Lone Clone
17年前
Coal-bed methane industry finds a home in Peace Country
Canada Energy Partners wins over Hudson's Hope and becomes a first in B.C.
By Scott Simpson, VANCOUVER SUNJanuary 9, 2009
http://www.vancouversun.com/Coal+methane+industry+finds+home+Peace+Country/1158147/story.html
Condemned in many British Columbia communities as an environmental hazard, coal-bed methane development has found a home in the Peace River Valley.
A junior gas exploration company with a head office in Vancouver, a CEO from Baton Rouge, La., and a drilling partner from Texas, has succeeded where industry giants including Shell, Encana and BP, have faltered.
The Vancouver junior, Canada Energy Partners, and Texas-based GeoMet Inc. announced earlier this week that they'd begun commercial shipment of coal-bed methane from an initial spate of wells in the vicinity of the historic northeast B.C. town of Hudson's Hope.
It is the first coal-bed gas project in B.C., where controversy has dogged every effort by the government to develop a potentially lucrative resource, to reach commercial production.
"There has been real resistance in the Fernie area, real resistance in Smithers, Vancouver Island, Princeton, Klappan," Baton Rouge native Ben Jones, president and CEO of Canada Energy, drawled in a telephone interview. "Our area is about the only one that has been sailing along -- with bumps, some stormy weather, but [it] has continued to sail."
Jones first came to B.C. in 1999 and acquired his first drilling lease for coal-bed methane in 2001, just as the government was gearing up to promote it.
He got the rights for an average $120 a hectare in an area of the province where recent bids exceed 100 times that amount, and multinationals such as Talisman Energy are talking about 10-year, $7.5-billion investments in coal-bed methane development.
So far Canada Energy and GeoMet, through subsidiary Hudson's Hope Gas, have drilled eight wells, with three now in production and five in the process of pumping out underground water so that the gas can begin to flow.
"With conventional exploration, your best production is at the beginning. The best day is the first day and everything is downhill from there, whereas in coal-bed methane it's exactly the opposite," Jones said.
"These things will build over time, but it makes for an excruciating manager's life because it will make you pull your hair out.
"We will not have recouped our sunk costs probably for several years, but we could be in a positive cash flow as to our lease-operating expenses this year."
The global financial crisis hasn't hurt and Canada Energy chairman John Proust said it's not likely to pose future problems.
"We were very fortunate to do a significant financing prior to the market coming down, so we are well financed," he said from his Vancouver office. "We've got approximately $16 million in our treasury currently and that takes us well through this year, well through next year."
In addition, he noted, Canada Energy has a development agreement with Crew Energy to undertake shallow and deep gas drilling on its properties in the Peace Region, which could bring in additional resource revenue.
Proust notes that the company could drill as many as 315 wells on its coal-bed project alone.
Since 2003, coal-bed methane, or CBM, has on three occasions been the subject of resolutions by the Union of B.C. Municipalities urging the province to deal exhaustively with community concerns before another well is drilled.
The principal fear is a repeat of environmental disasters that took place in the United States, notably Wyoming, as unsophisticated drilling efforts caused breaches in underground coal seams that allowed gas and saline water to contaminate aquifers containing potable water in the vicinity, and careless surface disposal of saline water that contaminated the landscape.
Those problems did not go unnoticed here in B.C.
Last month, the province announced a two-year moratorium on Shell Canada's drilling efforts in the Klappan coal field in northwest B.C., where aboriginal groups, environmentalists and local politicians were united in opposition to drilling on the premise that it could lead to contamination of drinking water and salmon streams.
Canada Energy and its 50-per-cent partner, Geomet, meanwhile, have worked through their issues and are now generally regarded in Hudson's Hope as a model of good corporate citizenry.
Jones noted that northeast B.C. is already home to a booming natural gas industry that has bolstered the province's finances at a time when resource revenues from forestry are crashing.
"Most of those people there were more familiar with oil and gas operations than any of these other areas. I think that was part of the reason we've been able to proceed along.
"And I want to compliment Hudson's Hope. It's a community of a lot of good people and most of them are fairly reasonable. Some of the most vociferous opponents of CBM, I have very positive, constructive dialogue with."
The harshest critic in Hudson's Hope, local landowner Steve Metzger, has concluded that there is little risk to the city's water supply.
"I'm never one who would say it's impossible for the methane to get into our water supplies here. But I'm not personally concerned about that," Metzger said in a telephone interview. "I understand how far away the gas is from where our water supplies come from and it's real unlikely that that's going to be a problem."
Metzger is resigned to the presence of the industry in the community, but remains concerned about the possible industrialization of the local landscape as more wells are developed.
Even on this issue, he's taking a wait-and-see attitude. "It got to the point where, you know, it's gone ahead and it's not going to stop.
"The focus has shifted to, 'Okay, it's here, how can we deal with it?' "
Fort St. John MLA Richard Neufeld, B.C.'s energy minister since May 2001, said he never imagined it would take so long for the industry to gain a foothold in B.C.
"I think it will be a little bit slower than what I had hoped for, and maybe in retrospect, that's not that bad," Neufeld said. "I think you do have to let people get accustomed to it, and now that we have one area that's producing coal-bed gas into a sales line, that's good news we can talk about in the rest of the province."
Hudson's Hope Mayor Karen Anderson said a fraction of the community is still expressing negative opinions about the industry, "but on the whole, I am quite pleased with Hudson's Hope Gas and the way they have gone forth with this venture of theirs."
"We heard some horror stories of things that went on in the States," Anderson said. "We did not let that scare us. We took an open-mind approach and had those [stories] investigated. We had the pros and the cons come and talk to us.
"We decided that we are a little community, that we are looking for growth in our community, that we are welcoming businesses within our community. They are just another type of a business and they have really stepped up to the plate and been really forthright with us.
"Personally, and I think I can talk for the majority of council, we are quite happy with the working relationship we have with Hudson's Hope Gas."
Lone Clone
18年前
Storm Cat Energy Corporation Announces Default Under Subordinated Convertible Notes, Provides Update of Credit Facility and Engages Parkman Whaling LL
Fri Oct 31, 6:01 AM
http://ca.news.finance.yahoo.com/s/31102008/30/link-f-cnw-storm-cat-energy-corporation-announces-default-under-subordinated.html
DENVER and CALGARY, Alberta, Oct. 31 /CNW/ -- Storm Cat Energy Corporation (Amex: SCU; TSX: SME) today reported that it failed to make its required quarterly interest payment when due on September 30, 2008, and such failure has continued for a period of 30 days, with respect to its Series A and Series B Subordinated Convertible Notes each due March 31, 2012. The failure of Storm Cat to make the required quarterly interest payment prior to the expiration of such 30 day grace period constitutes an "Event of Default" under the terms of each of the respective Note Purchase Agreements.
In connection with Storm Cat's previously reported and continuing defaults under its Credit Agreement, its Lenders notified the noteholders that pursuant to the terms of the Note Purchase Agreements and the Subordination and Intercreditor Agreement previously entered into by the noteholders, that the Lenders were enforcing their rights (1) to prohibit Storm Cat from making any payments to the noteholders, and (2) to require that the noteholders standstill and not accelerate any amounts due under the Notes upon an Event of Default or seek other enforcement or redemption actions otherwise permitted under the Note Purchase Agreements. Additionally, as a result of the Event of Default, the rate of interest on the outstanding principal amount of the Notes as well as any overdue interest will increase from 9 1/4% to 12.0% per annum.
Storm Cat has been in discussions with its Lenders since mid-August in order to seek a waiver or forbearance of the defaults under the Credit Agreement, to amend the Credit Agreement or otherwise restructure the Company and seek a liquidity event. Although Storm Cat intends to pursue in good faith efforts to renegotiate or restructure the terms of the Credit Agreement, there can be no assurance that these efforts will ultimately be successful. In addition, any restructuring plan ultimately agreed upon by Storm Cat and its Lenders may involve implementation through a bankruptcy filing by Storm Cat and/or certain of its subsidiaries. In the event that Storm Cat and its Lenders fail to agree on the terms of a consensual restructuring of the obligations under the Credit Agreement, the Lenders may attempt to effect an acceleration of the obligations under the Credit Agreement. In such event, a material adverse effect on the Company and its results of operations would result.
In connection with the above mentioned defaults under the Credit Agreement, an affiliate of one of the Lenders recently exercised its right to declare a cross-default on Storm Cat's natural gas commodity swap agreements. The swap agreements were terminated and amounts in the aggregate of $9.4 million owing to Storm Cat upon termination of the swap agreements were paid to the Lenders to be set-off and reduce the amounts outstanding under the Company's revolving credit facility. Because Storm Cat remains in default under the Credit Agreement, it may not re-borrow any funds used to pay down the revolving credit facility without the consent of the Lenders in their sole discretion. As a result of the termination of the swap agreements, Storm Cat is now fully exposed to the impact of gas price fluctuations in the commodity markets.
As previously reported, Storm Cat has been exploring since mid-May numerous alternatives to improve liquidity, including raising capital, refinancing outstanding debt or the potential sale of assets. Unfortunately, as a result of falling commodity prices and the global financial crisis Storm Cat has been unsuccessful to date. Nonetheless, in connection with on-going discussions with its Lenders regarding potential restructuring initiatives, Storm Cat has engaged Houston-based Parkman Whaling LLC for the purpose of assisting the Company in exploring strategic business alternatives as well as engaged Alvarez & Marsal, a turnaround and restructuring firm, for the purpose of assisting the Company with its restructuring efforts.
About Storm Cat Energy
Storm Cat Energy is an independent oil and gas company focused on the exploration, production and development of large unconventional gas reserves from fractured shales, coal beds and tight sand formations and, secondarily, from conventional formations. The Company has producing properties in Wyoming's Powder River Basin and Arkansas' Arkoma Basin and exploration and development acreage in Canada. The Company's shares trade on the American Stock Exchange under the symbol "SCU" and in Canada on the Toronto Stock Exchange under the symbol "SME."
Forward-looking Statements
This press release contains certain "forward-looking statements", as defined in the United States Private Securities Litigation Reform Act of 1995, and within the meaning of Canadian securities legislation, relating to potential future production and growth, proposed new wells and infrastructure improvements affecting the Company's operations. Forward-looking statements are statements that are not historical facts; they are generally, but not always, identified by the words "expects," "plans," "anticipates," "believes," "intends, "estimates," "projects," "aims," "potential," "goal," "objective," "prospective," and similar expressions, or that events or conditions "will," "would," "may," "can," "could" or "should" occur. Forward-looking statements are based on the beliefs, estimates and opinions of Storm Cat's management on the date the statements are made and they involve a number of risks and uncertainties. Consequently, there can be no assurances that such statements will prove to be accurate and actual results and future events could differ materially from those anticipated in such statements. Storm Cat undertakes no obligation to update these forward-looking statements if management's beliefs, estimates or opinions, or other factors, should change. Factors that could cause future results to differ materially from those anticipated in these forward-looking statements include, but are not limited to: (i) the Company's ability to continue as a going concern; (ii) the ability to consummate any strategic alternatives; (iii) the ability of the Company to obtain and maintain normal terms with vendors and service providers; (iv) the Company's ability to maintain contracts that are critical to its operations; (v) the potential adverse impact of continuing defaults under its credit facility and convertible notes on the Company's liquidity or results of operations; (vi) the volatility of natural gas prices, the possibility that exploration efforts will not yield economically recoverable quantities of gas, accidents and other risks associated with gas exploration and development operations, (vii) the ability of the Company to fund and execute its business plan; (viii) the ability of the Company to attract, motivate and/or retain key executives and employees; (ix) the ability of the Company to attract and retain customers and * the other risk factors discussed in greater detail in the Company's various filings on SEDAR (www.sedar.com) with Canadian securities regulators and its filings with the U.S. Securities and Exchange Commission, including the Company's Form 10-K for the fiscal year ended December 31, 2007.
Contacts
William Kent
Director
Investor Relations of Storm Cat Energy Corporation
+1-303-991-5070 Web Site: http://www.stormcatenergy.com
Lone Clone
18年前
Storm Cat Energy Corporation Announces Second Quarter 2008 Financial and Operating Results
16:15 EDT Monday, August 11, 2008
http://www.globeinvestor.com/servlet/WireFeedRedirect?cf=GlobeInvestor/config&vg=BigAdVariableGenerator&date=20080811&archive=prnews&slug=LAM075
DENVER and CALGARY, Alberta, Aug. 11 /PRNewswire-FirstCall/ -- Storm Cat Energy Corporation (Amex: SCU; TSX: SME) today reported second quarter 2008 financial and operating results.
The second quarter of 2008 was an important step in Storm Cat's transition towards profitability. During the quarter we initiated sales from our Fayetteville Shale acreage, bringing a total of six wells online in the quarter. Production from our Fayetteville property along with our Powder River Basin (PRB) assets produced both record production and revenue results for the quarter. Our production for the quarter was in excess of one billion cubic feet of gas, totalling 1,151.4 million cubic feet (MMcf). Our revenue for the quarter was $6.6 million, a 78.6% increase from the second quarter of 2007. Operating Cash Flow(1) from our oil and gas activities increased 39.1% to $2.8 million for the quarter and 25.8% to $5.6 million for the first six months of the year. Adjusted EBITDA(2) for the second quarter was $1.3 million and $2.7 million for the six months ending June 30, 2008. Reconciliations of non-GAAP financial measures are provided in the financial schedules accompanying this press release.
Financial Update (all figures in U.S. Dollars)
Natural gas revenue for the quarter ended June 30, 2008 was $6.6 million, representing a 78.6% increase over second quarter 2007. This record revenue growth was accomplished wholly through the drill bit.
Production sales volume for the second quarter of 2008 was a record 1,151.4 MMcf an increase of 54.4% over second quarter 2007. This represents the sixth consecutive quarter of organic sales volume increases and the first quarter in our history that we have produced in excess of one billion cubic feet of gas.
For the quarter, we reported a net loss of $4.7 million, or $0.06 per share, as compared to a net loss of $4.6 million, or $0.06 per share, for the second quarter of 2007. Excluding the impact of hedging, net loss for the quarter would have been $3.1 million, or $0.04 per share.
Inclusive of hedging, the average realized gas price for the second quarter was $5.69 per thousand cubic feet (Mcf), 15.7% higher than the second quarter 2007 average price of $4.92 per Mcf. Excluding hedging, the realized gas price for the second quarter of 2008 was $7.12 per Mcf.
Gathering and transportation expenses increased approximately $0.9 million from $0.4 million in the second quarter of 2007 to $1.3 million in the second quarter of 2008. The increase is primarily related to startup transportation fees associated with our Fayetteville pipeline which began shipping gas in early April and increased production volumes.
Lease operating expenses increased to $2.4 million in the second quarter of 2008 compared to $1.3 million in the second quarter of 2007. This increase resulted primarily from additional wells added through our successful drilling program, higher per well lease operating costs resulting from fuel and generator rental costs associated with new wells in our PRB development areas where the electrical infrastructure has yet to be installed and higher per well lease operating costs on our Sheridan and Ford Ranch areas resulting from higher water production.
Depreciation, depletion and amortization increased by $1.0 million to $2.9 million in the second quarter of 2008 compared to $1.9 million in the second quarter of 2007. This increase resulted from increased production resulting from our successful drilling activities over the past year.
Weighted average shares outstanding for the second quarter 2008 increased to 81.2 million as compared to 81.0 million in the second quarter of 2007. The increase in average shares outstanding is attributed to the exercise of outstanding options, the vesting of restricted share units and the issuance of new restricted share units.
As of June 30, 2008, we were not in compliance with the financial and minimum average daily production covenants set forth in our credit agreement. We are currently discussing a possible waiver or amendment to our credit agreement with our lenders. However, absent a waiver or an amendment to the financial covenants or repayment or refinancing of the credit facility, it is likely that we will not be in compliance with our covenants for the next twelve months. Accordingly, the $64.6 million outstanding under the credit facility at June 30, 2008 is classified as a current liability in the accompanying Consolidated Balance Sheet at June 30, 2008.
Operations Update (all figures in U.S. Dollars)
Current total net production is 15.3 million cubic feet per day (MMcf/d).
Powder River Basin
During the second quarter of 2008 we invested a total of $10.2 million in the PRB. These capital dollars were used for acquisitions, drilling and completion, permitting, staking and water management plans for the 2008 and 2009 drilling programs, infrastructure upgrades and well repairs. We drilled 15 wells in the PRB during the quarter, bringing total wells drilled in 2008 to 36. Since the end of the second quarter we have drilled one additional well in the PRB.
As previously announced, during the quarter we acquired approximately 14,000 undeveloped net acres in Sheridan County, Wyoming. The acquisition acreage is located in and around our current operations in the PRB.
Fayetteville Shale
We invested $6.7 million in capital in our Fayetteville Shale project in the second quarter of 2008. During the quarter we drilled two additional wells, bringing our total operated wells drilled to the Fayetteville in the first half of 2008 to seven. Additionally with the commencement of transportation of gas from our acreage in early April of 2008, we turned our three 2007 wells to sales as well as three 2008 wells. The three 2008 wells (the Ballard 1-13H, the Owen 1-18H, and the Roberts 1-13H), had initial production potential of 1,341 thousand cubic feet per day (Mcf/d), 1,240 Mcf/d and 1,177 Mcf/d respectively. Since the end of the quarter we have also commenced sales from the Vaughan 2-18, a shallow well completed in a gas-charged zone observed in the Vaughan 1-18H well, with initial production potential of 500 Mcf/d. Finally, both the Files 2-12H and the Files 3-12H, the two wells drilled and completed in the second quarter, are cleaning up post fracture and are pending sales.
Since the end of the second quarter we have commenced drilling operations on five additional Fayetteville wells. These five wells are in various stages of drilling and completion.
Elk Valley, B.C.
In Elk Valley we have nine wells on production and continue to progress in our dewatering efforts. We remain encouraged by the gas rates we are observing and continue to have active discussions with third-party pipeline operators concerning the design and possible installation of a gas sales pipeline. Final pipeline engineering and cost estimates are anticipated to be completed within the next few weeks.
Financial schedules accompany this press release. Please reference the Company's Quarterly Report on Form 10-Q filed with the Securities and Exchange Commission and with Canadian securities regulators on SEDAR for important notes to the financial statements.
About Storm Cat Energy
Storm Cat Energy is an independent oil and gas company focused on the exploration, production and development of large unconventional gas reserves from fractured shales, coal beds and tight sand formations and, secondarily, from conventional formations. The Company has producing properties in Wyoming's Powder River Basin and Arkansas' Arkoma Basin and exploration and development acreage in Canada. The Company's shares trade on the American Stock Exchange under the symbol "SCU" and in Canada on the Toronto Stock Exchange under the symbol "SME."
Forward-looking Statements
This press release contains certain "forward-looking statements", as defined in the United States Private Securities Litigation Reform Act of 1995, and within the meaning of Canadian securities legislation, relating to potential future production and growth, proposed new wells and infrastructure improvements affecting the Company's operations. Forward-looking statements are statements that are not historical facts; they are generally, but not always, identified by the words "expects," "plans," "anticipates," "believes," "intends, "estimates," "projects," "aims," "potential," "goal," "objective," "prospective," and similar expressions, or that events or conditions "will," "would," "may," "can," "could" or "should" occur. Forward-looking statements are based on the beliefs, estimates and opinions of Storm Cat's management on the date the statements are made and they involve a number of risks and uncertainties. Consequently, there can be no assurances that such statements will prove to be accurate and actual results and future events could differ materially from those anticipated in such statements. Storm Cat undertakes no obligation to update these forward-looking statements if management's beliefs, estimates or opinions, or other factors, should change. Factors that could cause future results to differ materially from those anticipated in these forward-looking statements include, but are not limited to, noncompliance with the covenants in our credit agreement and the ability of our lenders to accelerate our indebtedness under the credit facility, the volatility of natural gas prices, the possibility that exploration efforts will not yield economically recoverable quantities of gas, accidents and other risks associated with gas exploration and development operations, the risk that the Company will encounter unanticipated geological factors, the Company's need for and ability to obtain additional financing, the possibility that the Company may not be able to secure permitting and other governmental clearances necessary to carry out the Company's exploration and development plans, and the other risk factors discussed in greater detail in the Company's various filings on SEDAR (http://www.sedar.com) with Canadian securities regulators and its filings with the U.S. Securities and Exchange Commission, including the Company's Form 10-K for the fiscal year ended December 31, 2007.
CONSOLIDATED BALANCE SHEETS
(Stated in U.S. Dollars and in thousands, except share amounts)
June 30, December 31,
2008 2007
(Unaudited) (Audited)
ASSETS
CURRENT ASSETS:
Cash and cash equivalents $2,068 $1,133
Accounts receivable:
Joint interest billing 3,053 1,701
Revenue receivable 3,792 2,444
Fair value of derivative instruments - 1,760
Prepaid costs and other current assets 2,224 2,941
Total current assets 11,137 9,979
PROPERTY AND EQUIPMENT (full cost method),
at cost:
Oil and gas properties:
Unproved properties 57,043 51,438
Proved properties 100,283 78,096
Less accumulated depreciation, depletion,
and amortization (17,038) (12,228)
Oil and gas properties, net 140,288 117,306
Other property 1,149 1,180
Less accumulated depreciation (926) (778)
Total other property, net 223 402
Total property and equipment, net 140,511 117,708
OTHER NON-CURRENT ASSETS:
Restricted cash 168 685
Debt issuance costs, net of accumulated
amortization of $2,686 and $1,988,
respectively 2,963 3,435
Accounts receivable long-term - 759
Total other non-current assets 3,131 4,879
Total assets $154,779 $132,566
LIABILITIES AND SHAREHOLDERS' EQUITY
CURRENT LIABILITIES:
Accounts payable $10,588 $5,825
Revenue payable 3,191 1,678
Accrued and other liabilities 8,090 4,131
Interest payable - 12
Share-based payments liability 609 394
Fair value of derivative instruments 11,708 -
Bank debt 64,625 -
Total current liabilities 98,811 12,040
NON-CURRENT LIABILITIES:
Bank debt - 43,056
Ad valorem taxes payable 852 -
Asset retirement obligation 1,844 1,713
Fair value of derivative instruments 2,839 183
Convertible notes payable 50,195 50,195
Total non-current liabilities 55,730 95,147
Total liabilities 154,541 107,187
Commitments and Contingencies
SHAREHOLDERS' EQUITY:
Common shares, without par value, unlimited
authorized, issued and outstanding: 81,278,549
at June 30, 2008 and 81,087,320 at December 31,
2007 69,834 69,834
Additional paid-in capital 6,028 5,640
Accumulated other comprehensive income
(loss) (9,709) 7,483
Accumulated deficit (65,915) (57,578)
Total shareholders' equity 238 25,379
Total liabilities and shareholders'
equity $154,779 $132,566
CONSOLIDATED STATEMENTS OF OPERATIONS
(Stated in U.S. Dollars and in thousands, except share and per share amounts)
Three Months Ended Six Months Ended
June 30 June 30
2008 2007 2008 2007
NATURAL GAS REVENUE $6,550 $3,668 $12,567 $7,580
OPERATING EXPENSES:
Gathering and
transportation 1,340 398 2,143 958
Lease operating expenses 2,407 1,256 4,810 2,159
General and
administrative 1,819 3,491 3,536 6,152
Depreciation, depletion,
amortization and
accretion of asset
retirement obligation 2,856 1,879 5,018 3,513
Total operating expenses 8,422 7,024 15,507 12,782
Operating loss (1,872) (3,356) (2,940) (5,202)
OTHER INCOME (EXPENSE):
Interest expense (2,462) (1,519) (4,731) (2,148)
Interest and other
miscellaneous income 52 101 32 133
Amortization of deferred
financing costs
(411) - (698) -
Total other income
(expense) (2,821) (1,418) (5,397) (2,015)
Loss before taxes (4,693) (4,774) (8,337) (7,217)
Recovery of future income
tax asset from
flow-through shares - 182 - 1,278
NET LOSS $(4,693) $(4,592) $(8,337) $(5,939)
Basic and diluted loss
per share $(0.06) $(0.06) $(0.10) $(0.07)
Weighted average number
of shares outstanding 81,214,884 81,045,122 81,151,150 80,816,505
CONSOLIDATED STATEMENT OF CASH FLOWS
(Stated in U.S. Dollars and in thousands)
Six Months Ended
June 30,
2008 2007
Cash flows from operating activities:
Net loss $(8,337) $(5,939)
Adjustments to reconcile net loss to net
cash provided by (used in) operating activities:
Recovery of future income tax asset from
flow-through shares
- (1,252)
Share-based payments 625 1,161
Depreciation, depletion, amortization and
accretion of asset retirement obligation 5,018 3,521
Amortization of debt issuance costs 698 -
Changes in operating assets and liabilities:
Accounts receivable (2,694) (761)
Other current assets 700 381
Accounts payable 257 (2,674)
Accrued interest and other current
liabilities 5,103 (1,461)
Net cash provided by (used in) operating
activities 1,370 (7,024)
Cash flows from investing activities:
Restricted cash 1,264 (8)
Capital expenditures - oil and gas properties (22,801) (32,386)
Capital expenditures - other assets 21 (23)
Net cash used in investing activities (21,516) (32,417)
Cash flows from financing activities:
Issuance of common stock - 914
Debt issuance costs - (3,556)
Proceeds from (repayment of) bank debt 21,569 (13,278)
Proceeds from convertible notes payable - 50,194
Net cash provided by financing activities 21,569 34,274
Effect of exchange rate changes on cash (488) 883
Net decrease in cash and cash equivalents 935 (4,284)
Cash and cash equivalents at beginning of period 1,133 5,299
Cash and cash equivalents at end of period $2,068 $1,015
Supplemental disclosure of cash flow
information:
Cash paid for interest $5,224 $2,449
Supplemental disclosure of non-cash investing
and financing activities:
Capital accruals and asset additions $13,566 $6,700
Increase in asset retirement obligation $89 $(284)
Change in fair value derivatives $(16,123) $(1,360)
RECONCILIATION OF NET LOSS TO ADJUSTED EBITDA
(Stated in U.S. Dollars and in thousands)
Three Months Ended
June 30,
2008 2007
Net loss $(4,693) $(4,774)
Depreciation, depletion, amortization and
accretion 2,856 1,879
Interest Expense 2,410 1,418
Income Taxes - (182)
Amortization of Debt Issuance Costs 411 -
EBITDA 984 (1,659)
Stock-based compensation expense 351 742
Adjusted EBITDA(1)(3) $1,335 $(917)
Six Months Ended
June 30,
2008 2007
Net loss $(8,337) $(5,939)
Depreciation, depletion, amortization and
accretion 5,018 3,513
Interest Expense 4,699 2,015
Income Taxes - (1,278)
Amortization of Debt Issuance Costs 698 -
EBITDA 2,078 (1,689)
Stock-based compensation expense 617 1,189
Adjusted EBITDA(1)(3) $2,695 $(500)
RECONCILIATION OF OPERATING LOSS TO OPERATING CASH FLOW
(Stated in U.S. Dollars and in thousands)
Three Months Ended
June 30,
2008 2007
Operating loss $(1,872) $(3,356)
General and administrative 1,819 3,491
Depreciation, depletion, amortization and
accretion 2,856 1,879
Operating Cash Flow (2)(3) $2,803 $2,014
Six Months Ended
June 30,
2008 2007
Operating loss $(2,940) $(5,202)
General and administrative 3,536 6,152
Depreciation, depletion, amortization and
accretion 5,018 3,513
Operating Cash Flow (2)(3) $5,614 $4,463
(1) We have included Adjusted EBITDA (earnings before interest, taxes,
depreciation and amortization, and share-based compensation expense)
because we believe it provides investors with a useful industry
comparative and is a financial measure used by management to assess
the performance of our Company.
(2) We have included Operating Cash Flow (natural gas revenues less lease
operating expenses, gathering and transportation expenses and
production taxes) because we believe it provides useful information to
assess our performance and to measure our cash flows from operations
for our investors.
(3) We believe EBITDA, Adjusted EBITDA and Operating Cash Flow provide
useful measures of cash flows from operations for our investors
because EBITDA, Adjusted EBITDA and Operating Cash Flow are industry
comparative measures of cash flows generated by our operations and
because they are financial measures used by management to assess the
performance and liquidity of our Company. EBITDA, Adjusted EBITDA and
Operating Cash Flow are not measurements of financial performance or
liquidity under accounting principles generally accepted in the United
States of America and should not be considered in isolation or
construed as a substitutes for net income (loss) or other operations
data or cash flow data prepared in accordance with accounting
principles generally accepted in the United States of America for
purposes of analyzing our profitability or liquidity. In addition,
not all funds depicted by EBITDA, Adjusted EBITDA and Operating Cash
Flow are available for management's discretionary use. For example, a
portion of such funds are subject to contractual restrictions and
functional requirements to pay debt service, fund necessary capital
expenditures and meet other commitments from time to time as described
in more detail in the Company's 2007 Annual Report on Form 10-K filed
with the Securities and Exchange Commission on March 17, 2008.
EBITDA, Adjusted EBITDA and Operating Cash Flow, as calculated, may
not be comparable to similarly titled measures reported by other
companies.
SOURCE Storm Cat Energy Corporation
For further information: William Kent, Director, Investor Relations of Storm Cat Energy Corporation, +1-303-991-5070
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