Crocotta Energy Inc.
TSX : CTA

Crocotta Energy Inc.

November 12, 2007 06:00 ET

Crocotta Energy Inc.: Q3 2007 Financial and Operating Results

CALGARY, ALBERTA--(Marketwire - Nov. 12, 2007) - CROCOTTA ENERGY INC. (TSX:CTA) is pleased to announce its financial and operating results for the three and nine months ended September 30, 2007, including consolidated financial statements, notes to the consolidated financial statements, and Management's Discussion and Analysis. All dollar figures are Canadian dollars unless otherwise noted.

HIGHLIGHTS

- Subsequent to quarter-end, Crocotta closed a business combination with Diamond Tree Energy Ltd. ("Diamond Tree") by way of plan of arrangement (the "Arrangement"). The Arrangement is expected to add an additional 1,500 boe/d of production to Crocotta's current production base. In conjunction with the Arrangement, Crocotta raised $31.5 million through the exercise of put and call financing arrangements in existence at September 30, 2007.

- Subsequent to quarter-end, Crocotta increased its operating demand loan credit facility to $34.0 million.



Three Months Ended Nine Months Ended
FINANCIAL (1) September 30, 2007 September 30, 2007
----------------------------------------------------------------------------
($, except where noted)
Oil and natural gas sales 2,586,960 4,384,367

Funds from operations 1,156,608 1,408,541
per share - basic and diluted (2) 0.07 0.12

Net earnings (loss) (259,013) (215,784)
per share - basic and diluted (2) (0.02) (0.02)

Capital expenditures 5,737,295 9,387,137

Corporate acquisition 30,198,858

Net cash and working capital 3,847,826

Common shares outstanding (2)
weighted average - basic 16,845,369 11,717,097
- diluted 17,059,090 11,910,636

end of period - basic 16,845,369
- diluted 28,330,788

(1) There are no comparative numbers as the Company began active oil and
natural gas operations on November 15, 2006.

(2) On October 12, 2007, the Company consolidated its common shares on a
three-to-one basis. As a result, common shares outstanding and per share
amounts are disclosed on a post-consolidated basis.

----------------------------------------------------------------------------
Three Months Ended Nine Months Ended
OPERATING (1) September 30, 2007 September 30, 2007
----------------------------------------------------------------------------

Number of producing days 92 273

Daily production
Oil and liquids - (bbls/d) 228 128
Natural gas - (mcf/d) 2,107 1,138
----------------------------------------------------------------------------
Oil equivalent - (boe/d @ 6:1) 579 318

Revenue, net of transportation
Oil and liquids - ($/bbl) 69.20 67.48
Natural gas - ($/mcf) 5.62 6.26
----------------------------------------------------------------------------
Oil equivalent - ($/boe @ 6:1) 47.69 49.64

Royalties
Oil and liquids - ($/bbl) 11.71 9.44
Natural gas - ($/mcf) 0.73 0.98
----------------------------------------------------------------------------
Oil equivalent - ($/boe @ 6:1) 7.27 7.31

Production expenses
Oil and liquids - ($/bbl) 9.28 9.24
Natural gas - ($/mcf) 1.18 1.26
----------------------------------------------------------------------------
Oil equivalent - ($/boe @ 6:1) 7.95 8.24

Operating netback
Oil and liquids - ($/bbl) 48.21 48.80
Natural gas - ($/mcf) 3.71 4.02
----------------------------------------------------------------------------
Oil equivalent - ($/boe @ 6:1) 32.47 34.09

(1) There are no comparative numbers as the Company began active oil and
natural gas operations on November 15, 2006.



Management's Discussion and Analysis

November 9, 2007

Crocotta Energy Inc. ("Crocotta" or the "Company") is an emerging oil and natural gas company, actively engaged in the acquisition, development, exploration, and production of oil and natural gas reserves in Western Canada. Crocotta commenced trading on the Toronto Stock Exchange ("TSX") on October 17, 2007 under the symbol "CTA".

On August 16, 2005, Donner Minerals Ltd., the predecessor to the Company, completed a reorganization, by way of statutory plan of arrangement, and restructured into two separate companies, Donner Metals Ltd. and Donner Minerals Ltd., which changed its name to Donner Petroleum Ltd. and subsequently to Crocotta Energy Inc. On November 14, 2006, the Company appointed a new board of directors and hired a new management team consisting of the previous directors and officers of Chamaelo Exploration Ltd. ("Chamaelo"). On November 15, 2006, the Company commenced active oil and natural gas operations with the acquisition of certain oil and natural gas properties from Chamaelo.

Effective December 31, 2006, the Company changed its fiscal year-end from February 28 to December 31. As a result, the consolidated financial statements for the three and nine months ended September 30, 2007 and the disclosure throughout the Management's Discussion and Analysis ("MD&A") reflect Crocotta's overall company results for the three and nine months ended September 30, 2007, with comparative results for the three and nine months ended August 31, 2006.

The MD&A should be read in conjunction with the unaudited interim consolidated financial statements for the three and nine months ended September 30, 2007 and the audited consolidated financial statements for the 10-month period ended December 31, 2006. The unaudited interim consolidated financial statements and financial data contained in the MD&A have been prepared in accordance with Canadian generally accepted accounting principles ("Canadian GAAP") in Canadian currency (except where noted as being in another currency).

BOE Conversions

Barrel of oil equivalent ("boe") amounts have been calculated using a conversion rate of six thousand cubic feet of natural gas to one barrel of oil ("6:1") unless otherwise stated. The term "boe" may be misleading, particularly if used in isolation. A boe conversion rate of six thousand cubic feet of natural gas to one barrel of oil equivalence is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead.

Forward-Looking Information

This MD&A may contain forward-looking information that involves a number of risks and uncertainties that could cause actual results to differ materially from those anticipated. For this purpose, any statements herein that are not statements of historical fact may be deemed to be forward-looking statements. Such risks and uncertainties include, but are not limited to: risks associated with the oil and natural gas industry (e.g. - operational risks in exploration, development and production; changes and/or delays in the development of capital assets; uncertainty of reserve estimates; uncertainty of estimates and projections relating to production and costs; commodity price fluctuations; environmental risks; and industry competition).

Non-GAAP Measures

Funds from operations and operating netback as presented do not have any standardized meaning prescribed by Canadian GAAP and therefore may not be comparable to similar measures used by other companies. The determination of funds from operations is detailed on the Consolidated Statements of Cash Flows and is determined before changes in non-cash working capital. Operating netback, which is calculated as average unit sales price less royalties, production expenses, and transportation expenses, represents the cash margin for every barrel of oil equivalent sold.



Three Months Ended Nine Months Ended
Summary of Financial Results (1) September 30, 2007 September 30, 2007
----------------------------------------------------------------------------
$ $
Oil and natural gas sales 2,586,960 4,384,367

Funds from operations 1,156,608 1,408,541
per share - basic and diluted (2) 0.07 0.12

Net earnings (259,013) (215,784)
per share - basic and diluted (2) (0.02) (0.02)

Total assets 58,399,353

Net cash and working capital 3,847,826

Total long-term liabilities 994,009

(1) There are no comparative numbers as the Company began active oil and
natural gas operations on November 15, 2006.

(2) On October 12, 2007, the Company consolidated its common shares on a
three-to-one basis. As a result, common shares outstanding and per share
amounts are disclosed on a post-consolidated basis.


Crocotta Energy Inc.

Management's Discussion & Analysis

Three and nine months ended September 30, 2007



----------------------------------------------------------------------------
Production Three Months Ended Nine Months Ended
September 30, 2007 September 30, 2007
----------------------------------------------------------------------------
Average Daily Production
Oil and liquids (bbls/d) 228 128
Natural gas (mcf/d) 2,107 1,138
----------------------------------------------------------------------------
Total (boe/d) 579 318
----------------------------------------------------------------------------
----------------------------------------------------------------------------


For the three months ended September 30, 2007, crude oil and natural gas liquids production averaged 228 bbls/d and natural gas production averaged 2,107 mcf/d. On a combined basis, average daily production totaled 579 boe/d for the three months ended September 30, 2007. Year-to-date, crude oil and natural gas liquids production averaged 128 bbls/d and natural gas production averaged 1,138 mcf/d. On a combined basis, average daily production totaled 318 boe/d for the nine months ended September 30, 2007.

Production increased 312 boe/d or 117% in Q3 2007 over Q2 2007 (267 boe/d) as a result of the Company having a full quarter of production from the properties acquired through the Plan of Arrangement with Eastshore Energy Ltd. ("Eastshore") that closed on June 8, 2007. The Company anticipates to have a significant increase in Q4 2007 production as a result of the acquisition of Diamond Tree Energy Ltd. ("Diamond Tree") subsequent to September 30, 2007, which is expected to add an additional 1,500 boe/d to Q3 2007 production levels.



Revenue Three Months Ended Nine Months Ended
September 30, 2007 September 30, 2007
----------------------------------------------------------------------------
$ $
Oil and liquids 1,471,968 2,395,549
Natural gas 1,114,992 1,988,818
----------------------------------------------------------------------------
Total revenue 2,586,960 4,384,367
Transportation expenses (46,924) (75,390)
----------------------------------------------------------------------------
Total revenue, net of
transportation 2,540,036 4,308,977
----------------------------------------------------------------------------
----------------------------------------------------------------------------

Average Sales Price
----------------------------------------------------------------------------
Oil and liquids ($/bbl) 70.21 68.38
Natural gas ($/mcf) 5.75 6.40
----------------------------------------------------------------------------
Average sales price ($/boe) 48.57 50.51
Transportation expenses ($/boe) (0.88) (0.87)
----------------------------------------------------------------------------
Average sales price ($/boe), net
of transportation 47.69 49.64
----------------------------------------------------------------------------
----------------------------------------------------------------------------


Revenue, before transportation, totaled $2,586,960 for the three months ended September 30, 2007 and $4,384,367 for the nine months ended September 30, 2007. Revenue increased $1,321,264 or 104% in Q3 2007 over Q2 2007 ($1,265,696) as a result of the Plan of Arrangement with Eastshore that closed on June 8, 2007. On a per unit basis, revenue decreased 6.9% to $48.57/boe in Q3 2007 from $52.17/boe in Q2 2007 mainly due to a decrease in natural gas prices combined with a significant increase in natural gas production as a result of the Plan of Arrangement with Eastshore.

Currently, the Company sells all its oil, natural gas liquids, and natural gas on the spot market. Future prices received from the sale of oil, natural gas liquids, and natural gas may fluctuate as the result of market factors. The Company did not hedge any of its oil, natural gas liquids, or natural gas production for the period.

The following table outlines the Company's realized wellhead prices and industry benchmarks for the three and nine month periods ended September 30, 2007:



Commodity Pricing Three Months Ended Nine Months Ended
September 30, 2007 September 30, 2007
----------------------------------------------------------------------------
$US $Cdn $US $Cdn
Oil and liquids
Corporate Price ($/bbl) 70.21 68.38
West Texas Intermediate ($/bbl) 75.38 66.10
Edmonton Par ($/bbl) 80.70 73.69

Natural gas
Corporate Price ($/mcf) 5.75 6.40
AECO Daily Spot Price ($/mcf) 5.17 6.55

Exchange Rates
U.S./Cdn Dollar Average Exchange Rate 0.9567 0.9070
----------------------------------------------------------------------------
----------------------------------------------------------------------------


Corporate average oil and natural gas liquids prices were 87.0% and 92.8% of Edmonton Par price for the three and nine months ended September 30, 2007, respectively. Corporate average natural gas prices were 111.2% and 97.7% of AECO Daily Spot price for the three and nine months ended September 30, 2007, respectively. A difference can be the result of quality (higher or lower API, higher or lower heat content), sour content, natural gas liquids included in reporting, and various other factors. Crocotta's differences are mainly as a result of lower priced natural gas liquids included in oil price reporting and higher heat content natural gas production that is priced higher than AECO Daily Spot. Note that these differences change on a monthly basis pending demand for each particular product.



Transportation Expenses Three Months Ended Nine Months Ended
September 30, 2007 September 30, 2007
----------------------------------------------------------------------------
Oil and liquids ($/bbl) 1.01 0.90
Natural gas ($/mcf) 0.13 0.14
----------------------------------------------------------------------------
Total ($/boe) 0.88 0.87
----------------------------------------------------------------------------
----------------------------------------------------------------------------


Transportation expenses are third-party pipeline tariffs and trucking costs incurred to deliver the products to the purchasers at main hubs. The Company expects to have industry average transportation costs, as the current production and capital expenditure plans are located in West Central Alberta, Southern Alberta, and Northeast British Columbia.



Royalties Three Months Ended Nine Months Ended
September 30, 2007 September 30, 2007
----------------------------------------------------------------------------
$ $
Oil and liquids 245,602 330,791
Natural gas 141,625 304,208
----------------------------------------------------------------------------
Total royalties 387,227 634,999
----------------------------------------------------------------------------
----------------------------------------------------------------------------

Average Royalty Rate (% of sales)
----------------------------------------------------------------------------
Oil and liquids 16.7 13.8
Natural gas 12.7 15.3
----------------------------------------------------------------------------
Average royalty rate 15.0 14.5
----------------------------------------------------------------------------
----------------------------------------------------------------------------


Crude oil, natural gas liquids, and natural gas royalties totaled $387,227 for the three months ended September 30, 2007. Year-to-date, crude oil, natural gas liquids, and natural gas royalties totaled $634,999. For the three and nine months ended September 30, 2007, the overall effective royalty rates were 15.0 percent and 14.5 percent, respectively, of the Company's total revenue from the sale of crude oil, natural gas liquids, and natural gas. The low oil and natural gas liquids and natural gas royalty rates are due to a portion of the Company's oil and natural gas production being on a Crown royalty holiday. The Company expects its oil and natural gas royalties to increase in Q4 2007 as a result of the expiry of certain natural gas royalty holidays at the end of August 2007 and the addition of properties acquired from Diamond Tree subsequent to September 30, 2007.



Production Expenses Three Months Ended Nine Months Ended
September 30, 2007 September 30, 2007
----------------------------------------------------------------------------

Oil and liquids ($/bbl) 9.28 9.24
Natural gas ($/mcf) 1.18 1.26
----------------------------------------------------------------------------
Total ($/boe) 7.95 8.24
----------------------------------------------------------------------------
----------------------------------------------------------------------------


Per unit production expenses for the three months ended September 30, 2007 were $7.95/boe ($9.28/bbl of oil and natural gas liquids and $1.18/mcf of natural gas). Year-to-date, per unit production expenses were $8.24/boe ($9.24/bbl of oil and natural gas liquids and $1.26/mcf of natural gas). Production expenses decreased by $1.12/boe or 12.3% in Q3 2007 from $9.07/boe in Q2 2007. Crocotta recognizes that controlling operating costs plays an integral role in the effective exploitation of reserves typically found today in the Western Canadian Sedimentary Basin. Crocotta is committed to focusing efforts on opportunities that will improve operational efficiencies and reduce per boe production expenses to enhance netbacks.



----------------------------------------------------------------------------
Operating Netback Three Months Ended Nine Months Ended
September 30, 2007 September 30, 2007
----------------------------------------------------------------------------
Oil and liquids ($/bbl)
Revenue 70.21 68.38
Royalties 11.71 9.44
Production expenses 9.28 9.24
Transportation expenses 1.01 0.90
----------------------------------------------------------------------------
Operating netback 48.21 48.80
----------------------------------------------------------------------------
----------------------------------------------------------------------------

----------------------------------------------------------------------------
Natural gas ($/mcf)
Revenue 5.75 6.40
Royalties 0.73 0.98
Production expenses 1.18 1.26
Transportation expenses 0.13 0.14
----------------------------------------------------------------------------
Operating netback 3.71 4.02
----------------------------------------------------------------------------
----------------------------------------------------------------------------

----------------------------------------------------------------------------
Combined ($/boe) (6:1)
Revenue 48.57 50.51
Royalties 7.27 7.31
Production expenses 7.95 8.24
Transportation expenses 0.88 0.87
----------------------------------------------------------------------------
Operating netback 32.47 34.09
----------------------------------------------------------------------------
----------------------------------------------------------------------------


The operating netback is a key indicator of an exploration and production company's ability to generate cash flow for reinvestment. For the three months ended September 30, 2007, Crocotta generated an operating netback of $32.47/boe. Year-to-date, Crocotta generated and operating netback of $34.09/boe.

The operating netback decreased $2.30/boe or 6.6% in Q3 2007 from $34.77/boe in Q2 2007. The decrease was mainly as a result of a decrease in natural gas prices during the quarter.



General and Administrative Three Months Ended Nine Months Ended
Expenses ("G&A") September 30, 2007 September 30, 2007
----------------------------------------------------------------------------
$ $
G&A expenses (gross) 792,726 2,245,892
G&A capitalized (95,378) (295,742)
G&A recoveries (51,788) (100,717)
----------------------------------------------------------------------------
G&A expenses (net) 645,560 1,849,433
----------------------------------------------------------------------------
G&A expenses ($/boe) 12.12 21.30
----------------------------------------------------------------------------
----------------------------------------------------------------------------


G&A totaled $645,560 or $12.12/boe for the three months ended September 30, 2007 and $1,849,433 or $21.30/boe for the nine months ended September 30, 2007. G&A expenses decreased $13.97/boe or 53.5% in Q3 2007 from $26.09/boe in Q2 2007 due to higher production in the quarter which resulted from the acquisition of Eastshore on June 8, 2007. The Company expects per-unit G&A costs will decline significantly again in Q4 2007 as production levels will include production from the assets acquired from Diamond Tree subsequent to September 30, 2007.



Interest Three Months Ended Nine Months Ended
September 30, 2007 September 30, 2007
----------------------------------------------------------------------------
$ $
Interest income 72,855 302,261
Interest expense - (2,705)
----------------------------------------------------------------------------
Interest income (net) 72,855 299,556
----------------------------------------------------------------------------
Interest income ($/boe) 1.37 3.45
----------------------------------------------------------------------------
----------------------------------------------------------------------------


Interest income totaled $72,855 for the three months ended September 30, 2007, or $1.37/boe. Year-to-date, interest income totaled $299,556 or $3.45/boe. Interest income amounts related to interest earned on funds raised through the November 2006 and May 2007 private placement issuances.



Depletion, Depreciation and Three Months Ended Nine Months Ended
Accretion ("DD&A") September 30, 2007 September 30, 2007
----------------------------------------------------------------------------

DD&A ($) 1,387,326 2,278,486
DD&A ($/boe) 26.05 26.25
----------------------------------------------------------------------------
----------------------------------------------------------------------------


DD&A expense totaled $1,387,326 for the three months ended September 30, 2007 or $26.05/boe. Year-to-date, DD&A expense totaled $2,278,486 or $26.25/boe. As at September 30, 2007, the cost of oil and natural gas properties includes approximately $8,653,000 relating to properties from which there is no production and no reserves assigned and which have been excluded from costs subject to depletion and depreciation. Included in the provision for DD&A for the three and nine months ended September 30, 2007, respectively, are $18,449 ($0.35/boe) and $55,348 ($0.64/boe) for depreciation of office and other equipment and $17,500 ($0.33/boe) and $27,572 ($0.32/boe) for accretion of asset retirement obligations.



Stock-based Compensation Three Months Ended Nine Months Ended
September 30, 2007 September 30, 2007
----------------------------------------------------------------------------

Stock-based compensation ($) 28,295 73,159
Stock-based compensation ($/boe) 0.53 0.84
----------------------------------------------------------------------------
----------------------------------------------------------------------------


For the three and nine months ended September 30, 2007, stock-based compensation expense totaled $28,295 or $0.53/boe and $73,159 or $0.84/boe, respectively. During the nine months ended September 30, 2007, 928,333 stock options and 2,404,000 warrants were issued to directors, officers, and employees of the Company.

Taxes

At September 30, 2007, the Company had approximately $78.4 million in tax pools, losses, and share issue costs.



September 30, 2007
----------------------------------------------------------------------------
$
Canadian oil and gas property expense (COGPE) 12,932,864
Canadian development expense (CDE) 13,294,182
Canadian exploration expense (CEE) 35,649,836
Undepreciated capital costs (UCC) 7,923,154
Non-capital losses carried forward 3,434,139
Capital losses carried forward 3,416,617
Share issue costs 1,759,098
----------------------------------------------------------------------------
Total pools, losses, and share issue costs 78,409,890
----------------------------------------------------------------------------
----------------------------------------------------------------------------


During the nine months ended September 30, 2007, the Company had a future income tax recovery of $727,320 relating to the renunciation of approximately $2.5 million in flow-through share obligations.

Funds from Operations and Net Earnings

Funds from operations for the three and nine months ended September 30, 2007 were $1,156,608 ($0.07 per share) and $1,408,541 ($0.12 per share), respectively. Net loss for the three months ended September 30, 2007 totaled $259,013 ($0.02 per share) and net loss for the nine months ended September 30, 2007 totaled $215,784 ($0.02 per share).

Capital Expenditures

On June 8, 2007, the Company closed a Plan of Arrangement whereby it acquired all of the issued and outstanding shares of Eastshore Energy Ltd. The following table details the purchase price allocation for the business combination:



Net assets acquired Amount ($)
----------------------------------------------------------------------------
Oil and natural gas properties and equipment 34,604,212
Working capital deficit (3,698,673)
Asset retirement obligation (706,681)
----------------------------------------------------------------------------
30,198,858
----------------------------------------------------------------------------
----------------------------------------------------------------------------

Consideration of acquisition
----------------------------------------------------------------------------
Cash 8,480,289
Issuance of 5,748,702 common shares 21,557,633
Transaction costs 160,936
----------------------------------------------------------------------------
30,198,858
----------------------------------------------------------------------------
----------------------------------------------------------------------------


The net cash consideration for the business combination was $13,507,132, comprised of the original $8,480,289 cash, transaction costs of $160,936, and a negative cash balance of $4,865,907 acquired from Eastshore.

Net cash payments for capital expenditures are as follows:



Three Months Ended Nine Months Ended
September 30, 2007 September 30, 2007
----------------------------------------------------------------------------
$ $
Land 3,525,467 3,553,193
Drilling, completions and
workovers 1,882,932 4,410,622
Equipment 93,061 676,859
Geological and geophysical 235,835 746,463
----------------------------------------------------------------------------
5,737,295 9,387,137
----------------------------------------------------------------------------
----------------------------------------------------------------------------


During the quarter, Crocotta recompleted 2 (1.5 net) wells resulting in 1 (0.5 net) oil well and 1 (1.0 net) natural gas well. The recompleted oil well was tied in during the quarter, while the natural gas well is expected to be tied in during the fourth quarter of 2007. Year-to-date, the Company drilled 3 (1.8 net) wells, resulting in 1 (0.50 net) gas well, 1 (0.8 net) oil well, and 1 (0.5 net) uneconomical well.

Liquidity and Capital Resources

Net cash and working capital was $3,847,826 at September 30, 2007.

Subsequent to September 30, 2007, the Company consolidated its common shares on a three-to-one basis. As a result, all common share amounts below are disclosed on a post-consolidated basis.

On June 5, 2007, approximately 2.0 million series I special voting shares were exercised for common shares for proceeds of approximately $6.1 million. The outstanding series I special voting shares related to a put and call financing arrangement from November 2006. Upon exercise, the series I special voting shares were cancelled. Subsequent to September 30, 2007, the Company filed articles of amendment to cancel the special voting shares.

On June 8, 2007, the Company closed a Plan of Arrangement whereby it acquired all of the issued and outstanding shares of Eastshore Energy Ltd.

On June 13, 2007, Crocotta issued approximately 1.1 million common shares on a flow-through basis at a price of $4.65 per share for gross proceeds of approximately $5.0 million. Crocotta also entered into put and call financing arrangements to issue approximately 5.1 million common shares priced at $3.75 per share for proceeds of $19.0 million. The put and call financing arrangements were exercised subsequent to September 30, 2007.

Crocotta has a revolving operating demand loan credit facility available up to $14.5 million bearing interest at prime plus 0.125% with a Canadian bank. The credit facility is secured by a $35 million fixed and floating charge debenture on the assets of the Company and its 100% wholly-owned subsidiary. Subsequent to quarter-end, the Company increased its available line to $34.0 million. The increased credit facility bears interest at prime plus a range of 0% to 1.50% and is secured by a $75 million fixed and floating charge debenture on the assets of the Company and its 100% wholly-owned subsidiaries.

During the quarter, Crocotta entered into a put and call financing arrangement with two institutional investors to issue approximately 3.1 million common shares priced at $4.05 per share for gross proceeds of approximately $12.5 million. Subsequent to quarter-end, the put and call financing arrangements were exercised.

Subsequent to quarter-end, the Company closed a business combination with Diamond Tree Energy Ltd. ("Diamond Tree"), a public oil and natural gas company listed on the TSX, by plan of arrangement. Crocotta acquired approximately 1,500 boe/d of production for aggregate consideration of approximately $67.4 million, payable through the issuance of approximately 8.1 million common shares at an assumed price of $4.05 per share and the assumption of existing debt and working capital estimated to be $35.0 million.

The Company anticipates it will make substantial capital expenditures for the acquisition, exploration, development and production of oil and natural gas reserves in the future. The Company will utilize current cash reserves, internally generated cash flow from operations, debt where deemed appropriate, and equity financing if market conditions are favourable to finance its capital expenditures.



Summary of Quarterly Results (1)
Q4 2006 Q1 2007 Q2 2007 Q3 2007
----------------------------------------------------------------------------

Number of producing days 47 90 91 92

$ $ $ $
----------------------------------------------------------------------------

Oil and natural gas sales 290,243 531,711 1,265,696 2,586,960

Funds from operations (194,807) (70,887) 322,820 1,156,608
per share - basic and diluted (0.05) - 0.01 0.07

Net earnings (loss) (436,321) 381,942 (338,713) (259,013)
per share - basic and diluted (0.12) 0.02 (0.01) (0.02)
----------------------------------------------------------------------------
----------------------------------------------------------------------------

(1) There are not eight quarters of information disclosed as the Company
began active oil and natural gas operations on November 15, 2006. As
such, the disclosure reflects only those periods with active oil and
natural gas operations.
Results from oil and natural gas activities for Q4 2006 take into
account only the 47-day period from November 15, 2006 to December 31,
2006.


Outstanding Share Data

The Company is authorized to issue an unlimited number of voting common shares, an unlimited number of non-voting common shares, Class A and Class B preferred shares, issuable in series, and special voting shares, issuable in series. Subsequent to September 30, 2007, the outstanding voting common shares of the Company were consolidated on a three-to-one basis and the Company filed articles of amendment to cancel the special voting shares, issuable in series. The voting common shares of the Company commenced trading on the TSX on October 17, 2007 under the symbol "CTA". The following table summarizes the common shares outstanding and the number of shares exercisable into common shares from options, warrants, and other instruments:



September 30, 2007 November 9, 2007
----------------------------------------------------------------------------

Voting common shares 16,845,369 33,044,526
Options 928,333 928,333
Warrants 2,404,000 2,404,000
Outstanding Put and Call
Obligations (1) 8,153,086 -
----------------------------------------------------------------------------
Total 28,330,788 36,376,859
----------------------------------------------------------------------------
----------------------------------------------------------------------------

(1) See "Liquidity and Capital Resources" above.


Commitments

The Company is committed to payments under an operating lease for office space as follows:



Amount ($)
----------------------------------------------------------------------------
2007 149,415
2008 597,661
2009 597,661
2010 586,661
2011 488,884
----------------------------------------------------------------------------
2,420,282
----------------------------------------------------------------------------
----------------------------------------------------------------------------


Critical Accounting Policies and Significant Estimates

Management is required to make judgments, assumptions, and estimates in the application of Canadian GAAP that have a significant impact on the financial results of the Company. The following summarizes the accounting policies that are critical to determining the Company's financial results.

Full Cost Accounting - The Company follows the full cost method of accounting whereby all costs related to the acquisition of, exploration for, and development of oil and natural gas reserves are capitalized and charged against earnings. These costs, together with the estimated future costs to be incurred in developing proved reserves, are depleted or depreciated using the unit-of-production method based on the proved reserves before royalties as estimated by independent petroleum engineers. The costs of undeveloped properties are excluded from the costs subject to depletion and depreciation until it is determined whether proved reserves are attributable to the properties or impairment occurs. Reserve estimates can have a significant impact on earnings, as they are a key component in the calculation of depletion. A downward revision to the reserve estimate could result in higher depletion and thus lower net earnings. In addition, estimated reserves are also used in the calculation of the impairment (ceiling) test. Oil and natural gas properties are evaluated each reporting period through an impairment test to determine the recoverability of capitalized costs. The carrying amount is assessed as recoverable when the sum of the undiscounted cash flows expected from proved reserves plus the cost of unproved interests, net of impairments, exceeds the carrying amount. When the carrying amount is assessed not to be recoverable, an impairment loss is recognized to the extent that the carrying amount exceeds the sum of the discounted cash flows from proved and probable reserves plus the cost of unproved interests, net of impairments. The cash flows are estimated using expected future prices and costs and are discounted using a credit adjusted risk-free interest rate.

Proceeds from the sale of oil and natural gas properties are applied against capitalized costs, with no gain or loss recognized, unless such a sale would result in a change in the depletion rate of 20% or more.

Oil and Natural Gas Reserves - The Company's oil and natural gas reserves are evaluated and reported on by independent petroleum engineers. The estimates of reserves is a very subjective process as forecasts are based on engineering data, projected future rates of production, estimated future commodity prices and the timing of future expenditures, which are all subject to uncertainty and interpretation.

Asset Retirement Obligations - The Company is required to provide for future abandonment and site restoration costs. These costs are estimated based on existing laws, contracts or other policies. The obligations are initially measured at fair value and subsequently adjusted for the accretion of discount and any changes to the underlying cash flows. The asset retirement cost is capitalized to oil and natural gas properties and equipment and amortized into earnings on a basis consistent with depletion and depreciation. The estimate of future abandonment and site restoration costs involves estimates relating to the timing of abandonment, the economic life of the asset and the costs associated with abandonment and site restoration which are all subject to uncertainty and interpretation.

New Accounting Standards

Effective January 1, 2007, the Company adopted the Canadian Institute of Chartered Accountants ("CICA") Handbook Section 1530, Comprehensive Income, Section 3251, Equity, Section 3855, Financial Instruments - Recognition and Measurement, Section 3861, Financial Instruments - Disclosure and Presentation, and Section 3865, Hedges, retroactively with no restatement of prior periods.

The Company has evaluated the impact of these new standards and determined that the adoption of these standards has had no material impact on the Company's net earnings or cash flows. The other effects of the implementation of the new standards are discussed below.

Comprehensive Income

The new standards introduce comprehensive income, which consists of net earnings and other comprehensive income ("OCI"). Because the Company does not have any OCI, the Company's interim financial statements do not include a Statement of Comprehensive Income which would otherwise describe the components of comprehensive income. Accordingly, since there are no cumulative changes in OCI to be included in accumulated other comprehensive income ("AOCI"), the Company has not presented AOCI as a new category within shareholders' equity in the interim balance sheet and has not included a Statement of Accumulated Other Comprehensive Income, which would otherwise provide the continuity of the AOCI balance.

Financial Instruments

The financial instruments standard establishes the recognition and measurement criteria for financial assets, financial liabilities and derivatives. All financial instruments are required to be measured at fair value on initial recognition of the instrument, except for certain related party transactions. Measurements in subsequent periods depend on whether the financial instrument has been classified as "held-for-trading", "available-for-sale", "held-to-maturity", "loans and receivables", or "other financial liabilities" as defined by the standard.

Financial assets and financial liabilities classified as "held-for-trading" are measured at fair value with changes in those fair values recognized in net earnings. Financial assets classified as "available-for-sale" are measured at fair value, with changes in those fair values recognized in OCI. Financial assets classified as "held-to-maturity", "loans and receivables" and "other financial liabilities" are measured at amortized cost using the effective interest method of amortization. The methods used by the Company in determining fair value of financial instruments are unchanged as a result of implementing the new standard.

Cash and cash equivalents are designated as "held-for-trading" and are measured at carrying value, which approximates fair value due to the short-term nature of these instruments. Accounts receivable and deposits are designated as "loans and receivables" and accounts payable and accrued liabilities are designated as "other liabilities".

Risk management assets and liabilities are derivative financial instruments classified as "held-for-trading" unless designated for hedge accounting. The Company has no commodity financial contracts or fixed-price physical contracts in place at this time.

Section 1506 - Accounting Changes

Beginning January 1, 2007 the Company adopted Section 1506 "Accounting Changes," the only impact of which is to provide disclosure of when an entity has not applied a new source of GAAP that has been issued but is not yet effective. This is the case with Section 3862, Financial Instruments - Disclosures, Section 3863, Financial Instruments - Presentation, and Section 1535, Capital Disclosures, which are required to be adopted for fiscal years beginning on or after October 1, 2007. The Company will adopt these standards on January 1, 2008 and it is expected the only effect on the Company will be incremental disclosures regarding the significance of financial instruments for the entity's financial position and performance, the nature, extent and management of risks arising from financial instruments to which the entity is exposed, and the policies and processes the Company uses for managing its capital.

Risk Assessment

The acquisition, exploration, and development of oil and natural gas properties involves many risks common to all participants in the oil and natural gas industry. Crocotta's exploration and development activities are subject to various business risks such as unstable commodity prices, interest rate and foreign exchange fluctuations, the uncertainty of replacing production and reserves on an economic basis, government regulations, taxes and safety and environmental concerns. While the management of Crocotta realizes these risks cannot be eliminated, they are committed to monitoring and mitigating these risks. The Company currently does not have any commodity price, interest rate, or foreign exchange contracts in place.

Reserves and Reserve Replacement

The recovery and reserve estimates on Crocotta's properties are estimates only and the actual reserves may be materially different from that estimated. The estimates of reserve values are based on a number of variables including price forecasts, projected production volumes and future production and capital costs. All of these factors may cause estimates to vary from actual results.

Crocotta's future oil and natural gas reserves, production, and funds from operations to be derived therefrom are highly dependent on Crocotta successfully acquiring or discovering new reserves. Without the continual addition of new reserves, any existing reserves Crocotta may have at any particular time and the production therefrom will decline over time as such existing reserves are exploited. A future increase in Crocotta's reserves will depend on its abilities to acquire suitable prospects or properties and discover new reserves.

To mitigate this risk, Crocotta has assembled a team of experienced technical professionals who have expertise operating and exploring in areas which Crocotta has identified as being the most prospective for increasing Crocotta's reserves on an economic basis. To further mitigate reserve replacement risk, Crocotta has targeted a majority of its prospects in areas which have multi-zone potential, year-round access and lower drilling costs and employs advanced geological and geophysical techniques to increase the likelihood of finding additional reserves.

Operational Risks

Crocotta's operations are subject to the risks normally incidental to the operation and development of oil and natural gas properties and the drilling of oil and natural gas wells. Continuing production from a property, and to some extent the marketing of production therefrom, are largely dependent upon the ability of the operator of the property.

Commodity Price Risk

The Company's oil and natural gas production is marketed and sold on the spot market to area aggregators based on daily spot prices that are adjusted for product quality and transportation costs. The Company is exposed to foreign currency fluctuations as crude oil prices received are referenced to U.S. dollar denominated prices.

Safety and Environmental Risks

The oil and natural gas business is subject to extensive regulation pursuant to various municipal, provincial, national, and international conventions and regulations. Environmental legislation provides for, among other things, restrictions and prohibitions on spills, releases or emissions of various substances produced in association with oil and natural gas operations. Crocotta is committed to meeting and exceeding its environmental and safety responsibilities. Crocotta has implemented an environmental and safety policy that is designed, at a minimum to comply with current governmental regulations set for the oil and natural gas industry. Changes to governmental regulations are monitored to ensure compliance. Environmental reviews are completed as part of the due diligence process when evaluating acquisitions. Environmental and safety updates are presented and discussed at each Board of Directors meeting. Crocotta maintains adequate insurance commensurate with industry standards to cover reasonable risks and potential liabilities associated with its activities as well as insurance coverage for officers and directors executing their corporate duties. To the knowledge of management, there are no legal proceedings to which Crocotta is a party or of which any of its property is the subject matter, nor are any such proceedings known to Crocotta to be contemplated.

Disclosure Controls and Procedures and Internal Controls over Financial Reporting

The Company's President and Chief Executive Officer ("CEO") and Vice President Finance and Chief Financial Officer ("CFO") are responsible for establishing and maintaining disclosure controls and procedures and internal controls over financial reporting as defined in Multilateral Instrument 52-109 of the Canadian Securities Administrators.

Disclosure controls and procedures have been designed to ensure that information required to be disclosed by the Company is accumulated and communicated to management as appropriate to allow timely decisions regarding required disclosure. The Company evaluated its disclosure controls and procedures for the year ended December 31, 2006. The Company's CEO and CFO have concluded that, based on their evaluation, the Company's disclosure controls and procedures are effective to provide reasonable assurance that all material or potentially material information related to the Company is made known to them and is disclosed in a timely manner if required.

Internal controls over financial reporting have been designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with Canadian GAAP. No material changes in the Company's internal controls over financial reporting were identified during the most recent interim period that have materially affected, or are likely to material affect, the Company's internal controls over financial reporting.

Because of their inherent limitations, disclosure controls and procedures and internal controls over financial reporting may not prevent or detect misstatements, errors, or fraud. Control systems, no matter how well conceived or operated, can provide only reasonable, not absolute, assurance that the objectives of the control systems are met.

Additional information related to the Company may be found on the SEDAR website at www.sedar.com.



Crocotta Energy Inc.
Consolidated Balance Sheets
(Unaudited)

As at As at
September 30, 2007 December 31, 2006
----------------------------------------------------------------------------

$ $
----------------------------------------------------------------------------

Assets
Current assets:
Cash and cash equivalents 4,054,428 15,847,815
Accounts receivable 2,609,140 965,233
Prepaid expenses and deposits 371,458 109,284
----------------------------------------------------------------------------
7,035,026 16,922,332
Oil and natural gas properties and
equipment (note 3) 51,364,327 9,522,916

----------------------------------------------------------------------------
58,399,353 26,445,248
----------------------------------------------------------------------------
----------------------------------------------------------------------------

Liabilities and Shareholders' Equity
Current liabilities:
Accounts payable and accrued
liabilities 3,187,200 3,452,655

Asset retirement obligations (note 5) 994,009 173,173

Shareholders' equity:
Capital stock (note 6) 55,751,447 24,224,491
Contributed surplus 87,552 -
Deficit (1,620,855) (1,405,071)
----------------------------------------------------------------------------
54,218,144 22,819,420

Subsequent events (notes 4, 6, and 9)
----------------------------------------------------------------------------
58,399,353 26,445,248
----------------------------------------------------------------------------
----------------------------------------------------------------------------

See accompanying notes to the consolidated financial statements

Approved by the Board of Directors:

Director, "signed" Rob Zakresky Director, "signed" Larry Moeller

The interim consolidated financial statements of the Company have not been
reviewed by the Company's auditors.


Crocotta Energy Inc.
Consolidated Statements of Operations and Deficit
(Unaudited)


Three months ended Nine months ended
September August September August
30, 2007 31, 2006 30, 2007 31, 2006
----------------------------------------------------------------------------

$ $ $ $
----------------------------------------------------------------------------

Revenue:
Oil and natural gas sales 2,586,960 - 4,384,367 -
Transportation expense (46,924) - (75,390) -
Royalties (387,227) - (634,999) -
Interest income 72,855 - 299,556 -
----------------------------------------------------------------------------
2,225,664 - 3,973,534 -
Expenses:
Production 423,496 - 715,560 -
General and administrative 645,560 13,495 1,849,433 52,802
Interest - 31,833 - 96,293
Depletion, depreciation and
accretion 1,387,326 - 2,278,486 -
Stock-based compensation 28,295 - 73,159 -
----------------------------------------------------------------------------
2,484,677 45,328 4,916,638 149,095

----------------------------------------------------------------------------
Net loss from continuing
operations before taxes (259,013) (45,328) (943,104) (149,095)

Taxes:
Future income tax
(recovery) (note 6(b)) - - (727,320) -

----------------------------------------------------------------------------
Net earnings (loss) from
continuing operations (259,013) (45,328) (215,784) (149,095)

Net earnings from
discontinued operations
(note 7) - - - 179,534

Net earnings (loss) and
comprehensive income (loss) (259,013) (45,328) (215,784) 30,439
Deficit, beginning of period (1,361,842) (1,009,227) (1,405,071) (1,084,994)
----------------------------------------------------------------------------

Deficit, end of period (1,620,855) (1,054,555) (1,620,855) (1,054,555)
----------------------------------------------------------------------------
----------------------------------------------------------------------------

Net earnings (loss) per
share from continuing
operations:
Basic and diluted (0.02) (0.42) (0.02) (1.38)
----------------------------------------------------------------------------
----------------------------------------------------------------------------

Net earnings (loss) per
share:
Basic and diluted (0.02) (0.42) (0.02) 0.28
----------------------------------------------------------------------------
----------------------------------------------------------------------------

See accompanying notes to the consolidated financial statements


Crocotta Energy Inc.
Consolidated Statements of Cash Flows
(Unaudited)


Three months ended Nine months ended
September August September August
30, 2007 31, 2006 30, 2007 31, 2006
----------------------------------------------------------------------------

$ $ $ $
----------------------------------------------------------------------------
Cash provided by (used in):

Operating:
Net earnings (259,013) (45,328) (215,784) 30,439
Less: Net earnings from
discontinued operations
(note 7) - - - (179,534)
----------------------------------------------------------------------------
Net earnings (loss) from
continuing operations (259,013) (45,328) (215,784) (149,095)
Items not affecting cash:
Depletion, depreciation and
accretion 1,387,326 - 2,278,486 -
Amortization of convertible
debentures - 18,494 - 56,622
Amortization of deferred
financing costs - 3,153 - 9,459
Stock-based compensation 28,295 - 73,159 -
Future income tax recovery - - (727,320) -
----------------------------------------------------------------------------
1,156,608 (23,681) 1,408,541 (83,014)
Net change in non-cash
working capital from
continuing operations
(note 8) 971,912 347 1,139,261 231,827
----------------------------------------------------------------------------
2,128,520 (23,334) 2,547,802 148,813
Net change in non-cash
working capital from
discontinued operations
(note 7) - - - (178,231)
----------------------------------------------------------------------------
2,128,520 (23,334) 2,547,802 (29,418)
----------------------------------------------------------------------------
----------------------------------------------------------------------------

Financing:
Issuance of capital stock - - 11,117,274 -
Share issue costs (11,204) - (420,631) -
----------------------------------------------------------------------------
(11,204) - 10,696,643 -
----------------------------------------------------------------------------
----------------------------------------------------------------------------

Investing:
Business combination
(note 2) (8,697) - (13,507,132) -
Purchase and development of
oil and natural gas
properties and equipment (5,737,295) - (9,387,137) -
Net change in non-cash
investing working capital
from continuing operations
(note 8) 17,684 - (2,143,563) -
----------------------------------------------------------------------------
(5,728,308) - (25,037,832) -
----------------------------------------------------------------------------
----------------------------------------------------------------------------

Change in cash and cash
equivalents (3,610,992) (23,334) (11,793,387) (29,418)
Cash and cash equivalents,
beginning of period 7,665,420 41,558 15,847,815 47,642
----------------------------------------------------------------------------

Cash and cash equivalents,
end of period 4,054,428 18,224 4,054,428 18,224
----------------------------------------------------------------------------
----------------------------------------------------------------------------

See accompanying notes to the consolidated financial statements



Crocotta Energy Inc.
Notes to the Consolidated Financial Statements
Three and nine months ended September 30, 2007
----------------------------------------------------------------------------

On August 16, 2005, Donner Minerals Ltd., the predecessor to Crocotta Energy Inc. ("Crocotta" or the "Company"), completed a reorganization, by way of statutory plan of arrangement, and restructured into two separate companies, Donner Metals Ltd. and Donner Minerals Ltd., which changed its name to Donner Petroleum Ltd., and subsequently to Crocotta Energy Inc. On November 15, 2006, the Company commenced active oil and natural gas operations with the acquisition of certain oil and natural gas properties from Chamaelo Exploration Ltd.

Effective December 31, 2006, the Company changed its fiscal year-end from February 28 to December 31. As a result, the interim consolidated financial statements prepared are as at and for the three and nine months ended September 30, 2007, with comparative amounts for the three and nine months ended August 31, 2006.

The Company commenced trading on the Toronto Stock Exchange on October 17, 2007 under the symbol "CTA". The Company is engaged in the acquisition, development, exploration, and production of oil and natural gas reserves in Western Canada.

1. SIGNIFICANT ACCOUNTING POLICIES

a) Basis of presentation

The interim consolidated financial statements of Crocotta have been prepared by management in accordance with accounting principles generally accepted in Canada. The interim consolidated financial statements have been prepared following the same accounting policies and methods of computation as the audited consolidated financial statements for the period ended December 31, 2006. The disclosures provided below are incremental to those included with the audited annual consolidated financial statements. The interim consolidated financial statements should be read in conjunction with the audited consolidated financial statements and the notes thereto in the Company's annual report for the period ended December 31, 2006.

b) Stock-based compensation

The Company has a stock-based compensation plan, which is described in note 6. The Company applies the fair value method for valuing stock options granted to officers, directors, employees and consultants. Under this method, compensation cost attributable to stock options granted to officers, directors, employees and consultants is measured at fair value at the grant date and expensed over the vesting period with a corresponding increase to contributed surplus. Upon the exercise of the stock options, consideration paid together with the amount previously recognized in contributed surplus is recorded as an increase to share capital.

c) New accounting standards

Effective January 1, 2007, the Company adopted the Canadian Institute of Chartered Accountants ("CICA") Handbook Section 1530, Comprehensive Income, Section 3251, Equity, Section 3855, Financial Instruments - Recognition and Measurement, Section 3861, Financial Instruments - Disclosure and Presentation, and Section 3865, Hedges, retroactively with no restatement of prior periods.

The Company has evaluated the impact of these new standards and determined that the adoption of these standards has had no material impact on the Company's net earnings or cash flows. The other effects of the implementation of the new standards are discussed below.

Comprehensive Income

The new standards introduce comprehensive income, which consists of net earnings and other comprehensive income ("OCI"). Because the Company does not have any OCI, the Company's interim financial statements do not include a Statement of Comprehensive Income which would otherwise describe the components of comprehensive income. Accordingly, since there are no cumulative changes in OCI to be included in accumulated other comprehensive income ("AOCI"), the Company has not presented AOCI as a new category within shareholders' equity in the interim balance sheet and has not included a Statement of Accumulated Other Comprehensive Income, which would otherwise provide the continuity of the AOCI balance.

Financial Instruments

The financial instruments standard establishes the recognition and measurement criteria for financial assets, financial liabilities and derivatives. All financial instruments are required to be measured at fair value on initial recognition of the instrument, except for certain related party transactions. Measurements in subsequent periods depend on whether the financial instrument has been classified as "held-for-trading", "available-for-sale", "held-to-maturity", "loans and receivables", or "other financial liabilities" as defined by the standard.

Financial assets and financial liabilities classified as "held-for-trading" are measured at fair value with changes in those fair values recognized in net earnings. Financial assets classified as "available-for-sale" are measured at fair value, with changes in those fair values recognized in OCI. Financial assets classified as "held-to-maturity", "loans and receivables" and "other financial liabilities" are measured at amortized cost using the effective interest method of amortization. The methods used by the Company in determining fair value of financial instruments are unchanged as a result of implementing the new standard.

Cash and cash equivalents are designated as "held-for-trading" and are measured at carrying value, which approximates fair value due to the short-term nature of these instruments. Accounts receivable and deposits are designated as "loans and receivables" and accounts payable and accrued liabilities are designated as "other liabilities".

Risk management assets and liabilities are derivative financial instruments classified as "held-for-trading" unless designated for hedge accounting. The Company has no commodity financial contracts or fixed-price physical contracts in place at this time.

Section 1506 - Accounting Changes

Beginning January 1, 2007 the Company adopted Section 1506 "Accounting Changes" the only impact of which is to provide disclosure of when an entity has not applied a new source of GAAP that has been issued but is not yet effective. This is the case with Section 3862, Financial Instruments - Disclosures, Section 3863, Financial Instruments - Presentation, and Section 1535, Capital Disclosures, which are required to be adopted for fiscal years beginning on or after October 1, 2007. The Company will adopt these standards on January 1, 2008 and it is expected the only effect on the Company will be incremental disclosures regarding the significance of financial instruments for the entity's financial position and performance, the nature, extent and management of risks arising from financial instruments to which the entity is exposed, and the policies and processes the Company uses for managing its capital.

2. PLAN OF ARRANGEMENT

On June 8, 2007, the Company closed a Plan of Arrangement whereby it acquired all of the issued and outstanding shares of Eastshore Energy Ltd. ("Eastshore"). The following table details the purchase price allocation for the business combination, which is subject to final adjustments:



Net assets acquired Amount ($)
----------------------------------------------------------------------------
Oil and natural gas properties and equipment 34,604,212
Working capital deficit (3,698,673)
Asset retirement obligation (706,681)
----------------------------------------------------------------------------
30,198,858
----------------------------------------------------------------------------
----------------------------------------------------------------------------

Consideration of acquisition
----------------------------------------------------------------------------
Cash 8,480,289
Issuance of 5,748,702 common shares (see note 6(b)) 21,557,633
Transaction costs 160,936
----------------------------------------------------------------------------
30,198,858
----------------------------------------------------------------------------
----------------------------------------------------------------------------

The net cash consideration for the business combination was $13,507,132
comprised of the original $8,480,289 cash, transaction costs of $160,936,
and a negative cash balance of $4,865,907 acquired from Eastshore.

3. OIL AND NATURAL GAS PROPERTIES AND EQUIPMENT

Accumulated
Depletion and
Cost Depreciation Net Book Value
$ $ $
----------------------------------------------------------------------------
Oil and natural gas properties 53,523,474 2,312,892 51,210,582
Office and other equipment 221,393 67,648 153,745
----------------------------------------------------------------------------
53,744,867 2,380,540 51,364,327
----------------------------------------------------------------------------
----------------------------------------------------------------------------


As at September 30, 2007, the cost of oil and natural gas properties includes approximately $8,653,000 relating to properties from which there is no production and no reserves assigned and which have been excluded from costs subject to depletion and depreciation. During the three and nine months ended September 30, 2007, the provision for depletion, depreciation and accretion includes $17,500 and $27,572, respectively, for accretion of asset retirement obligations. During the three and nine months ended September 30, 2007, the Company capitalized $95,378 and $295,742, respectively, of general and administrative costs.

The Company performed an impairment test calculation at September 30, 2007 to assess the recoverable value of the oil and natural gas properties. The oil and natural gas future prices are based on October 1, 2007 commodity price forecasts of the Company's independent reserve evaluators. These prices have been adjusted for commodity price differentials specific to the Company. The following table summarizes the benchmark prices used in the ceiling test calculation. Based on these assumptions, there was no impairment at September 30, 2007.



Foreign Edmonton Light
WTI Oil Exchange Crude Oil AECO Gas
Year ($US/bbl) Rate ($Cdn/bbl) ($Cdn/mmbtu)
----------------------------------------------------------------------------
2007 69.67 1.000 74.98 6.64
2008 75.00 1.000 74.10 6.60
2009 71.50 1.000 70.60 6.80
2010 69.75 1.000 68.85 6.80
2011 68.00 1.000 67.10 6.85
2012 67.50 1.000 66.60 7.10
2013 67.50 1.000 66.60 7.23
2014 68.50 1.000 67.60 7.39
2015 69.13 1.000 68.23 7.55
2016 70.51 1.000 69.61 7.71
2017 71.92 1.000 71.00 7.86
Escalate
Thereafter 2.0% per year 2.0% per year 2.0% per year
----------------------------------------------------------------------------
----------------------------------------------------------------------------


4. REVOLVING CREDIT FACILITY

The Company has a revolving operating demand loan credit facility available up to $14.5 million bearing interest at prime plus 0.125% with a Canadian bank. The credit facility is secured by a $35 million fixed and floating charge debenture on the assets of the Company and its 100% wholly-owned subsidiary. At September 30, 2007, no amounts had been drawn on the credit facility.

Subsequent to quarter-end, the Company increased its revolving operating demand loan credit facility to $34.0 million. The credit facility bears interest at prime plus a range of 0% to 1.50% and is secured by a $75 million fixed and floating charge debenture on the assets of the Company and its 100% wholly-owned subsidiaries.

5. ASSET RETIREMENT OBLIGATIONS

The Company's asset retirement obligations result from net ownership interests in oil and natural gas properties including well sites, gathering systems, and processing facilities. The Company estimates the total undiscounted amount of cash flows (adjusted for inflation at 2% per year) required to settle its asset retirement obligations is approximately $2,747,000 which is estimated to be incurred between 2007 and 2027. A credit-adjusted risk-free rate of 7% was used to calculate the fair value of the asset retirement obligations.



A reconciliation of the asset retirement obligations is provided below:

Amount ($)
----------------------------------------------------------------------------
Balance at December 31, 2006 173,173
Liabilities acquired upon Plan of Arrangement (note 2) 706,681
Liabilities incurred in period 86,583
Accretion expense 27,572
----------------------------------------------------------------------------
Balance at September 30, 2007 994,009
----------------------------------------------------------------------------
----------------------------------------------------------------------------

6. CAPITAL STOCK

a) Authorized:

Unlimited number of voting common shares.
Unlimited number of non-voting common shares.
Class A preferred shares, issuable in series.
Class B preferred shares, issuable in series.
Special voting shares, issuable in series.

Subsequent to September 30, 2007, the Company filed articles of amendment
to cancel the special voting shares, issuable in series.

b) Issued and outstanding:

On October 12, 2007, the Company's outstanding common shares were
consolidated on a three-to-one basis. The amounts disclosed in the
following table are presented on a post-consolidated basis.

Number Amount ($)
----------------------------------------------------------------------------
Voting common shares
Balance at December 31, 2006 7,980,000 24,224,491
Conversion of special shares 2,036,667 6,110,000
Issued upon Plan of Arrangement (note 2) 5,748,702 21,557,633
Conversion of special warrants issued May 8, 2007 1,080,000 5,007,274
Share issue costs - (420,631)
Future tax effect of flow-through share renunciation - (727,320)
----------------------------------------------------------------------------
Balance at September 30, 2007 16,845,369 55,751,447
----------------------------------------------------------------------------
----------------------------------------------------------------------------


During the nine months ended September 30, 2007, the Company renounced approximately $2.5 million in flow-through share obligations, relating to flow-through share issuances in November 2006. The Company issued an additional 1,080,000 common shares on a flow-through basis during the nine months ended September 30, 2007.

c) Warrants

The Company has an arrangement that allows performance warrants to be issued to directors, officers, and employees. The maximum number of common shares that may be issued, and that have been reserved for issuance under this arrangement, is 2,404,000, representing 24% of the total outstanding common shares and special voting shares as at February 28, 2007, on a post-consolidated basis (see note 6(b)). Performance warrants granted vest over three years and have escalated exercise prices, ranging from $3.75 per share to $6.75 per share. No performance factors are required other than meeting the exercise price. During the nine months ended September 30, 2007, the Company authorized the issuance of 2,404,000 performance warrants as outlined below:



Weighted
Number of Average
Warrants Price ($) Expiry Date
----------------------------------------------------------------------------
Performance Warrants
- issued at $3.75 per share 747,222 3.75 December 23, 2009
- issued at $4.05 per share 20,778 4.05 December 23, 2009
- issued at $4.50 per share 780,556 4.50 December 23, 2009
- issued at $5.25 per share 54,111 5.25 December 23, 2009
- issued at $6.00 per share 747,222 6.00 December 23, 2009
- issued at $6.75 per share 54,111 6.75 December 23, 2009
----------------------------------------------------------------------------
2,404,000 4.80
----------------------------------------------------------------------------
----------------------------------------------------------------------------

The fair value of the performance warrants at the date of issue was
estimated to be $nil using the Black-Scholes option pricing model.


d) Stock options

During the nine months ended September 30, 2007, the Company authorized the issuance of 928,333 common shares at exercise prices ranging from $3.00 per share to $3.75 per share under a stock option plan enabling certain directors, officers, and employees to purchase common shares. The Company has reserved for issuance 1,684,537 common shares for this purpose, representing 10% of total issued and outstanding common shares. The Company will not issue options exceeding 10% of the total common shares outstanding at the time of the option grants. The options vest over a period of three years and have a term of five years. The options have expiry dates ranging from January 23, 2012 to June 27, 2012.



The Company had the following stock options outstanding at September 30,
2007:

Weighted Weighted
Number of Average Average
Options Price ($) Years to Expiry
----------------------------------------------------------------------------
Balance at December 31, 2006 - - -
Options granted 928,333 3.03 4.27
----------------------------------------------------------------------------
Balance at September 30, 2007 928,333 3.03 4.27
----------------------------------------------------------------------------
----------------------------------------------------------------------------

Exercisable at September 30, 2007 - - -
----------------------------------------------------------------------------
----------------------------------------------------------------------------


e) Stock-based compensation

The compensation cost recognized during the three months ended September 30, 2007 was $33,655, of which $28,295 has been charged against income and $5,360 has been capitalized. For the nine months ended September 30, 2007, the compensation cost recognized for the stock option plan was $87,552, of which $73,159 has been charged against income and $14,393 has been capitalized.



The fair value of each option granted is estimated on the date of grant
using the Black-Scholes option-pricing model with the following assumptions:

Three Months Ended Nine Months Ended
September 30, 2007 September 30, 2007
----------------------------------------------------------------------------
Fair value per option $0.14 $0.14
Risk-free rate 4.1% 4.1%
Expected life 4.0 years 4.0 years
Expected volatility 0.0% 0.0%
Dividend yield - -
----------------------------------------------------------------------------
----------------------------------------------------------------------------


f) Put and call obligations

During the quarter, Crocotta entered into put and call financing arrangements to issue 3.1 million common shares priced at $4.05 per share for proceeds of $12.5 million. At September 30, 2007, Crocotta had outstanding put and call financing agreements to issue a total of approximately 8.2 million common shares at exercise prices ranging from $3.75 per share to $4.05 per share. Subsequent to September 30, 2007, all common shares issuable under the put and call financing arrangements were issued.



g) Per share information

The weighted average number of shares outstanding for the determination of
basic and diluted per share amounts are as follows:

Three Months Ended Nine Months Ended
September 30, 2007 September 30, 2007
----------------------------------------------------------------------------
Basic 16,845,369 11,717,097
Dilutive effect of options and warrants 213,721 193,539
----------------------------------------------------------------------------
Diluted 17,059,090 11,910,636
----------------------------------------------------------------------------
----------------------------------------------------------------------------

For the three and nine months ended September 30, 2007, the Company excluded
from the weighted average calculation, 8.2 million common shares issuable
from outstanding put and call obligations and 1.7 million common shares
issuable from warrants as the effect of these was not dilutive.


7. DISCONTINUED OPERATIONS

On August 16, 2005, Donner Minerals Ltd., the predecessor to Crocotta, completed a reorganization, by way of statutory plan of arrangement, and restructured into two separate companies, Donner Metals Ltd. and Donner Minerals Ltd., which changed its name to Donner Petroleum Ltd. and subsequently to Crocotta Energy Inc. As a result of the reorganization and the lack of continuing operations, the Company's consolidated financial statements for the nine months ended August 31, 2006 segregated items prior to and subsequent to the reorganization. For purposes of the comparative period financial statements of Crocotta for the nine months ended September 30, 2007, all items disclosed as prior to restructuring in the consolidated financial statements for the nine months ended August 31, 2006 have been reclassified as discontinued operations.



8. SUPPLEMENTAL CASH FLOW INFORMATION

a) Net change in non-cash working capital

Three Months Ended Nine Months Ended
September 30, 2007 September 30, 2007
----------------------------------------------------------------------------
$ $
Accounts receivable 479,248 (1,643,907)
Prepaid expenses and deposits 42,512 (262,174)
Accounts payable and accrued
liabilities 467,836 (265,455)
Non-cash working capital acquired
on Plan of Arrangement (note 2) - 1,167,234
----------------------------------------------------------------------------
Net change in non-cash working capital 989,596 (1,004,302)
----------------------------------------------------------------------------
----------------------------------------------------------------------------

Relating to:
Operating 971,912 1,139,261
Investing 17,684 (2,143,563)
----------------------------------------------------------------------------
Net change in non-cash working capital 989,596 (1,004,302)
----------------------------------------------------------------------------
----------------------------------------------------------------------------

b) Interest and taxes

Three Months Ended Nine Months Ended
September 30, 2007 September 30, 2007
----------------------------------------------------------------------------
$ $
Cash interest received 72,855 302,261
Cash interest paid - (2,705)
----------------------------------------------------------------------------
Net cash interest received 72,855 299,556

Cash taxes paid - -
----------------------------------------------------------------------------
----------------------------------------------------------------------------


9. SUBSEQUENT EVENTS

On October 12, 2007, the Company acquired all of the issued and outstanding shares of Diamond Tree Energy Ltd. ("Diamond Tree"), a public oil and natural gas company listed on the TSX, by way of plan of arrangement. The aggregate consideration for the transaction is expected to be approximately $67.4 million, payable through the issuance of approximately 8.1 million common shares at an assumed price of $4.05 per share and the assumption of existing debt and working capital estimated to be $35.0 million.



CORPORATE INFORMATION

OFFICERS AND DIRECTORS

Robert J. Zakresky, CA BANK
President, CEO & Director National Bank of Canada
2700, 530 - 8th Avenue SW
Nolan Chicoine, MPAcc, CA Calgary, Alberta T2P 3S8
VP Finance & CFO

Terry L. Trudeau, P.Eng.
VP Operations & COO TRANSFER AGENT
Valiant Trust Company
Weldon Dueck, BSc., P.Eng. 310, 606 - 4th Street SW
VP Business Development Calgary, Alberta T2P 1T1

R.D. (Rick) Sereda, M.Sc., P.Geol.
VP Exploration
LEGAL COUNSEL
Helmut R. Eckert, P.Land Gowling Lafleur Henderson LLP
VP Land 1400, 700 - 2nd Street SW
Calgary, Alberta T2P 4V5
Kevin Keith
VP Production

Larry G. Moeller, CA, CBV AUDITORS
Chairman of the Board KPMG LLP
2700, 205 - 5th Avenue SW
Daryl H. Gilbert, P.Eng. Calgary, Alberta T2P 4B9
Director

Don Cowie
Director INDEPENDENT ENGINEERS
Gilbert Laustsen Jung
Brian Krausert 4100, 400 - 3rd Avenue SW
Director Calgary, Alberta T2P 4H2

Gary W. Burns
Director

Don D. Copeland, P.Eng.
Director

Brian Boulanger
Director


FORWARD-LOOKING STATEMENTS

This press release may contain forward-looking information that involves a number of risks and uncertainties that could cause actual results to differ materially from those anticipated. For this purpose, any statements herein that are not statements of historical fact may be deemed to be forward-looking statements. Such risks and uncertainties include, but are not limited to: risks associated with the oil and gas industry (e.g. --operational risks in exploration, development and production; changes and/or delays in the development of capital assets; uncertainty of reserve estimates; uncertainty of estimates and projections relating to production and costs; commodity price fluctuations; environmental risks; and industry competition).

Contact Information

  • Crocotta Energy Inc.
    Robert J. Zakresky
    President & CEO
    (403) 538-3736
    or
    Crocotta Energy Inc.
    Nolan Chicoine
    VP Finance & CFO
    (403) 538-3738
    or
    Crocotta Energy Inc.
    Suite 700, 639 - 5th Avenue SW
    Calgary, Alberta T2P 0M9
    (403) 538-3737
    (403) 538-3735 (FAX)
    Website: www.crocotta.ca