reflects the 2012 activity related to the estimated proved reserves and includes calculations of reserve replacement ratio and finding and development costs utilizing net sales volumes and capital expenditures:
December 31, 2011
Extensions and discoveries
Net sales volumes
Sales of properties
Other revisions (1)
December 31, 2012
Drill bit reserve replacement ratio excluding revisions (2)
Drill bit finding and development costs excluding revisions
EXPLANATION OF RESERVE REPLACEMENT RATIO AND FINDING AND DEVELOPMENT COSTS
The following discussion relates to Forest's reserve replacement ratios and finding and development costs in 2012:
Forest reclassified its natural gas reserves in Italy from proved to probable following an Italian regional regulatory body's denying approval of an environmental impact assessment needed in order for Forest to commence production.
The drill bit reserve replacement ratio excluding revisions of 194% was calculated by dividing extensions and discoveries of 235 Bcfe by net sales volumes of 121 Bcfe.
The drill bit finding and development costs, excluding revisions, of $2.76 per Mcfe was calculated by dividing the sum of exploration and development capital expenditures (excluding land and leasehold acquisitions, asset retirement obligations, capitalized interest, and capitalized equity compensation) of $648 million by extensions and discoveries of 235 Bcfe.
OPERATIONAL PROJECT UPDATE
Texas Panhandle Area
The Company is focused on drilling higher-margin oil opportunities, including the Missourian Wash (Hogshooter), Tonkawa, Douglas, and other intervals in the Texas Panhandle Area. In aggregate, seven zones have been identified for oil development. Forest is currently running two rigs in the Texas Panhandle Area and expects to maintain this level of activity during 2013.
Highlighting drilling activity since the last earnings release, the Company participated in drilling two Missourian Wash (Hogshooter) wells that had a 30-day average gross production rate of 1,840 Boe/d (68% oil). In addition, a third Missourian Wash (Hogshooter) well is currently in the process of being completed.
The Company has drilled eight Missourian Wash (Hogshooter) wells since initiating its drilling program in late-2011 that have had a 30-day average gross production rate of 1,820 Boe/d (67% oil) and a 90-day average gross production rate of 1,200 Boe/d (64% oil). The most productive well completed during 2012 began producing in January and had cumulative equivalent production of approximately 450,000 barrels of oil in its first year of sales.
Eagle Ford Shale
Drilling in the Eagle Ford continues to be focused in the central fairway of Forest's acreage position in Gonzales County, where the Company has experienced the most consistent performance within the drilling program. Forest currently plans to operate a one- to two-rig program during 2013 and believes that it can hold a core development position of approximately 40,000 net acres over the next several years.
The Company completed two Eagle Ford wells within the central fairway since the last earnings release that had a 30-day average gross production rate of 515 Boe/d (94% oil). In addition, Forest continues to make progress on lowering well costs and reached a notable milestone in the development of the Eagle Ford as one of the recent wells was drilled and completed for less than $6 million. The Company initiated a pad drilling program during the fourth quarter and is scheduled to complete the initial four-well pad during March of 2013.
The Company drilled fourteen wells in the central fairway of the Eagle Ford during 2012 that had a 30-day average gross production rate of 490 Boe/d (94% oil), and thirteen of the wells had a 90-day average gross production rate of 353 Boe/d (94% oil). The most productive well completed during 2012 began producing in July and had cumulative production of approximately 70,000 barrels of oil in its first 180 days.
The recent wells and the 2012 well program continue to meet Forest's type curve. The type curve projects an estimated ultimate recovery of 300 Mboe, with a pre-tax drilling rate of return of approximately 30% based on a $90 WTI-NYMEX oil price and a $6 million well cost.
Average net sales volumes from the Eagle Ford in the fourth quarter of 2012 increased 28% to 2,300 Boe/d as compared to third quarter 2012 volumes of 1,800 Boe/d. For 2012, net sales volumes averaged approximately 1,600 Boe/d, a 132% increase over 2011 net sales volumes.
Forest plans to continue a one- to two-rig program in the Eagle Ford and to drill approximately 20 wells during 2013.
The Company remains active in East Texas targeting higher-margin liquids opportunities within the Cotton Valley and other prospective zones. Since the last earnings release, two horizontal Cotton Valley wells (100% working interest) were completed with a 30-day average gross production rate of 9 MMcfe/d (37% liquids).
The Company drilled eight Cotton Valley wells during 2012 that had a 30-day average gross production rate of 7.9 MMcfe/d (38% liquids), and seven of the wells had a 90-day average gross production rate of 6.6 MMcfe/d (39% liquids).
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 February 20, 2013, Forest had natural gas and oil derivatives in place for 2013 and 2014 covering the aggregate average daily volumes and weighted average prices shown below:
Natural gas swaps:
Contract volumes (Bbtu/d)
Weighted average price (per MMBtu)
Contract volumes (MBbls/d)
Weighted average price (per Bbl)
In connection with several swaps shown in the table above, Forest granted swaption instruments to counterparties in exchange for Forest receiving premium hedged prices on the swaps. The table below sets forth the outstanding swaptions as of February 20, 2013:
Natural gas swaptions:
Contract volumes (Bbtu/d)
Weighted average price (per MMBtu)
Contract volumes (MBbls/d)
Weighted average price (per Bbl)
NON-GAAP FINANCIAL MEASURES
Adjusted Net Earnings
In addition to reporting net earnings (loss) from continuing operations as defined under generally accepted accounting principles (GAAP), Forest also presents adjusted net earnings from continuing operations (adjusted net earnings), which is a non-GAAP performance measure. Adjusted net earnings consist of net earnings (loss) from continuing operations 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 earnings (loss) from continuing operations (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 earnings (loss) from continuing operations and revenues to measure operating performance. The following table provides a reconciliation of net earnings (loss) from continuing operations, the most directly comparable GAAP measure, to adjusted net earnings for the periods presented (in thousands):
Three Months Ended
Net earnings (loss) from continuing operations
Ceiling test write-down of oil and natural gas properties, net of tax
Change in valuation allowance on deferred tax assets and foreign income tax rate differential
Impairment of properties, net of tax
Stock-based compensation expense attributable to the spin-off, net of tax
Severance and stock based compensation acceleration, net of tax
Non-deductible stock based compensation costs