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October 26, 2011
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Sherritt Reports Third-Quarter 2011 Results
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TORONTO, ONTARIO--(Marketwire - Oct. 26, 2011) -
NOT FOR DISTRIBUTION TO UNITED STATES NEWSWIRE SERVICES OR FOR DISSEMINATION IN THE UNITED STATES
Sherritt International Corporation ("Sherritt" or the "Corporation") (TSX:S) today announced third-quarter 2011 results.
-- Net earnings for third-quarter 2011 were up 102% to $45.5 million ($0.16
per share, basic), compared to net earnings of $22.5 million ($0.07 per
share, basic) for third-quarter 2010.
-- Sales volumes for third-quarter 2011 (Sherritt's share) totaled 9.4
million pounds of nickel, 1.1 million pounds of cobalt, 9.1 million
tonnes of thermal coal, 1.1 million barrels of oil and 159 GWh of
electricity.
-- Cash, cash equivalents and short-term investments were $586.6 million at
September 30, 2011, including $18.2 million (50% basis) held by the Moa
Joint Venture. Cash held by the Ambatovy Project is included in
"Investment in an Associate" and was $12.1 million (40% basis) as at
September 30, 2011.
-- Operating cash flow for third-quarter 2011 was $95.8 million, compared
to $91.3 million in third-quarter 2010.
-- Spending on capital and intangibles relating to existing operations
totaled $36.8 million for third-quarter 2011 (excluding accruals and
capital leases), unchanged compared to third-quarter 2010. Spending on
capital in the Ambatovy Project was $322.7 million (100% basis) for
third-quarter 2011, 60% higher than the prior-year period.
-- Primary construction of the Ambatovy Project is complete with all 56
major process plant modules turned over to commissioning teams. All
areas of the Project are either in pre-commissioning, commissioning, or
start-up. Two of the three power plant units are operating reliably and
provide sufficient power for commissioning activities and start-up. The
start-up sequencing has begun on the first systems of the pressure acid
leach circuits, including the first autoclave and the ammonia storage
facility. Commissioning is complete on many ancillary operations and
systems including the acid plants, air separation plant, and limestone
plant. The Project is scheduled to produce first metal in first-quarter
2012.
-- At September 30, 2011, total available liquidity was approximately $1.0
billion. During third-quarter 2011, the borrowing under the US$2.1
billion (100% basis) Ambatovy Joint Venture senior project financing was
completed. Total long-term debt at September 30, 2011 was $1.6 billion,
including approximately $0.8 billion related to non-recourse Ambatovy
partner loans to Sherritt.
Summary Data
SUMMARY FINANCIAL DATA
Nine months ended
September 30,
($ millions unless otherwise noted) Q3 2011 Q3 2010 2011 2010
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Revenue 466.4 412.7 1,441.5 1,185.4
EBITDA(1) 148.5 135.8 470.8 387.7
Earnings from operations and
associate 89.7 72.4 311.7 242.8
Net earnings 45.5 22.5 169.2 102.1
Basic earnings per share ($ per
share) 0.16 0.07 0.58 0.35
Diluted earnings per share ($ per
share) 0.15 0.07 0.57 0.35
Net working capital(2) 1,031.7 1,045.5 1,031.7 1,045.5
Spending on capital and
intangibles(3) 36.8 36.8 86.3 106.5
Total assets 6,367.6 6,020.2 6,367.6 6,020.2
Shareholders' equity 3,764.4 3,561.5 3,764.4 3,561.5
Long-term debt to total assets (%) 26 25 26 25
Weighted average number of shares
(millions)
Basic 295.2 294.0 295.0 293.9
Diluted 296.4 296.3 296.2 296.2
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(1) For additional information see the 'Non-IFRS Measure - EBITDA' section
of this release.
(2) Net working capital is calculated as total current assets less total
current liabilities.
(3) Spending on capital does not include accruals and does not include
spending on the Ambatovy Project.
SUMMARY SALES DATA
Nine months ended
September 30,
(units as noted) Q3 2011 Q3 2010 2011 2010
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Sales volumes
Nickel (thousands of pounds, 50%
basis) 9,421 9,800 27,922 27,462
Cobalt (thousands of pounds, 50%
basis) 1,052 1,067 3,121 2,989
Thermal coal - Prairie Operations
(millions of tonnes) 8.1 8.1 23.5 25.0
Thermal coal - Mountain Operations
(millions of tonnes)(1) 1.0 1.0 3.1 2.1
Oil (boepd, net working-interest
production) 11,982 10,911 12,250 11,913
Electricity (GWh, 33 1/3% basis) 159 176 461 519
Average realized prices
Nickel ($/lb) 9.81 9.87 10.70 9.88
Cobalt ($/lb) 15.50 18.61 16.42 19.20
Thermal coal - Prairie Operations
($/tonne) 16.20 14.32 16.19 14.41
Thermal coal - Mountain Operations
($/tonne) 102.39 88.41 98.03 83.71
Oil ($/boe) 69.62 50.51 66.81 51.58
Electricity ($/MWh) 40.66 42.92 40.49 42.59
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(1) Prior to July 1, 2010, the Corporation proportionately consolidated its
50% interest in the entity that owned the Coal Valley and Obed Mountain
mines.
Review of Operations
METALS
Nine months ended
September 30,
(units as noted) Q3 2011 Q3 2010 2011 2010
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Production
Mixed sulphides (tonnes, 50%
basis) 4,872 4,734 14,647 14,077
Nickel (tonnes, 50% basis) 4,395 4,522 12,689 12,527
Cobalt (tonnes, 50% basis) 489 489 1,408 1,361
Fertilizers (tonnes) 58,083 56,301 173,249 173,205
Sales
Nickel (thousands of pounds, 50%
basis) 9,421 9,800 27,922 27,462
Cobalt (thousands of pounds, 50%
basis) 1,052 1,067 3,121 2,989
Fertilizers (tonnes) 15,055 26,001 103,400 137,758
Reference prices
Nickel (US$/lb) 10.00 9.62 11.04 9.61
Cobalt (US$/lb)(1) 16.13 18.10 17.16 19.18
Realized prices
Nickel ($/lb) 9.81 9.87 10.70 9.88
Cobalt ($/lb) 15.50 18.61 16.42 19.20
Unit operating costs (US$/lb)
Mining, processing and refining
costs 6.28 4.86 6.06 5.02
Third-party feed costs 0.11 0.21 0.17 0.30
Cobalt by-product credits (1.76) (1.95) (1.87) (2.02)
Other (0.17) 0.25 (0.11) 0.01
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Net direct cash costs of
nickel(2) 4.46 3.37 4.25 3.31
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Sulphur (US$/tonne) 260.82 160.30 234.67 139.95
Sulphuric acid (US$/tonne) 191.87 133.28 187.92 132.76
Revenue ($ millions)
Nickel 92.4 96.7 298.8 271.3
Cobalt 16.3 19.9 51.2 57.4
Fertilizers, other 14.2 11.2 62.7 53.3
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Total revenue 122.9 127.8 412.7 382.0
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EBITDA ($ millions)(3) 44.4 56.4 164.7 157.3
Earnings from operations and
associate ($ millions) 35.7 50.0 143.2 133.2
Spending on capital ($ millions) 8.0 12.7 23.3 25.9
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(1) Average Metal Bulletin - Low Grade Cobalt published price.
(2) Net direct cash costs of nickel after cobalt and other by-product
credits.
(3) For additional information see the 'Non-IFRS Measure - EBITDA' section
of this release.Mixed sulphides production for third-quarter 2011 was 3% (276 tonnes, 100% basis) higher than third-quarter 2010, reflecting the impact of ongoing process improvements. Finished nickel production was 3% (254 tonnes, 100% basis) lower than the prior-year period due to a lower nickel to cobalt ratio in the feed as well the impact of maintenance activities at the refinery. Finished cobalt production was unchanged when compared to third-quarter 2010.
Third-quarter 2011 nickel and cobalt sales volumes were 4% (379 tonnes, 50% basis) and 1% (15 tonnes, 50% basis) lower, respectively, than the prior-year period due to the timing of shipments. Nickel sales were also impacted by lower production in the period.
The average nickel reference price in third-quarter 2011 was 4% (US$0.38/lb) higher than the prior-year period due mainly to relatively stronger demand. The average cobalt reference price was 11% (US$1.97/lb) lower than third-quarter 2010, due to lower demand.
The net direct cash cost of nickel for third-quarter 2011 was 32% (US$1.09/lb) higher than the prior-year period due to the impact of higher commodity input prices, including a 63% increase in the cost of sulphur, a 44% increase in the cost of sulphuric acid and a lower cobalt by-product credit resulting from the lower cobalt reference price. These impacts were only partially offset by lower third-party feed costs and higher fertilizer by-product credits.
Spending on capital in third-quarter 2011 for the Moa Joint Venture was 37% ($4.7 million, 50% basis) lower than the prior-year period due to the timing of expenditures.
Ambatovy
Ambatovy project expenditures for third-quarter 2011 were US$329.2 million (100% basis) and cumulative capital spending on the Project at September 30, 2011 was US$5.1 billion (100% basis). During third-quarter 2011, a total of $211.2 million (100% basis) in funding was provided by the Ambatovy Joint Venture partners; Sherritt's 40% share ($84.5 million) was funded directly from cash on hand. In addition, US$138.9 million was drawn on the senior project finance facility during third-quarter 2011.
Primary construction of the Project is complete with all 56 major process plant modules turned over to commissioning teams. All areas of the Project are either in pre-commissioning, commissioning, or start-up. As of September 30, 2011, approximately 70% of the construction personnel have been demobilized from the Project, including approximately 4,300 people in third-quarter 2011. During the staged start-up of the Project, demobilization will continue as pre-commissioning, commissioning, testing, reworking and site cleanup are completed. Full production rates require the operation of two of the three power plant units. As of mid-October, two of the three power plant units were operating reliably and provide sufficient power for commissioning activities and start-up. Commissioning of the third and final coal-fired boiler is underway and it is expected to be operational during the fourth quarter. Supplemental diesel power generation (30 MW in total) is being installed to provide additional assurance of reliable power availability for plant operations. When complete, total generation capacity of the Plant Site will be approximately 163 MW and will exceed total power requirements at full production (60 - 75 MW). The start-up sequencing has begun on the first systems of the pressure acid leach circuits, including the first autoclave and the ammonia storage facility. Commissioning is also complete on many ancillary operations and systems including the acid plants, air separation plant, and limestone plant. During third-quarter 2011, the first sulphur shipment was received at the port, transported to the Plant Site and discharged to the stockpile. The first ammonia vessel is due to arrive at the port during the fourth quarter.
The Project is designed to produce 60,000 tonnes (100% basis) of nickel and 5,600 tonnes (100% basis) of cobalt annually at capacity. The estimated Project capital cost is US$5.5 billion (100% basis), excluding financing charges, working capital, and foreign exchange with production of first metal scheduled for first-quarter 2012.
COAL
Nine months ended
September 30,
(units as noted) Q3 2011 Q3 2010 2011 2010
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Production (millions of tonnes)
Prairie Operations 7.7 8.4 22.9 24.4
Mountain Operations(1) 1.0 1.1 3.1 2.1
Sales (millions of tonnes)
Prairie Operations 8.1 8.1 23.5 25.0
Mountain Operations(1) 1.0 1.0 3.1 2.1
Realized prices ($/tonne)
Prairie Operations(2) 16.20 14.32 16.19 14.41
Mountain Operations 102.39 88.41 98.03 83.71
Unit operating costs ($/tonne)
Prairie Operations(3) 14.32 12.19 14.19 12.47
Mountain Operations 83.94 72.97 81.44 72.76
Revenue ($ millions)
Prairie Operations
Mining revenue 136.9 120.7 398.9 371.6
Coal royalties 7.6 10.7 29.1 31.7
Potash royalties 4.8 1.5 14.8 8.0
Mountain Operations and other
assets(1) 97.9 84.9 304.4 174.4
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Total revenue 247.2 217.8 747.2 585.7
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EBITDA ($ millions)(4)
Prairie Operations 27.8 29.4 88.0 85.4
Mountain Operations and other
assets(1) 15.7 12.3 47.2 19.5
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Total EBITDA 43.5 41.7 135.2 104.9
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Earnings from operations ($
millions) 14.0 12.2 56.1 53.6
Spending on capital ($ millions)
Prairie Operations 21.0 14.3 57.4 43.1
Mountain Operations and other
assets(1) 5.5 5.3 17.8 12.6
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Total spending on capital 26.5 19.6 75.2 55.7
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(1) Prior to July 1, 2010, the Corporation proportionately consolidated its
50% interest in the entity that owned the Coal Valley and Obed Mountain
mines.
(2) Prairie Operations realized pricing excludes results of the char and
activated carbon businesses and royalties.
(3) Prairie Operations unit operating costs exclude char and activated
carbon results.
(4) For additional information see the 'Non-IFRS Measure - EBITDA' section
of this release.Third-quarter 2011 production volumes at Prairie Operations were 8% (0.7 million tonnes) lower than the prior-year period mainly due to lower demand at a contract mine, whose main customer removed two generating units from service in first-quarter 2011. In September 2011, the customer began commercial operations of a new 495 MW (gross) generation unit that is considered one of the most advanced facilities of its kind in the world. The coal supply for this new unit is expected to offset the majority of the impact on coal demand from the closure of the two older generating units. Production volumes at Mountain Operations were 11% (0.1 million tonnes) lower than third-quarter 2010, reflecting the impact of dragline repair and increased overburden removal at the Obed Mountain mine. The focus on preparatory activities in the third quarter is expected to permit higher production levels in the last quarter of the year.
Sales volumes at both Prairie Operations and Mountain Operations for third-quarter 2011 were unchanged relative to third-quarter 2010.
Realized pricing in Prairie Operations (excluding royalties, activated carbon and char) for third-quarter 2011 was 13% ($1.88/tonne) higher than in the prior-year period primarily due to higher contract revenue on lower sales volume at a contract mine and the sale of stockpile inventory from Bienfait to Boundary Dam's main customer. Realized pricing in Mountain Operations in third-quarter 2011 was 16% ($13.98/tonne) higher than the prior-year period due to stronger export thermal coal pricing, partially offset by the impact of a stronger Canadian dollar relative to the U.S. dollar.
Unit operating costs at Prairie Operations were 17% ($2.13/tonne) higher than third-quarter 2010, due to the impact of lower production at a contract mine. Unit operating costs at Mountain Operations were 15% ($10.97/tonne) higher than in the prior-year period due to lower production volumes at the Obed Mountain mine and higher loading equipment costs at the Coal Valley mine.
Total royalties for third-quarter 2011 were 2% ($0.2 million) higher than third-quarter 2010, primarily due to the impact of higher potash market prices and production volumes.
Spending on capital in Prairie Operations in third-quarter 2011 was 47% ($6.7 million) higher than third-quarter 2010, due to a scheduled tub replacement at the Paintearth mine and the timing of mining equipment lease additions at the Boundary Dam mine. Capital spending in Mountain Operations for third-quarter 2011 was largely consistent with spending in the prior-year period.
OIL AND GAS
Nine months ended
September 30,
(units as noted) Q3 2011 Q3 2010 2011 2010
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Production (boepd)(1)
Gross working-interest - Cuba(2),
(3) 20,756 20,622 20,843 21,288
Net working-interest(4)
Cuba - cost recovery 3,501 4,655 3,809 3,991
Cuba - profit oil 7,764 5,559 7,665 7,078
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Cuba - total 11,265 10,214 11,474 11,069
Spain 354 336 422 481
Pakistan 363 361 354 363
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Total net working-interest 11,982 10,911 12,250 11,913
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Reference prices (US$/bbl)
U.S. Gulf Coast Fuel Oil No.6 98.55 66.69 94.45 68.56
Brent crude 114.47 77.49 112.73 77.47
Realized prices
Cuba ($/bbl) 70.36 51.06 67.06 51.77
Spain ($/bbl) 111.21 79.07 109.81 79.78
Pakistan ($/boe) 8.15 8.31 8.01 8.34
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Weighted average ($/boe) 69.62 50.51 66.81 51.58
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Unit operating costs
Cuba ($/bbl) 12.65 10.34 11.59 10.53
Spain ($/bbl) 84.22 47.84 46.75 32.75
Pakistan ($/boe) 2.49 1.90 2.98 2.05
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Weighted average ($/boe) 14.45 11.22 12.55 11.17
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Revenue ($ millions) 78.5 53.2 230.5 176.3
EBITDA ($ millions)(5) 60.8 38.5 181.2 131.0
Earnings from operations ($
millions) 43.4 14.4 132.2 71.4
Spending on capital ($ millions) 16.6 11.6 50.3 41.4
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(1) Oil production is stated in barrels per day ("bpd"). Natural gas
production is stated in barrels of oil equivalent per day ("boepd"),
which is converted at 6,000 cubic feet per barrel.
(2) In Cuba, Oil and Gas delivers all of its gross working-interest oil
production to Union Cubapetroleo (CUPET) at the time of production.
Gross working-interest oil production excludes production from wells
for which commerciality has not been established in accordance with
production-sharing contracts.
(3) Gross working-interest oil production is allocated between Oil and Gas
and CUPET in accordance with production-sharing contracts. The
Corporation's share, referred to as 'net working-interest oil
production', includes: (i) cost recovery oil (based upon the
recoverable capital and operating costs incurred by Oil and Gas under
each production-sharing contract), and (ii) a percentage of profit oil
(gross working-interest production remaining after cost recovery oil is
allocated to Oil and Gas). Cost recovery pools for each production-
sharing contract include cumulative recoverable costs, subject to
certification by CUPET, less cumulative proceeds from cost recovery oil
allocated to Oil and Gas. Cost recovery revenue equals capital and
operating costs eligible for recovery under the production-sharing
contracts.
(4) Net working-interest production (equivalent to net sales volume)
represents the Corporation's share of gross working-interest
production.
(5) For additional information see the 'Non-IFRS Measure - EBITDA' section
of this release.Third-quarter 2011 gross working-interest production for the period was relatively unchanged from the prior-year period. Net working-interest production in Cuba was 10% (1,051 bpd) higher for the same comparable periods due mainly to a 25% (1,154 bpd) decrease in cost recovery volumes resulting from the impact of higher realized oil prices, partially offset by an increase in cost recovery expenditures. Third-quarter 2011 production in both Spain and Pakistan was largely unchanged from the prior- year period.
Average realized prices in third-quarter 2011 were significantly higher than third-quarter 2010 in Cuba (38% or $19.30/bbl) and Spain (41% or $32.14/bbl), as the impact of stronger reference pricing more than offset the impact of a stronger Canadian dollar relative to the U.S. dollar.
Third-quarter 2011 unit operating costs in Cuba were 22% ($2.31/bbl) higher than the prior-year period as the impact of a stronger Canadian dollar relative to the U.S. dollar was more than offset by higher input prices. Unit operating costs in Spain were 76% ($36.38/bbl) higher than the prior-year period primarily due to well workover costs incurred in third-quarter 2011.
Spending on capital in third-quarter 2011 was 43% ($5.0 million) higher than in the prior-year period due to increased drilling activity in the Puerto Escondido and Yumuri fields. In third-quarter 2011, drilling on two development wells commenced and two development wells were completed. This compares to one development well commenced and two development wells completed in third-quarter 2010.
POWER
Nine months ended
September 30,
(units as noted) Q3 2011 Q3 2010 2011 2010
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Electricity sold (GWh, 33 1/3%
basis) 159 176 461 519
Realized price ($/MWh) 40.66 42.92 40.49 42.59
Unit cash operating cost ($/MWh) 20.13 15.34 21.26 13.87
Net capacity factor (%) 68 76 66 72
Revenue ($ millions) 14.0 11.0 41.4 34.7
EBITDA ($ millions)(1) 6.4 7.5 17.7 22.3
Earnings from operations ($
millions) 3.7 4.8 9.8 13.9
Spending on capital ($ millions) 2.5 3.5 4.7 5.3
Spending on service concession
arrangements ($ millions)(2) 4.3 0.6 13.4 3.5
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(1) For additional information see the 'Non-IFRS Measure - EBITDA' section
of this release.
(2) Costs incurred to maintain or enhance the Boca de Jaruco and Puerto
Escondido operating assets are expensed on the consolidated statements
of comprehensive income. As a result, maintenance and construction
activities at Boca de Jaruco, including the 150 MW Boca de Jaruco
Combined Cycle Project, are expensed as incurred. The Corporation
records an intangible asset and a corresponding construction revenue
amount to reflect the right to charge the Cuban government for the
future supply of electricity. The net result is a nil impact to net
earnings.Electricity production for third-quarter 2011 was 10% (17 GWh, 33 1/3% basis) lower than third-quarter 2010, due to continued gas supply shortages and scheduled maintenance. The gas turbine at Varadero that failed in second-quarter 2011 is expected to be returned to service in fourth-quarter 2011. Efforts to address the gas supply shortage continue, but to date, none have provided viable solutions to the issue.
Third-quarter 2011 unit cash operating costs were 31% ($4.79/MWh) higher than third-quarter 2010, due to higher repair and scheduled maintenance costs.
Spending on capital, including capitalized interest, and spending on service concession arrangements in third-quarter 2011 were 66% ($2.7 million, 33 1/3% basis) higher than in the prior-year period primarily due to increased activity on the 150 MW Boca de Jaruco Combined Cycle Project.
CASH, DEBT AND FINANCING
Cash, cash equivalents and short-term investments were $586.6 million at September 30, 2011. Of the cash balance, $18.2 million (50% basis) was held by the Moa Joint Venture and is for the exclusive use of the joint venture. Cash held by the Ambatovy Project is included in "Investment in an Associate" and was $12.1 million (40% basis) as at September 30, 2011.
Total long-term debt at September 30, 2011 was $1.6 billion, including approximately $0.8 billion related to non-recourse Ambatovy partner loans to Sherritt.
At September 30, 2011, the amount of credit available under various facilities was $0.5 billion. During third-quarter 2011, the borrowing under the US$2.1 billion (100% basis) Ambatovy Joint Venture senior project financing was completed.
Outlook
Projections for Sherritt's production volumes, royalties and spending on capital for the year 2011 are shown below.
(units as noted) 2011
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Production volumes
Mixed sulphides (tonnes) 38,850
Nickel (tonnes, 100% basis) 34,350
Cobalt (tonnes, 100% basis) 3,750
Coal - Prairie Operations (millions of tonnes) 32
Coal - Mountain Operations (millions of tonnes) 4.4
Oil - Cuba (gross working-interest, bpd) 20,700
Oil - All operations (net working-interest, boepd) 12,250
Electricity (GWh, 33 1/3% basis) 620
Royalties ($ millions)
Coal 39
Potash 17
Spending on capital ($ millions)
Metals - Moa Joint Venture (50% basis) 45
Coal - Prairie Operations 94
Coal - Mountain Operations 44
Oil and Gas - Cuba(1) 62
Oil and Gas - Other(1) 8
Power (33 1/3% basis)(2) 36
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Total spending on capital (excluding Ambatovy) 289
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Metals - Ambatovy (US$ millions, 100% basis) 1,000
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(1) Exploration and evaluation spending incurred prior to the technical
feasibility and commercial viability of extracting the resources is
recorded as an intangible asset.
(2) Includes projected spending related to the 150 MW Boca de Jaruco
Combined Cycle Project that is expensed as incurred and is included in
cost of sales on the consolidated statement of comprehensive income.
-- In Metals - Moa Joint Venture, guidance for full-year 2011 production of
mixed sulphides increased 1% (550 tonnes, 100% basis), reflecting the
strong operating performance in the first nine months. Finished nickel
and cobalt production guidance for full-year 2011 are marginally higher
than previous estimates due to the performance in the first nine months
of the year. Guidance for spending on capital in the Moa Joint Venture
is 10% ($5 million, 50% basis) lower than previously provided,
reflecting the deferral of spending to 2012. The Moa Joint Venture
partners continue to review options for the completion of the Phase 2
Expansion and construction of a sulphuric acid plant at Moa. Guidance
for spending on capital does not include any expansion-related
expenditure, other than capitalized interest.
-- In Metals - Ambatovy Joint Venture, full-year 2011 capital spending
remains at US$1.0 billion.
-- In Metals - Sulawesi Project, projected spending for 2011 is expected to
be $9 million, due to permitting delays. Spending is being directed
toward the next phase of the resource drilling program and advancing
environmental and social baseline studies as well as project
prefeasibility work.
-- In Coal - Prairie Operations, guidance for full-year 2011 production is
3% (1 million tonnes) lower than previous guidance due to the impact of
adverse weather conditions in first-half 2011 as well as the impact of
lower demand at a contract mine, whose main customer removed two
generating units from service in first-quarter 2011. Spending on capital
in Prairie Operations is 6% ($6 million) lower than previous full-year
2011 guidance, largely due to projects in the first nine months of 2011
costing less than originally projected, as well as the timing of
expenditures.
-- In Coal - Mountain Operations, production guidance remains unchanged.
Spending on capital in Mountain Operations is projected to be 4% ($2
million) lower than previous full-year 2011 guidance largely due to
projects in the first nine months of 2011 costing less than originally
projected.
-- In Oil and Gas, guidance relating to full-year 2011 gross working-
interest oil production in Cuba increased 1% (200 bpd), reflecting
better than expected performance from producing wells. Total net
working-interest production for 2011 remains largely unchanged. Guidance
on spending on capital for 2011 in Cuba remains largely unchanged from
previous estimates. In total, eight development wells are planned for
2011.
-- In Power, guidance for 2011 full-year production is 5% (32 GWh, 33 1/3%
basis) higher than previous estimates, reflecting higher than expected
gas supply in third-quarter 2011, and higher gas supply in fourth-
quarter 2011 than previously anticipated. However, gas supply is
expected to continue to be insufficient for the facilities to operate at
full capacity. Full-year 2011 guidance for spending on capital, which is
primarily related to the 150 MW Boca de Jaruco Combined Cycle Project,
remains largely unchanged from previous estimates.Non-IFRS Measure - EBITDA
The Corporation's definition of EBITDA is earnings (loss) from operations and associate as reported in the IFRS financial statements, excluding amounts included in net earnings or net loss for income taxes, financing income, financing expense, depletion, depreciation, and amortization in cost of sales and administrative expenses, impairment charges for property, plant and equipment, intangible assets, goodwill and investments, gain or loss on disposal of property, plant and equipment, and share of income or loss of associate.
About Sherritt
Sherritt is a world leader in the mining and refining of nickel from lateritic ores with projects and operations in Canada, Cuba, Indonesia and Madagascar. The Corporation is the largest coal producer in Canada and is the largest independent energy producer in Cuba, with extensive oil and power operations across the island. Sherritt licenses its proprietary technologies and provides metallurgical services to mining and refining operations worldwide. The Corporation's common shares are listed on the Toronto Stock Exchange under the symbol "S".
Forward-Looking Statements
This press release contains certain forward-looking statements. Forward-looking statements generally can be identified by the use of statements that include words such as "believe", "expect", "anticipate", "intend", "plan", "forecast", "likely", "may", "will", "could", "should", "suspect", "outlook", "projected", "continue" or other similar words or phrases. Specifically, forward-looking statements in this document include statements respecting certain future expectations about the Corporation's capital and project development spending; Ambatovy Project production, startup, commissioning and completion dates; production volumes; royalty revenues; and other corporate objectives, plans or goals for 2011. These forward-looking statements are not based on historic facts, but rather on current expectations, assumptions and projections about future events. There is significant risk that predictions, forecasts, conclusions or projections will not prove to be accurate, that those assumptions may not be correct and that actual results may differ materially from such predictions, forecasts, conclusions or projections. Sherritt cautions readers of this press release not to place undue reliance on any forward-looking statements as a number of factors could cause actual future results, conditions, actions or events to differ materially from the targets, expectations, estimates or intentions expressed in the forward-looking statements. By their nature, forward-looking statements require Sherritt to make assumptions and are subject to inherent risks and uncertainties.
Key factors that may result in material differences between actual results and developments and those contemplated by this press release include global economic conditions, business, economic and political conditions in Canada, Cuba, Indonesia, Madagascar, and the principal markets for Sherritt's products. Other such factors include, but are not limited to, uncertainties in the development and construction of large mining projects; risks related to the availability of capital to undertake capital initiatives; changes in capital cost estimates in respect of the Corporation's capital initiatives; risks associated with Sherritt's joint venture partners; future non-compliance with financial covenants; potential interruptions in transportation; political, economic and other risks of foreign operations; Sherritt's reliance on key personnel and skilled workers; the possibility of equipment and other unexpected failures; the potential for shortages of equipment and supplies; risks associated with mining, processing and refining activities; uncertainties in oil and gas exploration; risks related to foreign exchange controls on Cuban government enterprises to transact in foreign currency; risks associated with the United States embargo on Cuba and the Helms-Burton legislation; risks related to the Cuban government's ability to make certain payments to the Corporation; development programs; uncertainties in reserve estimates; uncertainties in asset-retirement and reclamation cost estimates; Sherritt's reliance on significant customers; foreign exchange and pricing risks; uncertainties in commodity pricing; credit risks; competition in product markets; Sherritt's ability to access markets; risks in obtaining insurance; uncertainties in labour relations; uncertainties in pension liabilities; the ability of Sherritt to enforce legal rights in foreign jurisdictions; the ability of Sherritt to obtain government permits; risks associated with government regulations and environmental health and safety matters; differences between Canadian GAAP and IFRS; and other factors listed from time to time in Sherritt's continuous disclosure documents.
Further, any forward-looking statement speaks only as of the date on which such statement is made, and except as required by law, Sherritt undertakes no obligation to update any forward-looking statements.
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CONTACT INFORMATION:
Sherritt International Corporation
Investor Relations
416.935.2451 or Toll-free: 1.800.704.6698
investor@sherritt.com
www.sherritt.com
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INDUSTRY: Energy and Utilities - Coal, Energy and Utilities - Oil and Gas , Manufacturing and Production - Mining and Metals
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