f10qamd1-033108.htm
 


 
UNITED STATES SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549

Form 10- Q/A
Amendment No. 1

(Mark One)

[X]
QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended March 31, 2008

or

[  ]
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

 
For the transition period from  _____  to _____

Commission file number: 000-51152

PETROHUNTER ENERGY CORPORATION
(Exact name of registrant as specified in its charter)

Maryland
 
98-0431245
(State or other jurisdiction of
 
(I.R.S. Employer
incorporation or organization)
 
Identification No.)
     
1600 Stout Street
 
80202
Suite 2000, Denver, Colorado
 
(Zip Code)
(Address of principal executive offices)
   

 (303) 572-8900
Registrant’s telephone number, including area code


Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. þYes ¨ No

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See definition of “accelerated filer,” “large accelerated filer”, and “smaller reporting company” in Rule 12b-2 of the Exchange Act.

Large accelerated filer o      Accelerated filer o      Non-accelerated filer o      Smaller reporting company þ

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). oYes    þNo

As of April 30, 2008, the registrant had 318,748,841 shares of common stock outstanding.

 
 

 
 

Unless otherwise noted in this report, any description of “us” or “we” refers to PetroHunter Energy Corporation and our subsidiaries. All amounts expressed herein are in U.S. dollars unless otherwise indicated.


FORWARD-LOOKING STATEMENTS

Certain statements contained in this Quarterly Report constitute “forward-looking statements.” These statements, identified by words such as “plan,”  “anticipate,”  “believe,”  “estimate,”  “should,”  “expect” and similar expressions include our expectations and objectives regarding our future financial position, operating results and business strategy. These statements reflect the current views of management with respect to future events and are subject to risks, uncertainties and other factors that may cause our actual results, performance or achievements, or industry results, to be materially different from those described in the forward-looking statements. All forward-looking statements herein as well as all subsequent written and oral forward-looking statements attributable to us, or persons acting on our behalf, are expressly qualified in their entirety by cautionary statements set forth in Item 1A “Risk Factors” appearing in our Annual Report on Form 10-K for the fiscal year ended September 30, 2007. We assume no duty to update or revise our forward-looking statements based on changes in internal estimates or expectations or otherwise. We advise you to carefully review the reports and documents we file from time to time with the Securities and Exchange Commission (the “SEC”).


EXPLANATORY NOTE REGARDING RESTATEMENTS

This Quarterly Report on Form 10-Q/A for the three- and six-month periods ended March 31, 2008 includes restatements of the previously filed condensed consolidated financial statements and data (and related disclosures) for the period ended March 31, 2008.  A summary of these restatements and corrections are discussed in Note 2, Restatement of Previously Issued Financial Statements, included in the accompanying consolidated financial statements for the period ended March 31, 2008.  These corrections are also discussed in Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations.  We previously announced, in a Form 8-K filed with the SEC on November 20, 2008, that we would restate our previously reported financial statements as originally filed with the SEC on May 15, 2008, as a result of the discovery of several significant errors by management during its year-end review, and in conjunction with the annual audit.  The information contained in this Quarterly Report on Form 10-Q/A amends only Items 1, 2 and 4 of Part I to the originally filed Quarterly Report on Form 10-Q filed with the SEC on May 15, 2008 (the “Original Report”).
 
This Quarterly Report on Form 10-Q/A does not reflect all events occurring after the original filing of the Original Report or modify or update all the disclosures affected by subsequent events.  Information not modified or updated herein reflects the disclosures made at the time of the filing of the Original Report on May 15, 2008.  Accordingly, this Form 10-Q/A should be read in conjunction with all of our periodic filings, including our amended filings on Form 10-Q/A in relation to the three-month period ended December 31, 2007, and in relation to the three- and nine-month period ended June 30, 2008, filed with the SEC in conjunction with the filing of this report.
 
All subsequent written and oral forward-looking statements attributable to us, or persons acting on our behalf, are expressly qualified in their entirety by the cautionary statements.  We assume no duty to update or revise our forward-looking statements based on changes in internal estimates or expectations or otherwise.


GLOSSARY

Unless otherwise indicated in this document, oil equivalents are determined using the ratio of six Mcf of natural gas to one barrel of crude oil, condensate or natural gas liquids so that six Mcf of natural gas are referred to as one barrel of oil equivalent.

API Gravity. A specific gravity scale developed by the American Petroleum Institute (API) for measuring the relative density of various petroleum liquids, expressed in degrees. API gravity is gradated in degrees on a hydrometer instrument and was designed so that most values would fall between 10° and 70° API gravity. The
 
 
2

arbitrary formula used to obtain this effect is: API gravity = (141.5/SG at 60°F) — 131.5, where SG is the specific gravity of the fluid.

Bbl. One stock tank barrel, or 42 U.S. gallons liquid volume, used in reference to oil or other liquid hydrocarbons.

Bcf. One billion cubic feet of natural gas at standard atmospheric conditions.

Capital Expenditures. Costs associated with exploratory and development drilling (including exploratory dry holes); leasehold acquisitions; seismic data acquisitions; geological, geophysical and land related overhead expenditures; delay rentals; producing property acquisitions; other miscellaneous capital expenditures; compression equipment and pipeline costs.

Carried Interest. The owner of this type of interest in the drilling of a well incurs no liability for costs associated with the well until the well is drilled, completed and connected to commercial production/processing facilities.

Completion. The installation of permanent equipment for the production of oil or natural gas.

Developed Acreage. The number of acres that are allocated or assignable to producing wells or wells capable of production.

Development Well. A well drilled within the proved area of an oil or natural gas reservoir to the depth of a stratigraphic horizon known to be productive.

Drilled and Cased. Involves drilling a well and installing casing to a specified depth in the wellbore for future completion.

Exploitation. The continuing development of a known producing formation in a previously discovered field. To make complete or maximize the ultimate recovery of oil or natural gas from the field by work including development wells, secondary recovery equipment or other suitable processes and technology.

Exploration. The search for natural accumulations of oil and natural gas by any geological, geophysical or other suitable means.

Exploratory Well. A well drilled to find and produce oil or natural gas in an unproved area, to find a new reservoir in a field previously found to be productive of oil or natural gas in another reservoir, or to extend a known reservoir.
 
Farm-In or Farm-Out. An agreement under which the owner of a working interest in a natural gas and oil lease assigns the working interest or a portion of the working interest to another party who desires to drill on the leased acreage. Generally, the assignee is required to drill one or more wells in order to earn its interest in the acreage. The assignor usually retains a royalty or reversionary interest in the lease. The interest received by an assignee is a “farm-in” while the interest transferred by the assignor is a “farm-out”.

Field. An area consisting of either a single reservoir or multiple reservoirs, all grouped on or related to the same individual geological structural feature and/or stratigraphic condition.

Finding and Development Costs. The total capital expenditures, including acquisition costs, and exploration and abandonment costs, for oil and gas activities divided by the amount of proved reserves added in the specified period.

Force Pooling. The process by which interests not voluntarily participating in the drilling of a well, may be involuntarily committed to the operator of the well (by a regulatory agency) for the purpose of allocating costs and revenues attributable to such well.

Gross Acres or Gross Wells. The total acres or wells, as the case may be, in which we have a working interest.

3

Lease. An instrument which grants to another (the lessee) the exclusive right to enter to explore for, drill for, produce, store and remove oil and natural gas on the mineral interest, in consideration for which the lessor is entitled to certain rents and royalties payable under the terms of the lease. Typically, the duration of the lessee’s authorization is for a stated term of years and “for so long thereafter” as minerals are producing.

Mcf. One thousand cubic feet of natural gas at standard atmospheric conditions.

MCFE. One thousand cubic feet of gas equivalent. Gas equivalents are determined using the ratio of six Mcf of gas (including gas liquids) to one Bbl of oil.

Net Acres or Net Wells. A net acre or well is deemed to exist when the sum of our fractional ownership working interests in gross acres or wells, as the case may be, equals one. The number of net acres or wells is the sum of the fractional working interests owned in gross acres or wells, as the case may be, expressed as whole numbers and fractions thereof.

Operator. The individual or company responsible to the working interest owners for the exploration, development and production of an oil or natural gas well or lease.

Overriding Royalty. A revenue interest in oil and gas, created out of a working interest which entitles the owner to a share of the proceeds from gross production, free of any operating or production costs.

Payout. The point at which all costs of leasing, exploring, drilling and operating have been recovered from production of a well or wells, as defined by contractual agreement.

Productive Well. A well that is found to be capable of producing hydrocarbons in sufficient quantities such that proceeds from the sale of the production exceed production expenses and taxes.

Prospect. A specific geographic area which, based on supporting geological, geophysical or other data and also preliminary economic analysis using reasonably anticipated prices and costs, is deemed to have potential for the discovery of commercial hydrocarbons.

Proved Reserves. The estimated quantities of oil, natural gas and natural gas liquids which geological and engineering data demonstrate with reasonable certainty to be commercially recoverable in future years from known reservoirs under existing economic and operating conditions.

Reserves. Natural gas and crude oil, condensate and natural gas liquids on a net revenue interest basis, found to be commercially recoverable.

Reservoir. A porous and permeable underground formation containing a natural accumulation of producible natural gas and/or oil that is confined by impermeable rock or water barriers and is separate from other reservoirs.

Royalty. An interest in an oil and natural gas lease that gives the owner of the interest the right to receive a portion of the production from the leased acreage, or of the proceeds of the sale thereof, but generally does not require the owner to pay any portion of the costs of drilling or operating the wells on the leased acreage. Royalties may be either landowner’s royalties, which are reserved by the owner of the leased acreage at the time the lease is granted, or overriding royalties, which are usually reserved by an owner of the leasehold in connection with a transfer to a subsequent owner.

Spud. To start the well drilling process by removing rock, dirt and other sedimentary material with the drill bit.

3-D Seismic. The method by which a three-dimensional image of the earth’s subsurface is created through the interpretation of reflection seismic data collected over a surface grid. 3-D seismic surveys allow for a more detailed understanding of the subsurface than do conventional surveys and contribute significantly to field appraisal, exploitation and production.

4

Undeveloped Acreage. Lease acres on which wells have not been drilled or completed to a point that would permit the production of commercial quantities of oil and gas regardless of whether or not such acreage contains proved reserves.

Working Interest. An interest in an oil and gas lease that gives the owner of the interest the right to drill and produce oil and gas on the leased acreage and requires the owner to pay a share of the costs of drilling and production operations. The share of production to which a working interest owner is entitled will always be smaller than the share of costs that the working interest owner is required to bear, with the balance of the production accruing to the owners of royalties.

 
 
5

 
 



PETROHUNTER ENERGY CORPORATION

FORM 10-Q/A

FOR THE SIX-MONTH PERIOD ENDED
MARCH 31, 2008
(restated)


INDEX


     
PART I — FINANCIAL INFORMATION
Item 1.
Financial Statements
   7
 
Consolidated Balance Sheets
   7 
 
Consolidated Statements of Operations
   8 
 
Consolidated Statements of Stockholders’ Equity and Comprehensive Loss
   9 
 
Consolidated Statements of Cash Flows
 11 
 
Notes to Consolidated Financial Statements
 12
Item 2.
Management's Discussion and Analysis of Financial Condition and Results of Operations
 37
Item 4T.
Controls and Procedures
 46
 
 
 
PART II — OTHER INFORMATION
Item 1.
Legal Proceedings
 47
Item 1A.
Risk Factors
 48
Item 6.
Exhibits
 48
 
Signatures
 49




 
 
6

 
 
PART I. FINANCIAL INFORMATION
PETROHUNTER ENERGY CORPORATION
(A Development Stage Company)
CONSOLIDATED BALANCE SHEETS
   
March 31,2008
   
September 30,
2007
 
   
(unaudited)
(restated)
       
   
($ in thousands)
 
ASSETS
 
Current Assets
           
Cash and cash equivalents
 
$
1,592
   
$
120
 
Receivables
               
Oil and gas receivables, net
   
404
     
487
 
Other receivables
   
15
     
59
 
GST receivable
   
442
     
 
Due from related parties
   
160
     
500
 
Note receivable — related party
   
     
2,494
 
Prepaid expenses and other assets
   
69
   
187
 
Total Current Assets
   
2,682
     
3,847
 
                 
Property and Equipment, at cost
               
Oil and gas properties under full cost method, net
   
165,940
     
162,843
 
Furniture and equipment, net
   
840
     
569
 
     
166,780
     
163,412
 
Other Assets
               
Joint interest billings
   
1,029
     
13,637
 
Restricted cash
   
549
     
599
 
Deposits and other assets
   
48
     
 
Deferred financing costs
   
1,785
     
529
 
    Intangible asset
   
2,431
     
 
Total Assets
 
$
175,304
   
$
182,024
 
LIABILITIES AND STOCKHOLDERS’ EQUITY
 
Current Liabilities
               
Accounts payable and accrued expenses
 
$
27,182
   
$
26,631
 
Notes payable — short-term
   
2,109
     
4,667
 
Convertible notes payable
   
400
     
400
 
Note payable — related party — current portion
   
2,805
     
3,755
 
Note payable — current portion of long-term liabilities
   
120
     
120
 
Accrued interest payable
   
5,130
     
2,399
 
Accrued interest payable — related party
   
720
     
516
 
Due to shareholder and related parties
   
1,079
     
1,474
 
Contract payable — oil and gas properties
   
     
1,750
 
Contingent purchase obligation
   
2,431
     
 
Total Current Liabilities
   
41,976
     
41,712
 
                 
Notes payable — net of discount
   
29,965
     
27,944
 
Subordinated notes payable — related parties
   
1,401
     
9,050
 
Convertible notes payable — net of discount
   
150
     
 
Asset retirement obligation
   
104
     
136
 
Total Liabilities
   
73,596
     
78,842
 
                 
Common Stock Subscribed
   
     
2,858
 
Commitments and Contingencies
               
Stockholders’ Equity
               
Preferred stock, $0.001 par value; authorized 100,000,000 shares; none issued
   
     
 
Common stock, $0.001 par value; authorized 1,000,000,000 shares; 318,748,841 and 278,948,841 shares issued and outstanding at March 31, 2008 and September 30, 2007, respectively
   
319
     
279
 
Additional paid-in-capital
   
198,592
     
172,672
 
Accumulated other comprehensive loss
   
(41
)
   
(5
)
Deficit accumulated during the development stage
   
(97,162
)
   
(72,622
)
Total Stockholders’ Equity
   
101,708
     
100,324
 
Total Liabilities and Stockholders’ Equity
 
$
175,304
   
$
182,024
 
See accompanying notes to consolidated financial statements.

 
7

 
 
PETROHUNTER ENERGY CORPORATION
(A Development Stage Company)
CONSOLIDATED STATEMENTS OF OPERATIONS
 
   
Three months
ended
March 31,
2008
   
Three months
ended
March 31,
2007
   
Six months
ended
March 31,
2008
   
Six months
ended
March 31,
2007
   
Cumulative
From Inception
(June 20, 2005) to
March 31, 2008
 
    (unaudited, restated, $ in thousands except per share amounts)  
Revenue
                             
Oil and gas revenue
 
$
496
   
$
989
   
$
1,003
   
$
1,438
   
$
3,859
 
Other revenue
   
150
     
     
150
     
     
150
 
Total revenue
   
646
     
989
     
1,153
     
1,438
     
4,009
 
                                         
Costs and Expenses
                                       
Lease operating expenses
   
140
     
224
     
240
     
386
     
1,037
 
General and administrative
   
2,469
     
4,405
     
4,787
     
8,076
     
37,735
 
Project development — related party
   
     
     
     
1,815
     
7,205
 
Impairment of oil and gas properties
   
     
3,800
     
     
8,951
     
24,053
 
Depreciation, depletion, amortization and accretion
   
221
     
827
     
483
     
1,213
     
1,801
 
Total operating expenses
   
2,830
     
9,256
     
5,510
     
20,441
     
71,831
 
                                         
Loss from operations     (2,184     (8,267     (4,357     (19,003     (67,822 ) 
Other Income (Expense):
                                       
Loss on conveyance of property
   
     
     
(11,875
)
   
     
(11,875
)
Gain on foreign exchange
   
11
     
     
11
     
     
34
 
Interest income
   
2
     
6
     
27
     
14
     
65
 
Interest expense
   
(2,574
)
   
(2,004
)
   
(5,359
)
   
(1,831
)
   
(14,577
)
Loss on sale of securities
   
(2,987
)
   
     
(2,987
)
   
     
(2,987
)
Total other expense
   
(5,548
)
   
(1,998
)
   
(20,183
)
   
(1,817
)
   
(29,340
)
Net Loss
 
$
(7,732
 
$
(10,265
)
 
$
(24,540
  
$
(20,820
)
 
$
(97,162
)
Net loss per common share — basic and diluted
 
$
(0.02
)
 
$
(0.05
)
 
$
(0.08
)
 
$
(0.09
)
       
Weighted average number of common shares outstanding — basic and diluted
   
316,978
     
222,562
     
312,610
     
221,245
         

See accompanying notes to consolidated financial statements.

 

 
 
8

 
 

PETROHUNTER ENERGY CORPORATION
(A Development Stage Company)
CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY AND COMPREHENSIVE LOSS
(unaudited, $ in thousands except share and per share amounts)
 
   
 
Common Stock
   
Additional
Paid-in
   
Deficit
Accumulated
During the
Development
   
Accumulated
Other
Compre-
hensive
   
Total
Stockholders’
   
Total
Compre-
hensive
 
   
Shares
   
Amount
   
Capital
   
Stage
   
Loss
   
Equity
   
Loss
 
Balances, June 20, 2005 (inception)
        $     $     $     $     $     $  
Shares issued to founder at $0.001 per share
    100,000,000       100                         100        
Stock-based compensation costs for options granted to non- employees
                823                   823        
Net loss
                      (2,119 )           (2,119 )     (2,119 )
Balances, September 30, 2005
    100,000,000       100       823       (2,119 )           (1,196 )     (2,119 )
Shares issued for property interests at $0.50 per share
    3,000,000       3       1,497                   1,500        
Shares issued for finder’s fee on property at $0.50 per share
    3,400,000       3       1,697                   1,700        
Shares issued upon conversion of debt, at $0.50 per share
    44,063,334       44       21,988                   22,032        
Shares issued for commission on convertible debt at $0.50 per share
    2,845,400       3       1,420                   1,423        
Sale of shares and warrants at $1.00 per unit
    35,442,500       35       35,407                   35,442        
Shares issued for commission on sale of units
    1,477,500       1       1,476                   1,477        
Costs of stock offering:
                                                       
Cash
                (1,638 )                 (1,638 )      
Shares issued for commission at $1.00 per share
                (1,478 )                 (1,478 )      
Exercise of warrants
    1,000,000       1       999                   1,000        
Recapitalization of shares issued upon merger
    28,700,000       30       (436 )                 (406 )      
Stock-based compensation
                9,189                   9,189        
Net loss
                      (20,692 )           (20,692 )     (20,692 )
Balances, September 30, 2006
    219,928,734       220       70,944       (22,811 )           48,353       (20,692 )
Shares issued for property interests at $1.62 per share
    50,000,000       50       80,950                   81,000        
Shares issued for property interests at $1.49 per share
    256,000             382                   382        
Shares issued for commission costs on property at $1.65 per share
    121,250             200                   200        
Shares issued for finance costs on property at $0.70 per share
    642,857       1       449                   450        
Shares issued for property and finance interests at various costs per share
    8,000,000       8       6,905                   6,913        
Foreign currency translation adjustment
                            (5 )     (5 )     (5 )
Discount on notes payable
                4,670                   4,670        
Stock-based compensation
                8,172                   8,172        
Net loss
                      (49,811 )           (49,811 )     (49,811 )
Balances, September 30, 2007
    278,948,841       279       172,672       (72,622 )     (5 )     100,324       (49,816 )
 
 
 
9

 
 
 
 
 
 
 
 
Common Stock
   
 
Additional Paid-in
   
Accumulated Deficit During the Development
   
Accumulated Other Compre-hensive
   
Total
Stockholders’
   
Total
Compre-hensive
 
   
Shares
   
Amount
   
Capital
   
Stage
   
Loss
   
Equity
   
Loss
 
Balances, September 30, 2007
    278,948,841       279       172,672       (72,622 )     (5 )     100,324       (49,816 )
Shares issued for property interests at $0.31 per share – related party
    25,000,000       25       7,725                   7,750        
Shares issued  in connection with  debt conversion at $0.23 per share – related party
    16,000,000       16       3,664                   3,680        
Shares issued for property interests at $0.25 per share
    5,000,000       5       1,245                   1,250        
Shares returned for property conveyance at $0.22 per share (restated)
    (6,400,000 )     (6 )     (1,402 )                 (1,408 )      
Shares issued for finance costs at $0.28 per share
    200,000             56                   56        
Discounts associated with beneficial conversion feature and detachable warrants on convertible debenture issuance
                6,956                   6,956        
Warrant value associated with convertible debenture issuance (restated)
                21                   21        
Warrants issued in connection with debt offering (restated)
                1,895                   1,895        
Warrant value associated with  debt conversion  - related party (restated)
                1,841                   1,841        
Debt conversion – related party (restated)
                2,704                   2,704        
Discount on notes payable (restated)
                143                   143        
Foreign currency translation adjustment
                            (36 )     (36 )     (36 )
Stock-based compensation (restated)
                1,072                   1,072        
Net loss (restated)
                      (24,540 )           (24,540 )     (24,540 )
Balances, March 31, 2008
    318,748,841     $ 319     $ 198,592     $ (97,162 )   $ (41 )   $ 101,708     $ (24,576 )
 
See accompanying notes to consolidated financial statements.
 
 
 
10

 
 
PETROHUNTER ENERGY CORPORATION
(A Development Stage Company)
CONSOLIDATED STATEMENTS OF CASH FLOWS
   
Six months
ended
March 31,
2008
   
Six months
ended
March 31,
2007
   
Cumulative From
Inception
(June 20, 2005)
to March 31,
2008
 
   
(unaudited, restated, $ in thousands)
 
Cash flows from operating activities
                 
Net loss
 
$
(24,540
)
 
$
(20,820
)
 
$
(97,162
)
Adjustments used to reconcile net loss to net cash used in operating activities:
                       
Stock-based compensation
   
1,072
     
3,617
     
19,256
 
Detachable warrants recorded as interest expense
   
163
     
     
163
 
Depreciation, depletion, amortization and accretion
   
483
     
1,763
     
1,801
 
Impairment of oil and gas properties
   
     
8,400
     
24,053
 
Amortization of deferred financing costs
   
1,020
     
1,441
     
2,643
 
Amortization of debt discount and beneficial conversion feature
   
1,180
     
148
     
2,216
 
Loss on marketable securities
   
2,987
     
     
2,987
 
Loss on conveyance of property
   
11,875
     
     
11,875
 
Other adjustments to reconcile net loss
   
45
     
     
122
 
    Changes in assets and liabilities:
Receivables
   
(315
)
   
(1,569
)
   
(861
)
Due from related party
   
     
921
     
(500
)
Prepaids and other
   
70
     
24
     
25
 
Accounts payable, accrued expenses, and other liabilities
   
1,898
     
(1,255
)
   
6,752
 
Due to shareholder and related parties
   
     
618
     
1,474
 
Net cash used in operating activities
   
(4,062
)
   
(6,712
)
   
(25,156
)
Cash flows from investing activities
                       
Additions to oil and gas properties
   
(8,707
)
   
(3,808
)
   
(74,372
)
Notes receivable, related party
   
     
(12,863
)
   
(2,494
)
Proceeds from sale of oil and gas properties
   
7,500
     
     
7,500
 
Proceeds from sales of marketable securities
   
2,541
     
     
2,541
 
Additions to furniture and equipment
   
(277
)
   
(95
)
   
(964
)
Restricted cash
   
 50
     
(525
)
   
(1,027
)
Net cash provided by (used in) investing activities
   
1,107
     
(17,291
)
   
(68,816
)
Cash flows from financing activities
                       
Proceeds from the sale of common stock
   
     
     
35,742
 
Proceeds from common stock subscribed
   
     
3,067
     
2,858
 
Proceeds from the issuance of notes payable
   
1,250
     
12,500
     
32,800
 
Borrowing on short-term notes payable
   
850
     
     
1,350
 
Payments on short-term notes payable
   
(4,654
)
   
     
(4,654
)
Payments on related party borrowing
   
(519
)
   
(450
)
   
(519
)
Proceeds from related party borrowing
   
1,170
     
     
1,445
 
Proceeds from the exercise of warrants
   
     
     
1,000
 
Cash received upon recapitalization and merger
   
     
     
21
 
Proceeds from issuance of convertible notes
   
6,330
     
     
27,162
 
Offering and financing costs
   
     
(44
)
   
(1,638
)
Net cash provided by financing activities
   
4,427
     
15,073
     
95,567
 
Effect of exchange rate changes on cash
   
     
     
(3
)
Net increase (decrease) in cash and cash equivalents
   
1,472
     
(8,930
)
   
1,592
 
Cash and cash equivalents, beginning of period
   
120
     
10,632
     
 
Cash and cash equivalents, end of period
 
$
1,592
   
$
1,702
   
$
1,592
 
                         
Supplemental schedule of cash flow information
                       
Cash paid for interest
 
$
 16
   
$
   
$
1,517
 
Cash paid for income taxes
 
$
   
$
   
$
— 
 
See accompanying notes to consolidated financial statements.

 
 
11

 
PETROHUNTER ENERGY CORPORATION
(A Development Stage Company)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(unaudited, restated)

Note 1 — Organization and Basis of Presentation

We are a development stage global oil and gas exploration and production company committed to acquiring and developing primarily unconventional natural gas and oil prospects that we believe have a very high probability of economic success. Since our inception in 2005, our principal business activities have been raising capital through the sale of common stock and convertible notes and acquiring oil and gas properties in the western United States and Australia. Currently, we own property in Colorado, where we have drilled five wells on our Buckskin Mesa property, and Australia, where we have drilled one well on our property in the Northern Territory, and in Montana, where we hold a land position in the Bear Creek area. The wells on these properties have not yet commenced oil and gas production. We own working interests in eight additional wells in Colorado which are operated by EnCana Oil & Gas USA (“EnCana”) and are currently producing gas. In November 2007, we sold 66,000 net acres of land and two wells in Montana and 177,445 acres of land in Utah (see Note 5 ) and subsequent to March 31, 2008, we entered into a binding purchase and sale agreement to sell up to 1,059 net acres and 16 wells in the Southern Piceance Basin in Colorado (see Note 13).

Our predecessor, Digital Ecosystems Corp. (“Digital”), was incorporated on February 21, 2002 under the laws of the state of Nevada. On February 10, 2006, Digital entered into a Share Exchange Agreement (the “Exchange Agreement”) with GSL Energy Corporation (“GSL”) and certain shareholders of GSL pursuant to which Digital acquired more than 85% of the issued and outstanding shares of common stock of GSL in exchange for shares of Digital’s common stock. The Exchange Agreement was completed on May 12, 2006. At that time, GSL’s business, which was formed in 2005 for the purpose of acquiring, exploring, developing and operating oil and gas properties, became Digital’s business and GSL became a subsidiary of Digital. Since this transaction resulted in the former shareholders of GSL acquiring control of Digital, for financial reporting purposes, the business combination was accounted for as an additional capitalization of Digital (a reverse acquisition with GSL as the accounting acquirer). In accounting for this transaction:

 
i.  
GSL was deemed to be the purchaser and parent company for financial reporting purposes. Accordingly its net assets were included in the consolidated balance sheet at their historical book value; and
     
  ii. control of the net assets and business of Digital was effective May 12, 2006 for no consideration. 
 
Subsequent to the closing of the Exchange Agreement, Digital acquired all the remaining outstanding stock of GSL, and effective August 14, 2006, Digital changed its name to PetroHunter Energy Corporation (“PetroHunter”). Likewise, in October 2006, GSL changed its name to PetroHunter Operating Company.

PetroHunter is considered a development stage company as defined by Statement of Financial Accounting Standards (“SFAS”) 7, Accounting and Reporting by Development Stage Enterprises, as we have not yet commenced our planned principal operations. A development stage enterprise is one in which planned principal operations have not commenced, or if its operations have commenced, there has been no significant revenue therefrom.

Unless otherwise noted in this report, any description of “us” or “we” refers to PetroHunter Energy Corporation and our subsidiaries. Financial information in this report is presented in U.S. dollars.


 
12

 
PETROHUNTER ENERGY CORPORATION
(A Development Stage Company)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(unaudited, restated)

Note 2 – Restatement of Previously Issued Financial Statements

On August 11, 2008, we concluded our unaudited financial statements for the quarterly periods ended December 31, 2007 and March 31, 2008, included in our Quarterly Reports on Form 10-Q for the quarterly periods ended December 31, 2007 and March 31, 2008, should not be read without also considering the effect of errors that were discovered in subsequent periods.  The Company had identified the aggregate effects of correcting these errors in their proper quarterly periods, which was announced in our Form 8-K filed with the SEC on August 14, 2008.

On November 14, 2008, we concluded our unaudited financial statements included in the Company’s Quarterly Reports on Form 10-Q for the quarters ended December 31, 2007, March 31, 2008 and June 30, 2008 would be restated due to the discovery of additional errors.

The following errors affected our Original Report for the three and six month periods ended March 31, 2008:

1.  
Detachable Warrants with Convertible Debentures – We corrected an error during our first quarter ended December 31, 2007 in relation to our accounting for the value of detachable warrants that were issued in relation to the issuance of $7.0 million of Convertible Debentures, where we erroneously charged the $2.9 million of value assigned to the detachable warrants to interest expense, versus recording the warrant value as a discount against the face value of the Convertible Debentures and amortizing the discount to interest expense over the remaining term of the convertible debentures using the effective interest method.  We recorded further corrections during the second quarter ended March 31, 2008 to give proper effect to the additional discount against the face value of the Convertible Debentures, and to properly record the effects of the additional amortization to interest expense.
 
2.  
Detachable Warrants with Global Debt Facility – We corrected errors in our accounting for detachable warrants issued in relation to our Global Credit Facility during our first quarter ended December 31, 2007.  First, we inappropriately used a warrant term assumption in our Black-Scholes calculation of fair value that was less than the contractual life of the warrants, which understated the initial value of the warrants by $1.9 million.  Second, we failed to properly record $1.2 million of the total as deferred financing costs associated with the warrants that were issued in connection with securing the facility.  We recorded further corrections during the second quarter ended March 31, 2008 to give proper effect to the additional amortization to interest expense.
 
3.  
Heavy Oil Asset Sale – We corrected several errors in our accounting for the sale of our Heavy Oil Projects during our first quarter ended December 31, 2007.  First, we corrected an error in our accounting for the proceeds from the sale of these assets to Pearl Exploration and Production Ltd., where we erroneously recorded $2.7 million of contingent consideration (in the form of the common stock of the acquirer) relating to the sale of assets that did not ultimately transfer, net of $0.9 million in unrealized losses also recognized in error.  Second, we corrected a $2.4 million error in our accounting for unrealized losses from declines in the market value of the securities received in the transaction, where we erroneously treated the securities as trading securities and recorded an unrealized loss in our statement of operations, versus reflecting the $1.6 million in unrealized losses (net of the $0.9 million excess discussed above) as a charge to other comprehensive income.  Finally, we determined we should have recorded a $11.9 million loss on conveyance on the transaction, based on the relationship of the fair value of the Heavy Oil Projects, versus what was recorded in our full cost pool.  We recorded further corrections during the second quarter ended March 31, 2008 to give proper effect to the recognition of the realized loss on the sale of marketable securities we acquired in relation to this transaction, and had been held for sale, by recording the proper realized loss in our statement of operations.  In addition, we recorded corrections during the second quarter ended March 31, 2008 to our oil and gas property accounts and our accumulated deficit in relation to the loss on conveyance.
 
4.  
Related Party Consulting Agreement Termination – We corrected a $0.2 million error in our accounting for the termination of certain consulting services that had been provided by a significant shareholder during the first quarter ended December 31, 2007, which understated accrued expenses and general and administrative expense.  We recorded further corrections during the second quarter ended March 31, 2008 to reverse the
 
13

PETROHUNTER ENERGY CORPORATION
(A Development Stage Company)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(unaudited, restated)
 
 
effects of corrections we reflected in our Original Report, affecting accrued expenses, additional paid in capital and general and administrative expense.
 
5.  
Contingent Purchase Obligation – During our first quarter ended December 31, 2007, we corrected an error in our accounting for a financial guarantee in relation to capital costs incurred by a third party in conjunction with the construction of a gas gathering system and the provision of gas gathering services for our Buckskin Mesa Project, and recorded a $2.0 million intangible asset and contingent purchase obligation to reflect the fair value of this guarantee.  We recorded further corrections during the second quarter ended March 31, 2008 to properly reflect the value the guarantee as of that date.
 
6.  
Stock-Based Compensation Expense – During our second quarter ended March 31, 2008, we corrected a $0.4 million error in our accounting for stock-based compensation expense, resulting from various errors in valuing our expense using our Black-Scholes calculation of fair value.
 
7.  
Maralex Transaction – During the first quarter ended December 31, 2007, we corrected an error in our accounting for the value of 6.4 million shares of our common stock that we reacquired during the quarter ended December 31, 2007.  The shares were originally issued during our year ended September 30, 2007 in relation to the acquisition of certain properties (our “Sugarloaf Project”) and the incurrence of penalties on a series of payment defaults on our contract.  The correction of this error resulted in a $4.1 million increase in our oil and gas property accounts, with a corresponding increase in additional paid in capital.  We recorded further corrections to our oil and gas property accounts and additional paid in capital during the second quarter ended March 31, 2008 to give proper effect to the correction of this error on our balance sheet.

8.  
Other Errors – We corrected several other errors that were individually insignificant and primarily related to the timing of the recognition of costs and expenses in our statement of operations during our year ending September 30, 2008 (primarily between the first quarterly period ended December 31, 2007 and the second quarterly period ended March 31, 2008) and the proper classification of amounts receivable for Goods and Services Taxes in Australia.


 
14

 
PETROHUNTER ENERGY CORPORATION
(A Development Stage Company)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(unaudited, restated)

Balance Sheet Effects of Restatements

The following table sets forth the unaudited condensed consolidated balance sheet, showing previously reported amounts, adjustments resulting from the correction of errors and reclassifications, and restated balances as of March 31, 2008 (in thousands):
 
   
March 31, 2008
 
   
As previously reported
   
Net Adjustments
   
As restated
 
                   
Current Assets
                 
  Cash and cash equivalents
  $ 1,592     $ -     $ 1,592  
  Receivables
    359       662       1,021  
  Other current assets
    69       -       69  
  Total Current Assets
    2,020       662       2,682  
                         
Property and Equipment, at cost and Other Assets
                       
  Oil and gas properties under full cost method, net
    173,975       (8,035 )     165,940  
  Intangible asset
    2,756       (325 )     2,431  
  Deferred financing costs
    713       1,072       1,785  
  Other assets
    2,073       393       2,466  
                         
Total Assets
  $ 181,537     $ (6,233 )   $ 175,304  
                         
Current Liabilities
                       
  Accounts payable and accrued expenses
  $ 26,695     $ 487     $ 27,182  
  Due to shareholders and related parties
    1,058       21       1,079  
  Notes and interest payable
    7,759       -       7,759  
  Notes and interest payable, related parties
    3,525        -       3,525  
  Contingent purchase obligation
    2,756       (325 )     2,431  
  Total Current Liabilities
    41,793       183       41,976  
                         
Non-Current Obligations
                       
  Notes payable, net
    30,099       (134 )     29,965  
  Convertible notes payable, net
    2,997       (2,847 )     150  
  Subordinated notes payable, related parties
    1,401       -       1,401  
  Asset retirement obligation
    104       -       104  
  Net Non-Current Obligations
    34,601       (2,981 )     31,620  
                         
  Total Liabilities
    76,394       (2,798 )     73,596  
                         
Stockholders' Equity
                       
  Common stock
    319       -       319  
  Additional paid in capital
    193,240       5,352       198,592  
  Accumulated other comprehensive loss
    (41 )     -       (41 )
  Deficit accumulated during development stage
    (88,375 )     (8,787 )     (97,162 )
  Total Stockholders' Equity
    105,143       (3,435 )     101,708  
                         
Total Liabilities and Stockholders' Equity
  $ 181,537     $ (6,233 )   $ 175,304  
 
15

PETROHUNTER ENERGY CORPORATION
(A Development Stage Company)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(unaudited, restated)
 
Statement of Operations Effects of Restatements
 
The following table presents our unaudited condensed consolidated statement of operations, showing previously reported amounts, adjustments resulting from the correction of errors, and restated balances for the three and six month periods ended March 31, 2008 (in thousands, except share data):
 
   
For the three months ended March 31, 2008
   
For the six months ended March 31, 2008
 
   
As previously reported
   
Net Adjustments
   
As restated
   
As previously reported
   
Net Adjustments
   
As restated
 
 
                                   
Total Revenue   $ 705     $ (59 )   $ 646     $ 992     $ 161     $ 1,153  
                                                 
Costs & Expenses:
                                               
General and administrative
    3,796       (1,327 )     2,469       5,690       (903 )     4,787  
Other operating expenses
    322       39       361       681       42       723  
Total Operating Expenses
    4,118       (1,288 )     2,830       6,371       (861 )     5,510