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InterOil Corporation Revised Consolidated Financial Statements (Expressed in United States dollars)

MANAGEMENT’S REPORT

The management of InterOil Corporation is responsible for the financial information and operating data presented in this Annual Report.

The consolidated financial statements have been prepared by management in accordance with Canadian generally accepted accounting principles. When alternative accounting methods exist, management has chosen those it deems most appropriate in the circumstances. Financial statements are not precise as they include certain amounts based on estimates and judgments. Management has determined such amounts on a reasonable basis in order to ensure that the financial statements are presented fairly, in all material respects. Financial information presented elsewhere in this Annual Report has been prepared on a basis consistent with that in the consolidated financial statements.

InterOil Corporation maintains systems of internal accounting and administrative controls. These systems are designed to provide reasonable assurance that the financial information is relevant, reliable and accurate and that the Company’s assets are properly accounted for and adequately safeguarded.

The Audit Committee, appointed by the Board of Directors, is composed of independent non-management directors. The Committee meets regularly with management, as well as the external auditors, to discuss auditing, internal controls, accounting policy and financial reporting matters. The Committee reviews the annual consolidated financial statements with both management and the independent auditors and reports its findings to the Board of Directors before such statements are approved by the Board.

The 2006 consolidated financial statements have been audited by PricewaterhouseCoopers, the independent auditors, in accordance with Canadian generally accepted auditing standards on behalf of the shareholders. PricewaterhouseCoopers has full and free access to the Audit Committee.

As noted in the superseded consolidated financial statements for the Company for the year ended December 31, 2006 issued on March 30, 2007, Management has been liaising with the Securities Exchange Commission (‘SEC’ or ‘Commission’) in relation to comments initially raised by the SEC staff in July 2006 on the Form 40-F filed for the year ended December 31, 2005. The queries were primarily in relation to the accounting treatment of the Indirect Participation Interest agreement # 3 (refer to note 19) as a conveyance in accordance with SFAS 19 – ‘Financial Accounting and Reporting by Oil and Gas Producing Companies’. The SEC staff had also raised comments about other matters related to the accounting treatment of Indirect Participation Interest agreement # 3 such as the bifurcation of the derivative, the fair value methodologies applied and the application of accretion expense.

Based on discussions with the SEC staff, Management has restated the consolidated financial statements for the year ended December 31, 2006 and 2005 to reflect a revised model for the accounting treatment of non-financial liability relating to indirect participation interest. These revised consolidated financial statements reflect all changes that have been made in relation to the revised model for the accounting treatment of this non-financial liability in the balance sheet of InterOil as at December 31, 2006 and December 31, 2005, and the statements of operations, shareholders’ equity and cash flows for each of the years then ended. These revised consolidated financial statements will have the effect of superseding the previously issued consolidated financial statements for year ended December 31, 2006 and 2005 on March 30, 2007.

Management’s original model, reflected in the superseded consolidated financial statements, considered there was sufficient evidence within the terms of the agreement to support the view that the conveyance of a mineral interest had occurred and should be accounted for in accordance was SFAS 19. Management applied judgment to the facts presented and concluded that sufficient risks and benefits of ownership had passed to the IPI investors. The equity conversion option was considered incidental and designed to recoup some of the initial investment if all 8 wells in the program were dry and abandoned.

Management has adopted a revised model which recognizes the equity conversion option feature present in the IPI agreement as an impediment to conveyance accounting under SFAS 19. Based on the revised treatment, the non-financial liability will be maintained at the previously determined undiscounted value ($105,000,000 less transaction costs) until the conveyance is deemed to have occurred. The conveyance will take place if the share conversion option is forfeited which occurs when the investors decide to convert their indirect participation interest in the program into a direct interest in the Production Development Licence (‘PDL’) for a successful well or by other means as specified in the agreement. This is based on the view that the investors have the option to convert their IPI interest into InterOil’s shares at any point in time from the date of the agreement until the equity conversion option is forfeited. The conversion of the option to shares during the exploration program would have resulted in funding provided by the IPI investors being the purchase price for InterOil’s shares rather than funding for a participation interest in InterOil’s exploration program.


InterOil Corporation Revised Consolidated Financial Statements (Expressed in United States dollars)

Management has adopted an accounting policy change to value the liability component first and assign the residual value to the equity component. This is in contrast to the relative fair value approach adopted earlier to value the liability and equity components in the contract. The residual basis methodology has been adopted due to difficulties in reliably estimating the fair value of the equity component (taking into account all the scenarios in which the values of both the drilling program interests and common shares could change) and appropriately applying the relative fair value approach. The non-financial liability has been valued at $105,000,000, being the estimated expenditures to complete the eight well drilling program (same estimate as disclosed in December 31, 2005 financials), and the residual value of $20,000,000 has been allocated to conversion option presented under Shareholder’s equity.

Given below is a summary of revised accounting treatment of the indirect participation interest contract and its impact on the consolidated financial statements:

Conveyance accounting under SFAS 19 adopted by the Company from day one under the original model has been reversed and non-financial liability maintained at initially recognized value of $105,000,000, being the estimated cost of completing the eight well program, less transaction costs. The remaining $20,000,000 has been bifurcated and presented under equity for conversion options under residual basis. Under the revised model adopted, conveyance accounting will be triggered only on the lapse of conversion option available to the investors or they elect to participate in the PDL for a successful well. This adjustment has the effect of increasing the IPI liability from the superseded balance as at December 31, 2006 by $51,259,148 (2005 — $31,774,513).

As conveyance accounting is not triggered from day one under the revised model, the Company will account for the exploration costs relating to the eight well program under successful efforts accounting policy adopted by the Company as noted under note 3(r) – ‘Oil and gas properties’. All geological and geophysical (‘G&G’) costs relating to the exploration program will be expensed as incurred and all drilling costs will be capitalized and assessed for recovery at each period. Under the earlier model, all costs relating to the eight well exploration program (covered by the IPI Agreement) was directly offset against the IPI liability and not capitalized to ‘Oil and gas properties’ or expensed in InterOil’s Statement of income. This was based on Management’s view that the conveyance had occurred from day one of the Agreement and these exploration costs were being expended on behalf of the IPI Investors, reducing the IPI liability in the process. This adjustment would result in higher exploration expenses and exploration impairment in both financial years, 2006 and 2005, relating to G&G costs and exploration impairment relating to Black Bass and Triceratops prospects. This adjustment has the effect of increasing the exploration costs for the year ended December 31, 2006 by $4,519,195 (2005 – $11,009,434) and exploration impairment for the year ended December 31, 2006 by $1,230,262 (2005 – $17,425,644).

Management has adopted an accounting policy change to use residual value approach and value the liability component first and assign the residual value to the equity component. The residual basis methodology has been adopted due to difficulties in reliably estimating the fair value of the equity component (taking into account all the scenarios in which the values of both the drilling program interests and common shares could change) and appropriately applying the relative fair value approach. The non-financial liability has been valued at $105,000,000, being the estimated expenditures to complete the eight well drilling program (same estimate as disclosed in December 31, 2005 financials), and the residual value of $20,000,000 has been allocated to conversion option presented under Shareholder’s equity. This adjustment has the effect of increasing the IPI liability from the superseded balance as at December 31, 2006 by $5,475,368 (2005 — $5,475,368).

For U.S. GAAP reporting, the Company has opted to utilize the scope exception under SFAS 133 Para 10(f) for ‘derivatives that serve as impediments to sales accounting’. This will result in non-financial liability maintained at full value of $125,000,000 less the transaction costs. This adjustment has the effect of increasing the IPI liability from the superseded balance as at December 31, 2006 by $27,249,587 (2005 — $27,249,587). The IPI liability balance will also be impacted by the revaluation of the conversion option noted below.

As a result of adopting the revised model, the conversion option will no longer be bifurcated and revalued under U.S. GAAP. This will result in the reversal of all revaluations performed at each period end for U.S. GAAP reporting. This adjustment will have the impact of reducing the U.S. GAAP loss for year ended December 31, 2006 by $19,755,017 (2005 — increase the loss by $4,279,284). This adjustment will also have the corresponding effect on ‘IPI liability’ balance carried forward in the balance sheet.

Under Canadian GAAP, should the conversion option be exercised by an investor, the non-financial liability and conversion option feature relating to that investor would be transferred to share capital for the number of shares issued. Under U.S. GAAP, should the conversion option be exercised by an investor, only the non-financial liability relating to that investor would be transferred to share capital as the conversion option is no longer bifurcated. There were no exercise of the conversion option to InterOil shares during the financial years ended December 31, 2006 and 2005.


InterOil Corporation Revised Consolidated Financial Statements (Expressed in United States dollars)

As noted above, the Company had, under the original model, bifurcated the non-financial liability and equity conversion option feature, and based on this allocation, the initial value of the non-financial liability did not represent the total expected cash costs to fulfill the contract. InterOil had accreted the non-financial liability upwards to reflect the cost of completion of the eight well program over the budgeted timeline of the program. Based on the revised model, the liability is maintained at full value and accretion costs are no longer recognized. This adjustment has the effect of reducing the loss for the year ended December 31, 2006 by $3,514,368 (2005 – $5,647,491).

Management has applied the same methodology on the discounting and accretion expense in relation to the PNG Drilling Ventures liability and reversed the initial discounting of the liability on recognition and the related accretion charges. This adjustment has the effect of increasing the ‘Loss on amendment of Indirect Participation Interest – PNGDV’ by $404,520 (2005 – nil) and decreasing the accretion expense by $226,886 (2005 – nil) resulting in a net income statement impact of increasing the loss for the for the year ended December 31, 2006 by $177,634 (2005 – nil). These adjustments have the corresponding effect of increasing the Indirect Participation Interest – PNGDV’ liability as at December 31, 2006 by the net amount.

When conveyance is triggered on election by the investors to participate in a Production Development Licence (PDL) or when the investor forfeits the conversion option, conveyance accounting will be applied. This would entail determination of proceeds for the interests conveyed and the cost of that interest as represented in the ‘Oil and gas properties’ in the balance sheet. The difference between proceeds on conveyance and capitalized costs to the interests conveyed will be recognized as gain or loss in the Statement of operations following the guidance in paragraphs 47(h) and 47(j) of SFAS 19. There is no impact on the consolidated financial statements for the years ended December 31, 2006 and 2005 due to this adjustment as conveyance has not yet occurred under the revised model during these years.

The net receipt of funds from IPI investors as part of the IPI#3 Agreement amounting to $116,861,259 was previously disclosed as part of proceeds from investing activities in the Statement of Cash flows. This has now been revised and the amount disclosed as proceeds from financing activities.

Under Canadian GAAP, the impact of all the above adjustments on the consolidated statement of income for the years ended December 31, 2006 and 2005 has been an increase in the loss by $2,412,723 ($0.08 per share) and $22,787,587 ($0.79 per share) respectively.

Under U.S. GAAP, the impact of all the above adjustments on the consolidated statement of income for the years ended December 31, 2006 and 2005 has been an decrease in the loss by $17,342,294 ($0.59 per share) and increase in the loss by $27,066,871 ($0.94 per share) respectively.

In accordance with IPI Agreement, InterOil has made cash calls for the extended well programs performed on the exploratory wells that form part of the IPI Agreement, i.e. Black Bass and Triceratops. These are additional cash calls made from the IPI investors for their interest in specific extended well programs undertaken by the Company. These cash calls were shown as a liability when received and reduced as amounts were spent on the extended well programs. There has been no change to the accounting treatment of the cash calls as these amounts are received for specific programs and there is no conversion option feature or any changes to the investor participation interest due to contributions to these cash calls.

Management would like to emphasize that the changes to the accounting treatment resulting from the adoption of the revised model for the recording of the IPI Agreement will not affect the cash position of the company.

For further details regarding the revisions made to the consolidated financial statements, and reconciliations of the restated and superseded balances, please refer note 2 of the consolidated financial statements.


Phil Mulacek		Collin Visaggio
Chief Executive Officer		Chief Financial Officer

INDEPENDENT AUDIT REPORT TO THE SHAREHOLDERS OF INTEROIL CORPORATION

We have audited the revised balance sheet of InterOil Corporation as at December 31, 2006 and December 31, 2005, and the revised statements of operations, shareholders’ equity and cash flows for each of the years then ended. These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our audit.

We conducted our audit in accordance with Canadian generally accepted auditing standards. Those standards require that we plan and perform an audit to obtain reasonable assurance whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation.

In our opinion, these revised financial statements present fairly, in all material respects, the financial position of the Company as at December 31, 2006 and December 31, 2005 and the results of its operations and its cash flows for each of the years then ended in accordance with Canadian generally accepted accounting principles.

Our previous report dated March 30, 2007 has been withdrawn and the financial statements have been revised as explained in Note 2 and the US GAAP reconciliation in Note 27.

(Signed) PricewaterhouseCoopers

Melbourne, Australia
March 30, 2007, except as to Note 2 and Note 27 which are as of October 29, 2007

AUDITORS’ REPORT TO THE SHAREHOLDERS

We have audited the consolidated balance sheet of InterOil Corporation as at December 31, 2004 and the consolidated statements of operations, shareholders’ equity, and cash flows for the year ended December 31, 2004. These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our audit.

In our opinion, these consolidated financial statements present fairly, in all material respects, the financial position of the Company as at December 31, 2004 and the results of its operations and its cash flows for the year ended December 31, 2004 in accordance with Canadian generally accepted accounting principles.

(signed) KPMG

Sydney, Australia
March 4, 2005


InterOil Corporation Revised Consolidated Balance Sheets (Expressed in United States dollars)


	As at
	December 31,			December 31,			December 31,
	2006			2005			2004
	$ (Restated)			$ (Restated)			$

Assets
Current assets:
Cash and cash equivalents (note 6)		31,681,435			59,601,807			28,544,398
Cash restricted (note 8)		29,301,940			16,452,216			15,497,127
Trade receivables (note 9)		67,542,902			49,958,973			58,698,069
Commodity derivative contracts (note 8)		1,759,575			1,482,798			503,500
Other assets		2,954,946			1,011,195			806,123
Inventories (note 10)		67,593,558			44,087,484			27,916,902
Prepaid expenses		880,640			638,216			190,135

Total current assets		201,714,996			173,232,689			132,156,254
Cash restricted (note 8)		3,217,284			210,053			102,096
Deferred financing costs (note 18)		1,716,757			1,256,816			1,311,488
Plant and equipment (note 11)		242,642,077			237,399,148			244,363,355
Oil and gas properties (note 12)		54,524,347			19,738,927			6,605,360
Future income tax benefit (note 13)		1,424,014			1,058,898			1,303,631

Total assets		505,239,475			432,896,531			385,842,184

Liabilities and shareholders’ equity
Current liabilities:
Accounts payable and accrued liabilities		73,310,793			26,005,034			26,328,544
Income tax payable		2,784,576			3,900,459			2,881,398
Working capital facility — crude feedstock (note 14)		36,873,508			70,724,322			76,520,541
Deferred hedge gain (note 8)		1,385			1,016,998			537,358
Business combination financing (note 15)		—			—			12,123,106
Unsecured loan (note 17)		—			21,453,132			—
Due to related parties (note 16)		—			—			1,056,251
Deferred liquefaction project liability (note 18)		6,553,080			—			—
Current portion of secured loan (note 18)		13,500,000			9,000,000			9,000,000
Current portion of indirect participation interest — PNGDV (note 19)		730,534			—			—

Total current liabilities		133,753,876			132,099,945			128,447,198
Accrued financing costs (note 18)		1,087,500			921,109			863,329
Secured loan (note 18)		184,166,433			71,500,000			76,000,000
Indirect participation interest (note 19)		96,861,259			96,861,259			13,749,852
Indirect participation interest — PNGDV (note 19)		1,190,633			9,685,830			10,608,830

Total liabilities		417,059,701			311,068,143			229,669,209

Non-controlling interest (note 20)		5,759,206			6,023,149			6,404,262

Shareholders’ equity:
Share capital (note 21)		233,889,366			223,934,500			216,813,654
Authorised — unlimited
Issued and outstanding - 29,871,180 (Dec 31, 2005 - 29,163,320) (Dec 31, 2004 - 28,310,884)
Contributed surplus		4,377,426			2,933,586			1,841,776
Warrants (note 23)		2,137,852			2,137,852			2,258,227
Foreign currency translation adjustment		1,492,869			477,443			463,200
Conversion options (note 19)		20,000,000			20,000,000			—
Accumulated deficit		(179,476,945	)		(133,678,142	)		(71,608,144	)

Total shareholders’ equity		82,420,568			115,805,239			149,768,713

Total liabilities and shareholders’ equity		505,239,475			432,896,531			385,842,184

See accompanying notes to the consolidated financial statements. Commitments and contingencies (note 25)

On behalf of the Board — Phil Mulacek, Director Christian Vinson, Director


InterOil Corporation Revised Consolidated Statement of Operations (Expressed in United States dollars)


	December 31,			December 31,			December 31,
	2006			2005			2004
	$ (Restated)			$ (Restated)			$

Revenue
Sales and operating revenues		511,087,934			481,180,645			70,644,486
Interest		3,223,995			1,830,808			382,461
Other		3,747,603			528,270			196,337

		518,059,532			483,539,723			71,223,284


Expenses
Cost of sales and operating expenses		499,494,540			467,246,990			65,344,516
Administrative and general expenses		20,728,618			14,672,793			7,831,550
Depreciation and amortization		12,352,672			11,036,550			639,075
Exploration costs, excluding exploration impairment (note 12)		6,176,866			11,009,434			2,903,313
Exploration impairment (note 12)		1,647,185			19,570,073			35,566,761
Legal and professional fees		3,937,517			3,606,415			3,573,727
Short term borrowing costs		8,478,540			8,855,857			4,705,190
Long term borrowing costs		11,856,872			6,351,337			1,401,256
Loss on amendment of indirect participation interest — PNGDV (note 19)		1,851,421			—			—
Foreign exchange loss/(gain)		(4,744,810	)		796,590			392,805

		561,779,421			543,146,039			122,358,193

Loss before income taxes and non-controlling interest		(43,719,889	)		(59,606,316	)		(51,134,909	)

Income taxes
Current		(1,232,487	)		(2,605,265	)		(2,538,410	)
Future		(1,110,386	)		(226,729	)		663,347

		(2,342,873	)		(2,831,994	)		(1,875,063	)

Loss before non-controlling interest		(46,062,762	)		(62,438,310	)		(53,009,972	)


Non-controlling interest (note 20)		263,959			368,312			70,091


Net loss		(45,798,803	)		(62,069,998	)		(52,939,881	)


Basic loss per share (note 21)		(1.55	)		(2.15	)		(2.09	)
Diluted loss per share (note 21)		(1.55	)		(2.15	)		(2.09	)
Weighted average number of common shares outstanding
Basic and diluted		29,602,360			28,832,263			25,373,575

See accompanying notes to the consolidated financial statements


InterOil Corporation Revised Consolidated Statement of Cash Flows (Expressed in United States dollars)


	December 31,			December 31,			December 31,
	2006			2005			2004
	$ (Restated)			$ (Restated)			$

Cash flows provided by (used in):

Operating activities
Net (loss) (note 5)		(45,798,803	)		(62,069,998	)		(52,939,881	)
*Adjustments for non-cash transactions*
Non-controlling interest		(263,959	)		(381,113	)		(70,091	)
Depreciation and amortization		12,352,672			11,036,550			639,075
Future income tax asset		1,333,108			244,733			(663,347	)
Loss/(gain) on sale of other assets		—			—			(94,260	)
Loss/(gain) on sale of plant and equipment		263,945			(95,053	)		—
Impairment of plant and equipment		755,857			—			—
Amortization of discount on debt		28,891			161,255			604,045
Amortization of deferred financing costs		219,033			154,672			268,873
Debt conversion settlement expense — debentures (note 23)		—			—			77,589
Interest expense forfeited by debenture holders		—			—			998,438
Loss/(gain) on unsettled hedge contracts		(71,875	)		119,200			33,858
Gain on derivative contracts		(1,220,500	)		(585,000	)		—
Stock compensation expense		1,976,072			1,668,896			1,209,921
Inventory revaluation		—			355,215			1,508,334
Oil and gas properties expensed		7,824,051			30,579,507			38,470,074
Loss on amendment of indirect participation interest — PNGDV		1,851,421			—			—
Unrealized foreign exchange loss/(gain)		(4,744,810	)		796,590			392,805
Non-cash interest on secured loan facility		2,926,025			—			—
*Change in non-cash operating working capital*
(Increase)/decrease in trade receivables		(6,663,218	)		8,751,789			(49,224,125	)
(Increase) in commodity derivative contracts		—			(33,858	)		—
(Increase)/decrease in other assets and prepaid expenses		4,051			(653,153	)		982,014
Decrease/ (increase) in inventories		2,642,493			(16,515,467	)		(23,240,590	)
Increase in accounts payable, accrued liabilities and income tax payable		28,773,008			3,752,531			4,183,664

		2,187,462			(22,712,704	)		(76,863,604	)


Investing activities
Expenditure on oil and gas properties		(47,990,758	)		(43,023,990	)		(22,057,419	)
Expenditure on plant and equipment		(13,585,792	)		(5,575,194	)		(38,947,904	)
Proceeds received on sale of assets		3,770,080			112,229			405,353
Redemption of short-term investments		—			—			24,723,572
Acquisition of subsidiary net of cash received (note 15)		(25,820,515	)		—			4,631,904
Repayment of business combination financing		—			(12,226,581	)		—
(Increase) in restricted cash held as security on borrowings		(15,856,955	)		(1,063,046	)		(15,501,806	)
Change in non-cash working capital
Increase/(decrease) in accounts payable and accrued liabilities		2,412,621			(3,165,756	)		4,094,594

		(97,071,319	)		(64,942,338	)		(42,651,706	)


Financing activities
Repayments of secured loan		(4,500,000	)		(4,500,000	)		—
Proceeds from indirect participation interest		—			103,111,405			13,749,852
Proceeds from secured loan, net of transaction costs		125,293,488			—			2,000,000
Net proceeds from senior convertible debentures and warrants		—			—			41,740,234
Proceeds from conversion options		—			—			3,235,000
Proceeds from related party borrowings		—			—			1,775,565
(Repayments) to related parties		—			(1,056,251	)		(2,198,065	)
Proceeds from unsecured borrowings		—			21,453,132			5,100,000
Repayments of unsecured borrowings		(21,453,132	)		—			(5,100,000	)
Proceeds from/(repayments of) working capital facility		(33,850,814	)		(5,796,219	)		76,520,541
Proceeds from issue of common shares		1,473,943			5,500,384			2,020,316

		66,963,485			118,712,451			138,843,443


Increase/(decrease) in cash and cash equivalents		(27,920,372	)		31,057,409			19,328,133
Cash and cash equivalents, beginning of period		59,601,807			28,544,398			9,216,265

Cash and cash equivalents, end of period (note 6)		31,681,435			59,601,807			28,544,398

See accompanying notes to the consolidated financial statements

See note 5 for non cash financing and investing activities


InterOil Corporation Revised Consolidated Statements of Shareholders’ Equity (Expressed in United States dollars)


	Year ended
	December 31,			December 31,			December 31,
	2006			2005			2004
	$ (Restated)			$ (Restated)			$

Share capital

At beginning of period		223,934,500			216,813,654			157,449,200
Adjustment to reflect change in accounting for employee stock options (note 3(t))		—			—			92,434
Issue of capital stock (note 21)		9,954,866			7,120,846			59,272,020

At end of period		233,889,366			223,934,500			216,813,654

Contributed surplus

At beginning of period		2,933,586			1,841,776			540,222
Adjustment to reflect change in accounting for employee stock options (note 3(t))		—			—			645,216
Stock compensation (note 22)		1,443,840			1,091,810			656,338

At end of period		4,377,426			2,933,586			1,841,776

Warrants

At beginning of period		2,137,852			2,258,227			—
Movement for period (note 23)		—			(120,375	)		2,258,227

At end of period		2,137,852			2,137,852			2,258,227

Foreign currency translation adjustment
At beginning of period		477,443			463,200			—
Movement for period, net of tax		1,015,426			14,243			463,200

At end of period		1,492,869			477,443			463,200

Conversion options

At beginning of period		20,000,000			—			—
Movement for period (note 19)		—			20,000,000			—

At end of period		20,000,000			20,000,000			—

Accumulated deficit

At beginning of period		(133,678,142	)		(71,608,144	)		(11,031,402	)
Adjustment to reflect change in accounting for employee stock options (note 3(t))		—			—			(737,650	)
Adjustment to cummulative debentures conversion expense (note 23)		—			—			(6,899,211	)
Net (loss) for period		(45,798,803	)		(62,069,998	)		(52,939,881	)

At end of period		(179,476,945	)		(133,678,142	)		(71,608,144	)

Shareholders’ equity at end of period		82,420,568			115,805,239			149,768,713

See accompanying notes to the consolidated financial statements


InterOil Corporation Notes to Revised Consolidated Financial Statements (Expressed in United States dollars)

1. Nature of operations and organization

InterOil Corporation (the “Company” or “InterOil”) is a publicly traded, integrated oil and gas company operating in Papua New Guinea (“PNG”).

Management has organized the Company’s operations into four major segments — Upstream, Midstream, Downstream and Corporate.

Upstream includes Exploration and Production operations for crude oil and natural gas in PNG. Midstream includes Liquefaction, Refining and Marketing of products both domestically in Papua New Guinea and for export. Downstream includes Wholesale and Retail Distribution of refined products in PNG. Corporate engages in business development and improvement, common services and management, financing and treasury, government and investor relations. Common and integrated costs are recovered from business segments on an equitable driver basis.

Restatement of Consolidated financial statements for the year ended December 31, 2006 and 2005

Based on discussions with the SEC staff, Management has restated the consolidated financial statements for the year ended December 31, 2006 and 2005 to reflect the revised model for the accounting treatment for non-financial liability relating to indirect participation interest. These revised consolidated financial statements reflect all changes that have made in relation to the revised model for the accounting treatment of this non-financial liability in the balance sheet of InterOil as at December 31, 2006 and December 31, 2005, and the statements of operations, shareholders’ equity and cash flows for each of the years then ended. These revised consolidated financial statements will have the effect of superseding the previously issued consolidated financial statements for year ended December 31, 2006 and 2005 on March 30, 2007.

Management has adopted a revised model which recognizes the conversion option feature present in the IPI agreement as an impediment to conveyance accounting under SFAS 19 from day one of the IPI Agreement. Based on the revised treatment, the non-financial liability will be maintained at initially recognized value ($105,000,000 less transaction costs) till the conversion feature in the agreement lapses or is exercised. The revised model proposes that conveyance accounting should not be applied till the investors elect to transfer their indirect participation interest in the program into a direct interest in the Production Development Licence (‘PDL’) for a successful well or forfeiture of the conversion option occurs as per the agreement. This was based on the view that the investors have the option to convert into InterOil’s share at any point in time from the date of the agreement till the option lapses on the occurrence of any of the conditions outlined in the contract. The exercise of the option by the investors during the exploration program would have resulted in funding provided by the IPI investors being in the nature of purchase price for InterOil’s shares rather than funding for a participation interest in InterOil’s exploration program.

Management’s original model, reflected in the superseded consolidated financial statements, was that conveyance accounting under SFAS 19 was triggered from day one as the intent of the IPI agreement was for the investors to fund eight well exploration program in Papua New Guinea in return for a twenty five percent interest in successful wells. Management’s earlier view was that the conversion option was considered only incidental to recoup some of the initial investment and would only be exercised if all the wells were dry and abandoned. The conversion option was fair valued by the management, bifurcated and disclosed separately, under equity, from the non-financial liability.

The conversion option feature in the IPI Agreement was valued and bifurcated using relative fair value approach based on CICA 3861 – ‘Financial Instruments Disclosure and Presentation’. CICA 3861 Para .22 gives the option to value the components using the relative fair value approach (as adopted earlier) or the residual method by valuing the easier component first. Management has adopted an accounting policy change to value the liability component first and assign the residual value to the equity component. This revised residual basis methodology has been adopted due to difficulties in reliably estimating the fair value of the equity component (taking into account all the scenarios in which the values of both the drilling program interests and common shares could change) and appropriately applying the relative fair value approach. The non-financial liability has been valued at $105,000,000, being the estimated expenditures to complete the eight well drilling program (same estimate as disclosed in December 31, 2005 financials), and the residual value of $20,000,000 has been allocated to conversion option presented under Shareholder’s equity.


InterOil Corporation Notes to Revised Consolidated Financial Statements (Expressed in United States dollars)

Restatement of Consolidated financial statements for the year ended December 31, 2006 and 2005 (cont’d)

Management has also resolved not to discount the liability on recognition and accrete the balance over the life of the exploration program. The transaction costs relating to the transaction amounting to $8,138,742 has been presented in accordance with EIC-94 – “Accounting for Corporate Transaction Costs”, which indicates that costs that are related to debt, should be presented as a non-current deferred charge in a classified balance sheet. The investors signed an amendment to the IPI agreement which clarified certain provisions of the IPI Agreement on the nature of costs that could be incurred with the IPI funds, including deductibility of transaction costs relating to the IPI Agreement from the IPI proceeds received on signing the agreement. As a result, the full amount of the costs relating to the IPI Agreement will be netted off against the liability.

Given below is a summary of revised accounting treatment of the indirect participation interest contract and its impact on the consolidated financial statements:

Restatement to Consolidated Balance Sheets


	December 31, 2006									December 31, 2005
	Original						Restated			Original					Restated
	Balance			Adjustments			Balance			Balance		Adjustments			Balance			Reference
	$			$			$			$		$			$

Non-current assets

Oil and gas properties (note 12)		37,449,734			17,074,613			54,524,347			16,399,492		3,339,435			19,738,927		(i), (ii)

Current and Non-current liabilities

Indirect participation interest (note 19)		49,288,602			47,572,657			96,861,259			65,258,869		31,602,390			96,861,259		(i), (iii), (iv)

Indirect participation interest — PNGDV (note 19)		1,743,533			177,634			1,921,167			9,685,830		—			9,685,830		(vi)

Shareholders’ Equity

Conversion options (note 19)		25,475,368			(5,475,368	)		20,000,000			25,475,368		(5,475,368	)		20,000,000		(iii)

Accumulated deficit (Refer ‘Restatement to Consolidated Statement of Operations’ below)		(154,276,635	)		(25,200,310	)		(179,476,945	)		(110,890,555		) (22,787,587	)		(133,678,142	)

Restatement to Consolidated Statement of Operations


	Year ended December 31, 2006							Year ended December 31, 2005
	Original					Restated		Original					Restated
	Balance		Adjustments			Balance		Balance		Adjustments			Balance		Reference
	$		$			$		$		$			$

Expenses

Exploration costs, excluding exploration impairment (note 12)		1,657,671		4,519,195			6,176,866		—		11,009,434			11,009,434	(ii)

Exploration impairment (note 12)		416,923		1,230,262			1,647,185		2,144,429		17,425,644			19,570,073	(ii)
Accretion expense (note 19)		3,741,254		(3,741,254	)		—		5,647,491		(5,647,491	)		—	(iv), (vi)

Loss on amendment of indirect participation interest — PNGDV (note 19)		1,446,901		404,520			1,851,421		—		—			—	(vi)

Total restated expenses		7,262,749		2,412,723			9,675,472		7,791,920		22,787,587			30,579,507

Net loss		43,386,080		2,412,723			45,798,803		39,282,411		22,787,587			62,069,998


InterOil Corporation Notes to Revised Consolidated Financial Statements (Expressed in United States dollars)

Restatement of Consolidated financial statements for the year ended December 31, 2006 and 2005 (cont’d)

(i)

Conveyance accounting under SFAS 19 adopted by the Company from day one under the original model has been reversed and non-financial liability maintained at initially recognized value of $105,000,000, being the estimated cost of completing the eight well program, less transaction costs. The remaining $20,000,000 has been bifurcated and presented under equity for conversion options under residual basis. Under the revised model, conveyance accounting will be triggered only on the lapse of conversion option available to the investors or they elect to participate in the PDL for a successful well. This adjustment has the effect of increasing the ‘IPI liability’ and ‘Oil and gas properties’ from the superseded balance as at December 31, 2006 by $51,259,148 (2005 — $31,774,513).

(ii)

As conveyance accounting is not triggered from day one under the revised model, the Company will account for the exploration costs relating to the eight well program under successful efforts accounting policy adopted by the Company as noted under note 3(r) – ‘Oil and gas properties’. All geological and geophysical (‘G&G’) costs relating to the exploration program will be expensed as incurred and all drilling costs will be capitalized and assessed for recovery at each period. Under the earlier model, all costs relating to the eight well exploration program (covered by the IPI Agreement) was directly offset against the IPI liability and not capitalized to ‘Oil and gas properties’ or expensed in InterOil’s Statement of income. This was based on Management’s view that the conveyance had occurred from day one of the Agreement and these exploration costs were being expended on behalf of the IPI Investors, reducing the IPI liability in the process. This adjustment results in higher exploration expenses and exploration impairment in both financial years, 2006 and 2005, relating to G&G costs and exploration impairment relating to Black Bass and Triceratops prospects. This adjustment has the effect of increasing the exploration costs for the year ended December 31, 2006 by $4,519,195 (2005 – $11,009,434) and exploration impairment for the year ended December 31, 2006 by $1,230,262 (2005 – $17,425,644). These increases to the exploration costs have the corresponding effect of reducing the ‘Oil and gas properties’ carried forward in the balance sheet from the superseded balance (and the adjustments noted above in (i)) as at December 31, 2006 and 2005 by $34,184,535 and $28,434,078 respectively.

(iii)

In the superseded financial statements, the conversion option feature in the IPI Agreement was valued and bifurcated using relative fair value approach based on CICA 3861 – ‘Financial Instruments Disclosure and Presentation’. CICA 3861 Para .22 gives the option to value the components using the relative fair value approach (as adopted earlier) or the residual method by valuing the easier component first. Based on discussions with the SEC, Management has adopted an accounting policy change to value the liability component first and assign the residual value to the equity component. This revised residual basis methodology has been adopted due to difficulties in reliably estimating the fair value of the equity component (taking into account all the scenarios in which the values of both the drilling program interests and common shares could change) and appropriately applying the relative fair value approach. The non-financial liability has been valued at $105,000,000, being the estimated expenditures to complete the eight well drilling program (same estimate as disclosed in December 31, 2005 financials), and the residual value of $20,000,000 has been allocated to conversion option presented under Shareholder’s equity. This revision was made as it was determined that the non-financial liability component was more easily measurable that the conversion option feature. This adjustment has the effect of increasing the IPI liability and correspondingly reducing the Conversion options from the superseded balance as at December 31, 2006 by $5,475,368 (2005 — $5,475,368).

(iv)		As noted above, the Company had, under the original model, bifurcated the non-financial liability and conversion option feature, and based on this allocation, the initial value of the non-financial liability did not represent the total expected cash costs to fulfill the contract. InterOil had drawn comparisons between this situation and the accounting approach that is adopted with respect to mandatory redeemable securities, where there can also be a difference between the initial value of the security and the redemption price, and accreted the non-financial liability upwards to reflect the cost of completion of the eight well program over the budgeted timeline of the program. Based on the revised model, the liability is maintained at the undiscounted value and accretion costs are no longer recognized. This adjustment has the effect of reducing the loss for the year ended December 31, 2006 by $3,514,368 (2005 – $5,647,491).

		These decreases to the accretion expenses have the corresponding effect of increasing the IPI liability in the balance sheet as at December 31, 2006 and 2005 from the superseded balance by $9,161859 and $5,647,491 respectively.

(v)

When conveyance is triggered on election by the investors to participate in a PDL or when the investor forfeits the conversion option, conveyance accounting will be applied. This would entail determination of proceeds for the interests conveyed and the cost of that interest as represented in the ‘Oil and gas properties’ in the balance sheet. The difference between proceeds on conveyance and capitalized costs to the interests conveyed will be recognized as gain or loss in the Statement of operations following the guidance in paragraphs 47(h) and 47(j) of SFAS 19. There is no impact on the consolidated financial statements for the years ended December 31, 2006 and 2005 due to this adjustment as conveyance has not been triggered based on this revised model during these years.


InterOil Corporation Notes to Revised Consolidated Financial Statements (Expressed in United States dollars)

2.		Restatement of Consolidated financial statements for the year ended December 31, 2006 and 2005 (cont’d)

(vi)		Management has applied the same methodology on the discounting and accretion expense in relation to the PNG Drilling Ventures liability and reversed the initial discounting of the liability on recognition and the related accretion charges. This adjustment has the effect of increasing the ‘Loss on amendment of Indirect Participation Interest – PNGDV’ by $404,520 (2005 – nil) and decreasing the accretion expense by $226,886 (2005 – nil) resulting in a net income statement impact of increasing the loss for the for the year ended December 31, 2006 by $177,634 (2005 – nil). These adjustments have the corresponding effect of increasing the Indirect Participation Interest – PNGDV’ liability as at December 31, 2006 by the net amount.

(vii)		The impact of all the above adjustments on the consolidated statement of income for the years ended December 31, 2006 and 2005 has been an increase in the loss by $2,412,723 ($0.08 per share) and $22,787,587 ($0.79 per share) respectively.

(viii)		The net receipt of funds from IPI investors as part of the IPI#3 Agreement amounting to $116,861,259 was previously disclosed as part of proceeds from investing activities in the Statement of Cash flows. This has now been revised and the amount disclosed as proceeds from financing activities in the respective years.

(ix)		In accordance with IPI Agreement, InterOil has made cash calls for the extended well programs performed on the exploratory wells that form part of the IPI Agreement, i.e. Black Bass and Triceratops. These are additional cash calls made from the IPI investors for their interest in specific extended well programs undertaken by the Company. These cash calls were shown as a liability when received and reduced as amounts were spent on the extended well programs. There has been no change to the accounting treatment of the cash calls as these amounts are received for specific programs and there is no conversion option feature or any changes to the investor participation interest due to contributions to these cash calls.

3. Significant accounting policies

The principal accounting policies adopted in the preparation of the financial report are set out below. These policies have been consistently applied for all years presented, unless otherwise stated.

(a) Basis of preparation

These financial statements are prepared in accordance with Canadian generally accepted accounting principles (“GAAP”) applicable to a going concern, which, in the case of the Company, differ in certain respects from those in the United States. These differences are described in note 27, Reconciliation to Accounting Principles Generally Accepted in the United States.

The consolidated financial statements for the year ended December 31, 2006 are in accordance with Canadian GAAP which requires the use of certain critical accounting estimates. It also requires management to exercise its judgment in the process of applying Company’s accounting policies. These estimates and judgments may affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reported period. Actual results could differ from these estimates.

(b) Principles of consolidation

The consolidated financial statements of the Company incorporates the assets and liabilities of InterOil Corporation as at December 31, 2006, December 31, 2005, December 31, 2004 and the results of all subsidiaries for the years then ended. Subsidiaries of InterOil Corporation include SP InterOil, LDC (“SPI”) (99.9%), SPI Exploration and Production Corporation (100%), SPI Distribution Limited (100%), InterOil Australia Pty Ltd (100%), SPI InterOil Holdings Limited (100%), Direct Employment Services Company (100%), PNG LNG, Inc (100%) and their subsidiaries. InterOil Corporation and its subsidiaries together are referred to in these financial statements as the Company or the consolidated entity.

Effective October 1, 2006 the Company acquired 100% shareholding of Shell Papua New Guinea Ltd from Shell. The acquired entity has been renamed IPL (PNG) Ltd and is a fully owned subsidiary of InterOil Products Limited. The results of IPL (PNG) Ltd have been incorporated into the Company consolidation from October 1, 2006.

During the year 2006, the Company has set up PNG LNG (Inc), a Bahamas incorporated entity, to construct and operate a Liquefied Natural Gas facility (‘LNG Project’) in PNG. The results of the LNG Project has been disclosed separately within the segment notes, refer to note 5.


InterOil Corporation Notes to Revised Consolidated Financial Statements (Expressed in United States dollars)

3. Significant accounting policies (cont’d)

Subsidiaries are all those entities over which the Company has the power to govern the financial and operating policies generally accompanying a shareholding of more than one-half of the voting rights. The existence and effect of potential voting rights that are currently exercisable or convertible are considered when assessing whether the Company controls another entity. Subsidiaries are fully consolidated from the date on which control is transferred to the Company. They are de-consolidated from the date that control ceases.

The purchase method of accounting is used to account for the acquisition of subsidiaries by the Company, refer to note 3(h). Intercompany transactions, balances and unrealized gains on transactions between Company companies are eliminated on consolidation. Minority interest in the results and equity of subsidiaries are shown separately in the consolidated statements of operations and balance sheets.

(c) Going concern

These consolidated financial statements assume that InterOil will continue in operation for the foreseeable future and will be able to realize its assets and discharge its liabilities in the normal course of operations and therefore the consolidated financial statements do not include any adjustments relating to the recoverability of assets.

As shown in the consolidated financial statements, the Company incurred a net loss of $45.8 million (2005 — $62.1 million, 2004 – $53.0 million) and generated cash from its operating activities of $2.2 million (2005 — $22.7 million, 2004 — $79.8 million) during the year ended December 31, 2006. The Company had cash and cash equivalents of $31.7 million (2005 — $59.6 million, 2004 — $28.5 million) and $32.5 million (2005 — $16.7 million, 2004 — $15.6 million) in restricted cash as at December 31 2006. The Company believes that this is sufficient to fund on-going operations. The current financial condition, among other factors, indicates that with focused management and the continued support of lenders InterOil has the ability to continue as a going concern.

The Company’s continuation as a going concern is dependent upon its ability to internally generate or externally raise additional cash to allow for the satisfaction of its obligations on a timely basis. InterOil is actively optimizing the business, improving cash generated from operations and exploring various financing alternatives. Management has initiated business improvement programs and will continue to manage value enhancing opportunities and reduce expenses until optimal operations are achieved. While the Company is exploring all opportunities to improve its financial condition, there is no assurance that these programs will be successful.

(d) Segment reporting

An operating segment (also referred to as a ‘business segment’) is a component of an enterprise:

	a.		that engages in business activities from which it may earn revenues and incur expenses (including revenues and expenses relating to transactions with other segment of the same enterprise),

	b.		whose operating results are regularly reviewed by the Company’s management to make decisions about resources to be allocated to the segment and assess its performance, and

	c.		for which discrete financial information is available.

The Company’s assets and operations are predominantly based in Papua New Guinea and therefore are disclosed as one geographical segment. Refer to note 1 for the management’s organization of the Company by business segment.

(e) Foreign currency translation

Functional and presentation currency

Items included in the financial statements of each of the Company’s entities are measured using the currency of the primary economic environment in which the entity operates (‘the functional currency’). The consolidated financial statements are presented in United States Dollars which is InterOil’s functional and presentation currency.

Group companies

For subsidiaries considered to be self-sustaining foreign operations, all assets and liabilities denominated in foreign currency are translated to United States dollars at exchange rates in effect at the balance sheet date and all revenue and expense items are translated at the rates of exchange in effect at the time of the transactions. Foreign exchange gains or losses are reported as a separate component of shareholders’ equity as a Foreign currency translation adjustment.

For subsidiaries considered to be an integrated foreign operation, monetary items denominated in foreign currency are translated to United States dollars at exchange rates in effect at the balance sheet date and non-monetary items are translated at rates of exchange in effect when the assets were acquired or obligations incurred. Revenue and expense items are translated at the rates of exchange in effect at the time of the transactions. Foreign exchange gains or losses are included in the statement of operations.


InterOil Corporation Notes to Revised Consolidated Financial Statements (Expressed in United States dollars)

3.		Significant accounting policies (cont’d)

(f)		Revenue recognition

Revenue is measured at the fair value of the consideration received or receivable. Amounts disclosed as revenue are net of returns, trade allowances and duties and taxes paid. The following particular accounting policies, which significantly affect the measurement of results and of financial position, have been applied.

Revenue from midstream operations:

Revenue from sales of products is recognized when products are shipped and the customer takes ownership and assumes risk of loss, collection of the relevant receivable is probable, persuasive evidence of an arrangement exists and the sales price is fixed or determinable. During the years ended December 31, 2006 and December 31, 2005, sales between the business segments of the Company have been eliminated from sales and operating revenues and cost of sales.

Up to December 31, 2004, the sales between business segments of the Company were eliminated from sales, operating revenues, cost of sales and refinery assets as all revenues and expenses relating to the refinery were capitalized as part of the development stage activities.

Revenue from downstream operations:

Sales of goods are recognized when the Company has delivered products to the customer, the customer takes ownership and assumes risk of loss, collection of the receivable is probable, persuasive evidence of an arrangement exists and the sale price is fixed or determinable. It is not the Company’s policy to sell products with a right of return.

Interest income:

Interest income is recognized on a time-proportionate basis.

(g) Income tax

The income tax expense or revenue for the period is the tax payable on the current period’s taxable income based on the national income tax rate for each jurisdiction adjusted by changes in deferred tax assets and liabilities attributable to temporary differences between the tax bases of assets and liabilities and their carrying amounts in the financial statements and to unused tax losses.

Deferred tax assets and liabilities are recognized for temporary differences at the tax rates expected to apply when the assets are recovered or liabilities are settled, based on those tax rates which are enacted or substantively enacted for each jurisdiction. The relevant tax rates are applied to the cumulative amounts of deductible and taxable temporary differences to measure the deferred tax asset or liability.

Deferred tax assets are recognized for deductible temporary differences and unused tax losses only if it is more likely than not that future taxable amounts will be available to utilize those temporary differences and losses. A valuation allowance is provided against any portion of a future tax asset which will more likely not be recovered.

(h) Acquisitions of assets

The purchase method of accounting is used to account for all acquisitions of assets (including business combinations) regardless of whether equity instruments or other assets are acquired. Cost is measured as the fair value of the assets given, shares issued or liabilities assumed at the date of exchange plus costs directly attributable to the acquisition.

Identifiable assets acquired and liabilities and contingent liabilities assumed in a business combination are measured initially at their fair values at the acquisition date. The excess of the cost of acquisition over the fair value of the Company’s share of the identifiable net assets is recorded as goodwill. If the cost of acquisition is less than the fair value of the net assets of the subsidiary acquired, the difference, to the extent possible, is allocated against acquired fixed assets in accordance with the standards on a pro rata basis. Any further excess is presented as an extraordinary gain in the statement of operations.

Where settlement of any part of cash consideration is deferred, the amounts payable in future are discounted to their present value as at the date of exchange. The discount rate is the Company’s incremental borrowing rate, being the rate at which similar borrowing could be obtained from an independent financier under comparable terms and conditions.

(i) Impairment of assets

Assets that are subject to amortization are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount may not be recoverable. The carrying amount of a long-lived asset is not recoverable if the carrying amount exceeds the sum of the undiscounted cash flows expected to result from its use and eventual disposition.


InterOil Corporation Notes to Revised Consolidated Financial Statements (Expressed in United States dollars)

Significant accounting policies (cont’d)

An impairment loss is recognized for the amount by which the asset’s carrying amount exceeds its fair value. Fair value is the amount of the consideration that would be agreed upon in an arm’s length transaction between knowledgeable, willing parties who are under no compulsion to act. When no liquid market exists, the fair value is the present value of future cash flows discounted at the risk free rate of interest plus a risk premium. If an impairment loss is recognized, the adjusted carrying amount becomes the new cost basis.

For the purposes of assessing impairment, assets are grouped at the lowest levels for which there are separately identifiable cash flows.

(j)

Cash and cash equivalents

Cash and cash equivalents includes cash on hand, deposits held at call with financial institutions, other short-term, highly liquid investments with original maturities of three months or less that are readily convertible to known amounts of cash and which are subject to insignificant risk of changes in value.

(k)

Restricted cash

Restricted cash consists of cash on deposit with a maturity of less than three months at the time of purchase but which is restricted from being used in daily operations. Restricted cash is carried at cost and any accrued interest is classified under other assets.

(l)

Trade receivables

The collectibility of trade receivables is assessed on an ongoing basis. Debts which are known to be uncollectible are written off. A provision for doubtful receivables is established when there is objective evidence that the Company will not be able to collect all amounts due according to the original terms of the receivables. The amount of provision is recognized in the statement of operations.

The Company sells certain trade receivables with recourse to BNP Paribas under its working capital facility. The receivables are retained on the balance sheet as the Company retains control over these receivables.

(m)

Inventory

Raw materials and stores and finished goods

Raw materials and stores and finished goods are stated at the lower of costs and net realizable value. Costs comprise direct materials, direct labor and an appropriate proportion of variable and fixed overhead expenditure. Net realizable value is the estimated selling price in the ordinary course of the business less the estimated costs of completion and the estimated costs necessary to make the sale.

Crude oil and refined petroleum products

Crude oil and refined petroleum products are recorded on a first-in, first-out basis and the net realizable value test for crude oil and refined petroleum products are performed separately. The cost of midstream refined petroleum product consists of raw material, labour, direct overheads and transportation costs. The cost of downstream refined petroleum product includes the cost of the product plus related freight, wharfage and insurance.

(n)

Assets held for sale

Non-current assets are classified as held for sale and stated at the lower of their carrying amount and fair value less costs to sell if their carrying amount will be recovered principally through a sale transaction rather than through continuing use.

An impairment loss is recognized for any initial or subsequent write down of the asset (or disposal group) to fair value less costs to sell. A gain is recognized for any subsequent increase in fair value less costs to sell an asset but not in excess of any cumulative impairment loss previously recognized. A gain or loss not previously recognized by the date of sale of the non-current asset is recognized at the date of derecognition.

Non-current assets are not depreciated or amortized while they are classified as held for sale. Interest and other expenses attributable to the liabilities of a disposal group classified as held for sale continue to be recognized.

Non-current assets classified as held for sale are presented separately from other assets in the balance sheet. The liabilities of a disposal group classified as held for sale are presented separately from other liabilities in the balance sheet.


InterOil Corporation Notes to Revised Consolidated Financial Statements (Expressed in United States dollars)

3.		Significant accounting policies (cont’d)

(o)		Derivative financial instruments

Derivative financial instruments are utilized by the Company in the management of its crude purchase cost exposures and its finished products sales price exposures. The Company’s policy is not to utilize derivative financial instruments for trading or speculative purposes. The Company may choose to designate derivative financial instruments as hedges.

When applicable, at the inception of the hedge, the Company formally documents all relationships between hedging instruments and hedged items, as well as its risk management objective and strategy for undertaking various hedge transactions, the nature of the risk being hedged, how the hedging instruments’ effectiveness in offsetting the hedged risk will be assessed and a description of the method for measuring effectiveness. This process includes linking all derivatives to specific assets and liabilities on the balance sheet or to specific firm commitments or anticipated transactions. The Company also assesses whether the derivatives that are used in hedging transactions are highly effective in offsetting changes in fair value or cash flows of hedged items at inception and on an ongoing basis.

Changes in the fair value of a derivative that is highly effective and that is designated and qualifies as a cash-flow hedge are recorded in a separate component of liabilities until earnings are affected by the variability in cash flows of the designated hedged item.

The Company discontinues hedge accounting prospectively when it is determined that the derivative is no longer effective in offsetting changes in cash flows of the hedged item, the derivative expires or is sold, terminated or exercised, the derivative is no longer designated as a hedging instrument because it is unlikely that a forecasted transaction will occur, a hedged firm commitment no longer meets the definition of a firm commitment or management determines that designation of the derivative as a hedging instrument is no longer appropriate.

In all situations in which hedge accounting is discontinued, the Company continues to carry the derivative at its fair value on the balance sheet and recognizes any subsequent changes in its fair value in earnings. The adjustment of the carrying amount of the hedged asset or liability is accounted for in the same manner as other components of the carrying amount of that asset or liability. When hedge accounting is discontinued because it is probable that a forecasted transaction will not occur, the Company recognizes it immediately in earnings gains and losses that were previously accumulated in a separate component of liabilities.

The Company enters into crude swaps in order to reduce the impact of fluctuating crude prices on its cost of sales. These swap agreements require the periodic exchange of payments without the exchange of the notional product amount on which the payments are based. The Company designates its crude price swap agreements as hedges of the underlying purchase. Cost of sales is adjusted to include the payments made or received under the crude purchase cost swaps.

The Company enters into naphtha, diesel and jet kerosene swaps in order to reduce the impact of fluctuating naphtha, jet kerosene and diesel prices respectively on its revenue. These swap agreements require the periodic exchange of payments without the exchange of the notional product amounts on which the payments are based. The Company designates its naphtha, diesel and jet kerosene price swap agreements as hedges of the underlying sale. Sales revenue of the respective product is adjusted to include the payments made or received under the price swaps.

(p)

Deferred financing costs

Deferred financing costs represent the unamortized financing costs paid to secure borrowings. Amortization is provided on a straight-line basis over the term of the related debt and is included in expenses for the period.

(q)

Plant and equipment

Refinery assets

The Company’s most significant item of plant and equipment is the oil refinery in Papua New Guinea which is included within midstream assets. During 2004, the Company was considered to be in the construction and pre-operating stage of development of the oil refinery, however, the pre-operating stage ceased on January 1, 2005. Project costs, net of any recoveries, incurred during the pre-operating stage were capitalized as part of plant and equipment. Development costs and the costs of acquiring or constructing support facilities and equipment are also capitalized.

The refinery assets are recorded at cost. Interest costs relating to the construction and pre-operating stage of the development project prior to commencement of commercial operations were capitalized as part of the cost of such plant and equipment.

Refinery related assets are depreciated on straight line basis over their useful lives, at an average rate of 4% per annum. The refinery is built on land leased from the Independent State of Papua New Guinea. The lease expires on July 26, 2097 and does not outline any terms for restoration and closure costs.


InterOil Corporation Notes to Revised Consolidated Financial Statements (Expressed in United States dollars)

3. Significant accounting policies (cont’d)

Repairs and maintenance costs, other than major turnaround costs, are charged to earnings as incurred. Major turnaround costs will be deferred to other assets when incurred and amortized over the estimated period of time to the next scheduled turnaround. No major turnaround costs had been incurred at December 31, 2006.

Other assets

Property, plant and equipment are recorded at cost. Depreciation of assets begins when the asset is in place and ready for its intended use. Assets under construction and deferred project costs are not depreciated. Depreciation of plant and equipment is calculated using the straight line method, based on the estimated service life of the asset. Maintenance and repair costs are expensed as incurred. Improvements that increase the capacity or prolong the service life of an asset are capitalized. The depreciation rates by category are as follows:


Downstream	0% - 25	%
Midstream	1% - 33	%
Upstream	4% - 100	%
Corporate	13% - 33	%

During the year 2006, InterOil has adopted a deminimus threshold of $5,000 below which all capital purchases are expensed in the period of purchase.

Leased assets

Leases of property, plant and equipment where the Company has substantially all the risks and rewards of ownership are classified as finance leases. Finance leases are classified at the lease’s inception at the lower of the fair value of the leased property and the present value of the minimum lease payments. The corresponding rental obligations, net of finance charges, are included in other long term payables. Each lease payment is allocated between the liability and the finance charges so as to achieve a constant rate on the finance balance outstanding. The interest element of the finance cost is charged to the statement of operations over the lease period so as to produce a constant periodic rate of interest on the remaining balance of the liability for each period. The property, plant and equipment acquired under finance leases are depreciated over the shorter of asset’s useful life and the lease term.

Leases in which a significant portion of the risks and rewards of ownership are retained by the lessor are classified as operating leases. Operating lease payments are representative of the pattern of benefit derived from the leased asset and accordingly are included in expenses in the periods in which they are incurred.

Asset retirement obligations

Estimated costs of future dismantlement, site restoration and abandonment of properties are provided based upon current regulations and economic circumstances at year end. Management estimates there are no material obligations associated with the retirement of the refinery or with its normal operations relating to future restoration and closure costs. The refinery is built on land leased from the Independent State of Papua New Guinea. The lease expires on July 26, 2097.

Environmental remediation

Remediation costs are accrued based on estimates of known environmental remediation exposure. Ongoing environmental compliance costs, including maintenance and monitoring costs, are expensed as incurred. Provisions are determined on an assessment of current costs, current legal requirements and current technology. Changes in estimates are dealt with on a prospective basis. As at December 31, 2006, no provision has been raised.

Disposal of property, plant and equipment

At the time of disposition of plant and equipment, accounts are relieved of the asset values and accumulated depreciation and any resulting gain or loss is included in the statement of operations.

(r) Oil and gas properties

The Company uses the successful-efforts method to account for its oil and gas exploration and development activities. Under this method, costs are accumulated on a field-by-field basis with certain exploratory expenditures and exploratory dry holes being expensed as incurred. The Company continues to carry as an asset the cost of drilling exploratory wells if the required capital expenditure is made and drilling of additional exploratory wells is underway or firmly planned for the near future or when exploration and evaluation activities have not yet reached a stage to allow reasonable assessment regarding the existence of economical reserves. Capitalized costs for producing wells will be subject to depletion on the units-of-production method.

Geological and geophysical costs are expensed as incurred, except when they have been incurred to facilitate production techniques, to increase total recoverability and to determine the desirability of drilling additional development wells within a proved area. Geological and geophysical costs capitalized would be included as part of the cost of producing wells and be subject to depletion on the units-of-production method.


InterOil Corporation Notes to Revised Consolidated Financial Statements (Expressed in United States dollars)

3.		Significant accounting policies (cont’d)

(s)		Accounts payable and accrued liabilities

These amounts represent liabilities for goods and services provided to the Company prior to the end of financial year which are unpaid. These amounts are unsecured and are usually paid within 30 days of recognition.

(t) Employee entitlements

Wages and salaries, and annual leave

Liabilities for wages and salaries, including annual leave expected to be settled within 12 months of the reporting date are recognized in accounts payables in respect of employees’ services up to the reporting date and are measured at the amounts expected to be paid when liabilities are settled.

Long Service Leave

The liability for long service leave is recognized in the provision for employee benefits and measured as the present value of expected future payments to be made in respect of services provided by employees up to the reporting date. Consideration is given to expected future wage and salary levels, experience of employee departures, periods of service and statutory obligations.

Retirement benefit obligations

The Company contributed to a defined contribution plan and the Company’s legal or constructive obligation is limited to these contributions. Contributions to the defined contribution fund are recognized as an expense as they become payable.

Stock-based compensation

Stock-based compensation benefits are provided to employees via the Company Option plan and an employee share scheme. The fair value at grant date is independently determined using a Black-Scholes option pricing model that takes into account the exercise price, the terms of the option, the vesting criteria, the share price at grant date and expected price volatility of the underlying share, the expected yield and risk-free interest rate for the term of the option. Upon exercise of options, the balance of the contributed surplus relating to those options is transferred to share capital. The Company uses the fair value based method to account for employee stock options. Under the fair value based method, compensation expense is measured at fair value at the date of grant and is expensed over the award’s vesting period.

Prior to January 1, 2004, the Company applied the fair value based method only to employee stock appreciation rights, and applied the settlement method of accounting to employee stock options. Under the settlement method, any consideration paid by employees on the exercise of stock options or purchase of stock was credited to share capital and no compensation expense was recognized. The Company adopted the fair value based method to account for employee stock options, beginning January 1, 2004. In accordance with one of the transitional options permitted, the Company has retroactively applied the fair value based method to all employee stock options granted on or after January 1, 2002, without restatement to prior periods in the year ended December 31, 2004. The effect of retroactively adopting the fair value based method to the 2004 financial statements, without restatement, was to increase the opening accumulated deficit by $737,650, increase contributed surplus by $645,216 and increase share capital by $92,434.

Profit-sharing and bonus plans

The Company recognizes a provision where contractually obliged or where there is a past practice that has created a constructive obligation.

(u) Earnings per share

Basic earnings per share

Basic common shares outstanding are the weighted average number of common shares outstanding for each period. The calculation of basic per share amounts is based on net earnings/(loss) divided by the weighted average of common shares outstanding.

Diluted earnings per share

Diluted per share amounts are computed similarly to basic per share amounts except that the weighted average shares outstanding are increased to include additional shares from the assumed exercise of stock options, conversion options and warrants, if dilutive. The number of additional shares is calculated by assuming that outstanding stock options were exercised and the proceeds from such exercises were used to acquire shares of common stock at the average price during the reporting period.

(v) Reclassification

Certain prior years’ amounts have been reclassified to conform to current presentation.


InterOil Corporation Notes to Revised Consolidated Financial Statements (Expressed in United States dollars)

4. Financial Risk Management

The Company’s activities expose it to a variety of financials risks; market risk, credit risk, liquidity risk and cash flow interest rate risk. The Company’s overall risk management program focuses on the unpredictability of markets and seeks to minimize potential adverse effects on the financial performance of the Company. The Company uses derivative financial instruments to hedge certain price risk exposures.

Risk Management is carried out by the Finance Department under policies approved by the Board of Directors. The Finance Department identifies, evaluates and hedges financial risks in close cooperation with the Company’s operating units. The Board provides written principles for overall risk management, as well as written policies covering specific areas, such as use of derivative financial instruments.

(a) Market risk

Foreign exchange risk

Foreign exchange risk arises when future commercial transactions and recognized assets and liabilities are denominated in a currency that is not the Company’s functional currency.

The Company operates internationally and is exposed to foreign exchange risk arising from currency exposures to the United States Dollar.

Most of the Company transactions are undertaken in United States Dollars, hence reducing the foreign exchange risk exposure of the Company. The Papua New Guinea Kina exposures are minimized as the downstream sales in local currency is used to adequately cover the operating expenses of the midstream refinery and downstream operations.

Price risk

The midstream refining operations of the Company are largely exposed to price fluctuations during the period between the crude purchases and the refined products leaving the refinery on sales to downstream operations and other distributors. The Company actively tries to manage the price risk by entering into derivative contracts to buy and sell crude and finished products.

The derivative contracts are entered into by the Management based on documented risk management strategies which have been approved by the Risk Management Committee. All derivative contracts entered into are reviewed by the Risk Management Committee as part of the meetings of the Committee.

Product risk

The composition of the crude feedstock will vary the refinery output of products. The 2006 output achieved includes distillates fuels, which includes diesel, gasoline and jet fuels (65%) (2005 – 55%) and naphtha and low sulphur waxy residue (28%) (2005 – 39%). The product yields obtained will vary going forward as the refinery operations are optimized and will vary based on the type of crude feedstock used.

Management tries to manage the product risk by actively reviewing the market for demand and supply, trying to maximize the production of the higher margin products and also renegotiating the selling prices for the lower margin products.

(b) Credit risk

A significant amount of the Company’s export sales are made to one customer in Singapore which represented $86,156,904 (2005 -$151,106,105) or 17% (2005 – 32%) of total sales in the year ended December 31, 2006. The Company’s domestic sales for the period ended December 31, 2006 were not dependent on a single customer or geographic region of Papua New Guinea.

The export sales to one customer cannot be considered a key risk as there is a ready market for InterOil export products and the prices are quoted on active markets.

(c) Liquidity risk

Prudent liquidity risk management implies maintaining sufficient cash and marketable securities and the availability of funding through an adequate amount of committed credit facilities. Due to the dynamic nature of the underlying business, Company Finance aims at maintaining flexibility in funding by keeping committed credit lines available.

(d) Cash flow and fair value interest rate risk

As the Company has no significant interest-bearing assets, the Company’s income and operating cash flows are substantially independent of changes in market interest rates.


InterOil Corporation Notes to Revised Consolidated Financial Statements (Expressed in United States dollars)

4. Financial Risk Management (cont’d)

The Company’s interest-rate risk arises from long-term borrowings and working capital financing facilities. Borrowings issued at variable rates expose the Company to cash flow interest-rate risk. Borrowings issued at fixed rates expose the Company to fair value interest-rate risk.

The Company’s long term borrowings mainly consists of OPIC and Merrill Lynch facilities (refer note 18) and the working capital financing facility is provided by BNP Paribas (refer note 14). Company is actively seeking to manage its cash flow and fair value interest-rate risks.

(e) Geographic risk

The operations of InterOil are concentrated in Papua New Guinea.

5. Segmented financial information (Restated)

As stated in note 1, management has identified four major business segments — upstream, midstream, downstream and corporate. The corporate segment includes assets and liabilities that do not specifically relate to the other business segments. Results in this segment primarily include financing costs and interest income.

During the year the Company has started incurring costs in relation to the Liquefaction project which has been reported separately under Midstream – Liquefaction project below.

The foreign exchange loss/(gain) for the years have been disclosed separately during the year to provide additional information to the reader. This item was classified under office and administration and other expenses in the prior periods. The prior period comparatives have been reclassified to reflect the change in disclosure.

During the year, management has also decided to reclassify the interest and other income to the relevant segments to provide additional information to the reader.

Consolidation adjustments relating to total assets relates to the elimination of intercompany loans and investments in subsidiaries.

Notes to and forming part of the segment information

Segment information is prepared in conformity with the accounting policies of the entity as disclosed in note 3.

Segment revenues, expenses and total assets are those that are directly attributable to a segment and the relevant portion that can be allocated to the segment on a reasonable basis. Upstream, midstream and downstream include costs allocated from the corporate activities based on a fee for services provided. The eliminations relate to sales and operating revenues between segments recorded at transfer prices based on current market prices and to unrealized intersegment profits in inventories.


InterOil Corporation Notes to Revised Consolidated Financial Statements (Expressed in United States dollars)

5. Segmented financial information (Restated) (cont’d)


Year ended December 31, 2006 (Restated)	Upstream			Midstream - Refining and Marketing			Midstream - Liquefaction			Downstream			Corporate			Consolidation adjustments			Total

Revenues from external customers		—			315,211,130			—			195,876,804			—			—			511,087,934
Intersegment revenues		—			136,583,916			—			22,480			8,669,933			(145,276,329	)		—
Interest revenue		2,820,888			360,319			—			100,750			1,601,491			(1,659,453	)		3,223,995
Other revenue		2,427,816			—			—			1,319,787			—			—			3,747,603

Total segment revenue		5,248,704			452,155,365			—			197,319,821			10,271,424			(146,935,782	)		518,059,532


Cost of sales and operating expenses		—			451,374,165			—			183,511,182			—			(135,390,806	)		499,494,541
Office and admin and other expenses		6,370,436			8,017,245			694,416			7,671,208			15,378,963			(8,552,604	)		29,579,664
Foreign exchange (gain)/loss		(61,423	)		(4,635,878	)		(219	)		(192,433	)		145,142			—			(4,744,811	)
Exploration costs, excluding exploration impairment		6,176,866			—			—			—			—			—			6,176,866
Exploration impairment		1,647,185			—			—			—			—			—			1,647,185
Depreciation and amortisation		806,142			10,729,546			—			909,767			37,247			(130,030	)		12,352,672
Interest expense		5,428			10,880,779			—			151,730			7,894,820			(1,659,453	)		17,273,304

Total segment expenses		14,944,634			476,365,857			694,197			192,051,454			23,456,172			(145,732,893	)		561,779,421

(Loss)/income before income taxes and non-controlling interest		(9,695,930	)		(24,210,492	)		(694,197	)		5,268,367			(13,184,748	)		(1,202,889	)		(43,719,889	)
Income tax expense		—			—			—			(2,273,773	)		(69,100	)		—			(2,342,873	)
Non controlling interest		—			259,169			—			—			—			4,790			263,959

Total net income/(loss)		(9,695,930	)		(23,951,323	)		(694,197	)		2,994,594			(13,253,848	)		(1,198,099	)		(45,798,803	)


Total assets		85,335,500			325,351,819			(683,582	)		98,722,803			393,700,711			(397,187,776	)		505,239,475


				Midstream -
				Refining and			Midstream -								Consolidation
Year ended December 31, 2005 (Restated)	Upstream			Marketing			Liquefaction		Downstream			Corporate			adjustments			Total

Revenues from external customers		—			356,326,763			—		124,853,882			—			—			481,180,645
Intersegment revenues		—			80,094,501			—		6,202			5,345,017			(85,445,720	)		—
Interest revenue		1,011,511			244,157			—		95,317			686,718			(206,895	)		1,830,808
Other revenue		283,634			496			—		245,760			30,509			(32,129	)		528,270

Total segment revenue		1,295,145			436,665,917			—		125,201,161			6,062,244			(85,684,744	)		483,539,723


Cost of sales and operating expenses		—			436,490,554			—		110,857,139			—			(80,100,703	)		467,246,990
Office and admin and other expenses		2,426,909			9,204,613			—		4,724,568			11,608,822			(5,465,658	)		22,499,254
Foreign exchange (gain)/loss		(689,084	)		1,434,498			—		843			50,333			—			796,590
Exploration costs, excluding exploration impairment		11,009,434			—			—		—			—			—			11,009,434
Exploration impairment		19,570,073			—			—		—			—			—			19,570,073
Depreciation and amortisation		314,467			10,598,134			—		204,247			49,732			(130,030	)		11,036,550
Interest expense		—			10,161,899			—		225,450			806,694			(206,895	)		10,987,148

Total segment expenses		32,631,799			467,889,698			—		116,012,247			12,515,581			(85,903,286	)		543,146,039

(Loss)/income before income taxes and non-controlling interest		(31,336,654	)		(31,223,781	)		—		9,188,914			(6,453,337	)		218,542			(59,606,316	)
Income tax expense		—			—			—		(2,755,845	)		(76,149	)		—			(2,831,994	)
Non controlling interest		—			362,140			—		—			—			6,172			368,312
Total net income/(loss)		(31,336,654	)		(30,861,641	)		—		6,433,069			(6,529,486	)		224,714			(62,069,998	)


Total assets		78,926,578			314,904,035			—		47,342,109			317,227,597			(325,503,788	)		432,896,531


InterOil Corporation Notes to Revised Consolidated Financial Statements (Expressed in United States dollars)

5. Segmented financial information (Restated) (cont’d)


				Midstream -
				Refining and			Midstream -								Consolidation
Year ended December 31, 2004	Upstream			Marketing			Liquefaction		Downstream			Corporate			adjustments			Total

Revenues from external customers		—			26,309,547			—		62,410,291			—			(18,075,352	)		70,644,486
Intersegment revenues		—			—			—		489,111			3,787,944			(4,277,055	)		—
Interest revenue		151,780			8,761			—		56,896			165,024			—			382,461
Other revenue		(39,267	)		(63,031	)		—		205,836			92,799			—			196,337

Total segment revenue		112,513			26,255,277			—		63,162,134			4,045,767			(22,352,407	)		71,223,284

Cost of sales and operating expenses		—			27,685,347			—		53,158,737			—			(15,499,568	)		65,344,516
Office and admin and other expenses		1,649,191			3,167,216			—		3,146,905			10,538,730			(3,766,608	)		14,735,434
Exchange (Gain)/loss		—			(34,121	)		—		—			—			—			(34,121	)
Exploration costs, excluding exploration impairment		2,903,313			—			—		—			—			—			2,903,313
Exploration impairment		35,566,761			—			—		—			—			—			35,566,761
Depreciation and amortisation		12,510			311,986			—		224,214			90,365			—			639,075
Interest expense		4,932			843,888			—		455,368			1,899,027			—			3,203,215

Total segment expenses		40,136,707			31,974,316			—		56,985,224			12,528,122			(19,266,176	)		122,358,193

(Loss)/income before income taxes and non-controlling interest		(40,024,194	)		(5,719,039	)		—		6,176,910			(8,482,355	)		(3,086,231	)		(51,134,909	)
Income tax expense		—			—			—		(1,899,803	)		24,740			—			(1,875,063	)
Non controlling interest		—			68,961			—		—			—			1,130			70,091

Total net income/(loss)		(40,024,194	)		(5,650,078	)		—		4,277,107			(8,457,615	)		(3,085,101	)		(52,939,881	)


Total assets		21,570,219			310,941,494			—		34,436,144			211,530,962			(192,636,636	)		385,842,184

6. Cash and cash equivalents

The components of cash and cash equivalents are as follows:


	December 31,		December 31,		December 31,
	2006		2005		2004
	$		$		$

Cash on deposit		31,681,435		59,597,724		24,224,523
Bank term deposits
- Papua New Guinea kina deposits		—		—		4,315,513
- Australian dollar deposits		—		4,083		4,362

		31,681,435		59,601,807		28,544,398


InterOil Corporation Notes to Revised Consolidated Financial Statements (Expressed in United States dollars)

7. Supplemental cash flow information


	December 31,		December 31,		December 31,
	2006		2005		2004
	$		$		$

Cash paid during the year
Interest		8,548,552		13,373,832		1,444,006
Income taxes		2,306,218		1,656,985		1,914,459
Interest received		3,154,380		1,800,062		671,479
Non-cash investing and financing activities:
Deferred financing costs included in accounts payable and accrued liabilities		500,000		100,000		—
Accrued financing costs and deferred financing costs		—		—		834,439
Increase in additional paid up capital as a result of a change in accounting policy for stock based compensation (3(t))		—		—		645,216
Decrease in plant and equipment as a result of impairment		755,857		—		—
Deferred liquefaction project liability		6,553,080		—		—
Increase in share capital from:
the exercise of share options		532,232		577,086		646,216
the exercise of warrants		—		120,375		—
change in accounting policy for stock based compensation (note 3(t))		—		—		92,434
transfer of deferred transaction costs on conversion of the debenture		—		—		(3,093,734	)
transfer of carrying value of debentures to share capital on conversion of the securities		—		—		42,890,448
conversion of indirect participation interest into share capital		7,948,691		923,000		9,226,260
shares issued to induce conversion of debentures		—		—		6,976,800
transaction costs being attributed to share capital transaction		—		—		300,000
Movement in accumulated deficit as a result of the inducement paid on conversion of the debentures		—		—		(6,899,211	)

All non-cash investing and financing activities disclosed in note 7 relate to the “corporate” segment except for that involving the decrease in plant and equipment as a result of impairment (upstream).

8. Financial instruments

Cash and cash equivalents

With the exception of cash and cash equivalents and restricted cash, all financial assets are non-interest bearing. In 2006, the Company earned 5.0% (2005 – 2.9%) on the cash on deposit which related to the working capital facility. In 2006, cash and cash equivalents earned an average interest rate of 5.1% per annum (2005 – 1.3%, 2004 – 1.6%) on cash, other than the cash on deposit that was related to the working capital facility.

Credit risk is minimized as all cash amounts and certificates of deposit are held with large banks which have acceptable credit ratings determined by a recognized rating agency. The carrying values of cash and cash equivalents, trade receivables, all other assets, accounts payable and accrued liabilities, all short-term loan facilities and amounts due to related parties approximate fair values due to the short term maturities of these instruments.


InterOil Corporation Notes to Revised Consolidated Financial Statements (Expressed in United States dollars)

8. Financial instruments (cont’d)

Cash restricted

All other components of cash and cash equivalents are non-interest bearing. Restricted cash, which mainly relates to the working capital facility, is comprised of the following:


	December 31,		December 31,		December 31,
	2006		2005		2004
	$		$		$

Cash deposit on working capital facility (5.0%)		29,301,940		16,452,216		15,497,127

Cash restricted — Current		29,301,940		16,452,216		15,497,127


Cash deposit on secured loan (3.9%)		647,502		106,267		—
Debt reserve for secured loan		2,420,000		—		—
Bank term deposits on Petroleum Prospecting Licenses (0.8%)		107,997		103,786		102,096
Cash deposit on office premises (4.5%)		41,785		—		—

Cash restricted — Non-current		3,217,284		210,053		102,096

		32,519,224		16,662,269		15,599,223

Cash held as deposit on the working capital facility supports the Company’s working capital facility with BNP Paribas. The balance is initially based on 20% of the outstanding balance of the facility subject to fluctuations or variations in inventory and accounts receivables. The cash held as deposit on secured loan supports the Company’s secured loan borrowings with the Overseas Private Investment Corporation (“OPIC”).

The debt reserve for secured loan supports the bridging facility. As part of the facility, InterOil is required to maintain two quarterly interest repayments in the debt reserve account.

Bank term deposits on Petroleum Prospecting Licenses are unavailable to the Company while Petroleum Prospecting Licenses 236, 237 and 238 are being utilized by the Company.

The prior year balances of restricted cash have been reclassified to correctly reflect the current and non-current component, consistent with the current year presentation.

Commodity derivative contracts

InterOil uses derivative commodity instruments to manage exposure to price volatility on a portion of its refined product and crude inventories.

At December 31, 2006, InterOil had a net receivable of $1,759,575 (2005 – $1,482,798, 2004 –$503,500) relating to commodity hedge contracts. Of this total, a payable of $45,925 (2005 – receivable of $897,798, 2004 – receivable of $503,500) relates to hedges deemed effective at December 31, 2006 and a receivable of $1,805,500 (2005 – $585,000, 2004 — $nil) relates to outstanding derivative contracts for which hedge accounting was not applied or had been discontinued. The gain/(loss) on hedges for which final pricing will be determined in future periods was $1,385 (2005 — $1,016,998, 2004 – $537,358). This amount has been included in the deferred hedge gain/(loss) account on the balance sheet.

As at December 31, 2006, InterOil had entered into naphtha swap agreements to hedge a portion of first quarter 2007 naphtha sales. These transactions have been hedge accounted and tested for effectiveness on a regular basis. If any of hedge accounted transactions are found to be ineffective in comparison to management’s risk mitigation policies, hedge accounting is discontinued on those transactions. The gain or loss on derivative contracts that have been hedge accounted are charged to sales or cost of sales depending on the timing of the risk the hedge was expected to cover. The unrealized gain/loss on these hedge transactions are included in deferred hedge gain/(loss) in the balance sheet until these transactions are settled. The gain on the derivative contracts for which hedge accounting has been discontinued is included in general and administration expenses for the year.

During the year, InterOil entered into Brent contracts to hedge a portion of its anticipated low sulphur waxy residue sales by buying and selling the raw material component, crude at fixed prices to match the timing of the purchase and sale respectively. These transactions are not hedge accounted and any gain/loss on these contracts are included in general and administration expenses for the year. As at December 31, 2006 of the $1,805,500 from non-hedge accounted transactions, $1,745,500 (2005 — $nil, 2004 — $nil) relates to transactions for which hedge accounting was not applied and $60,000 (2005 — $585,000, 2004 — $nil) relates to transactions for which hedge accounting was discontinued.


InterOil Corporation Notes to Revised Consolidated Financial Statements (Expressed in United States dollars)

8. Financial instruments (cont’d)

The following summarizes the effective hedge contracts by derivative type on which final pricing will be determined in future periods as at December 31, 2006:


Derivative	Type	Notional volumes (bbls)
Naphtha swap	Sell Naphtha	175,000

As at December 31, 2005:


Derivative	Type	Notional volumes (bbls)

Crude swap	Sell crude	300,000
Crude swap	Buy crude	250,000
Jet kerosene crack spread swap	Sell jet kerosene/buy crude	249,999

As at December 31, 2004:


Derivative	Type	Notional volumes (bbls)

Naphtha swap	Sell naphtha	50,000
Naphtha crack spread swap	Sell naphtha/buy crude	50,000

9. Trade receivables

InterOil has a discounting facility with BNP Paribas on specific monetary receivables under which the Company is able to sell, on a revolving basis, specific monetary receivables up to $40,000,000 (refer to note 14). As at December 31, 2006, $23,671,568 (2005 — $23,196,914, 2004 — $13,034,904) in outstanding accounts receivable had been sold with recourse under the facility. As the sale is with recourse, the receivables are retained on the balance sheet and included in the accounts receivable and the proceeds are recognized in the working capital facility. The Company has retained the responsibility for administering and collecting accounts receivable sold.

At December 31, 2006, $55,955,400 (2005 — $39,430,264, 2004 — $49,989,840) of the trade receivables secures the BNP Paribas working capital facility disclosed in note 14. This balance includes $20,186,665 (2005 — $5,059,192, 2004 — $3,078,447) of intercompany receivables which were eliminated on consolidation.

10. Inventories


	December 31,		December 31,		December 31,
	2006		2005		2004
	$		$		$

Midstream — refining and marketing (crude oil feedstock)		12,795,356		5,019,580		3,971,982
Midstream — refining and marketing (refined petroleum product)		22,329,270		25,967,357		16,396,975
Midstream — refining and marketing (parts inventory)		46,646		—		—
Downstream (refined petroleum product)		32,422,296		13,100,547		7,547,945

		67,593,568		44,087,484		27,916,902

At December 31, 2006, all inventory balances are carried at cost where as in 2005 and 2004 the balances reflected net realizable value. The net realizable value write downs for prior year 2005 and 2004 of $355,215 and $1,508,334 are included in cost of sales.

At December 31, 2006, $35,171,272 (2005 — $30,986,937, 2004 — $20,368,957) of the midstream inventory balance secures the BNP Paribas working capital facility disclosed in note 14.


InterOil Corporation Notes to Revised Consolidated Financial Statements (Expressed in United States dollars)

11. Plant and equipment

The majority of the Company’s plant and equipment is located in Papua New Guinea, except for items in the corporate segment with a net book value of $118,644 (2005 — $132,375, 2004 — $86,327) which are located in Australia. Amounts in deferred project costs and work in progress are not being amortized.

Consolidation entries relates to midstream assets which were created when the gross margin on 2004 refinery sales to the downstream segment were eliminated in the development stage of the refinery.


										Corporate &
December 31, 2006	Upstream			Midstream			Downstream			Consolidated			Totals

Plant and equipment		1,247,201			249,741,042			37,697,458			146,797			288,832,498
Deferred project costs and work in progress		—			723,566			715,653			—			1,439,219
Consolidation entries		—			—			—			(2,990,688	)		(2,990,688	)
Accumulated depreciation and amortisation		(153,455	)		(21,760,341	)		(22,697,003	)		(28,153	)		(44,638,952	)

Net book value		1,093,746			228,704,267			15,716,108			(2,872,044	)		242,642,077


Capital expenditure		—			11,948,960			10,543,842			156,817			22,649,619


										Corporate &
December 31, 2005	Upstream			Midstream			Downstream			Consolidated			Totals

Plant and equipment		5,657,125			238,078,544			12,164,417			331,183			256,231,269
Deferred project costs and work in progress		—			1,987,085			1,386,488			—			3,373,573
Consolidation entries		—			—			—			(3,120,718	)		(3,120,718	)
Accumulated depreciation and amortisation		(308,378	)		(11,245,748	)		(7,332,042	)		(198,808	)		(19,084,976	)

Net book value		5,348,747			228,819,881			6,218,863			(2,988,343	)		237,399,148


Capital expenditure		—			3,284,108			1,902,334			95,782			5,282,224


										Corporate &
December 31, 2004	Upstream			Midstream			Downstream			Consolidated			Totals

Plant and equipment		5,659,248			236,551,876			10,875,211			263,217			253,349,552
Deferred project costs and work in progress		—			—			949,924			—			949,924
Consolidation entries		—			—			—			(2,002,214	)		(2,002,214	)
Accumulated depreciation and amortisation		(19,792	)		(419,629	)		(7,317,596	)		(176,890	)		(7,933,907	)

Net book value		5,639,456			236,132,247			4,507,539			(1,915,887	)		244,363,355


Capital expenditure		1,131			40,532,990			1,320,644			83,920			41,938,685

During the year ended December 31, 2006, InterOil recognized a loss of $263,945 (2005 – gain of $95,053, 2004 – gain of $94,260) on the disposal of assets.

During 2006, InterOil sold one of the two barges included in the upstream segment. Prior to the sale, an impairment assessment was performed and an impairment loss of $755,857 was recognized. This loss is included in office and administrative expenses in the statement of operations.


InterOil Corporation Notes to Revised Consolidated Financial Statements (Expressed in United States dollars)

12. Oil and gas properties (Restated)

For detailed reconciliation of the restated and superseded balance, refer note 2 above.

Costs of oil and gas properties which are not subject to depletion are as follows:


	December 31,		December 31,		December 31,
	2006		2005		2004
	$ (Restated)		$ Restated)		$

Drilling equipment		18,242,972		15,100,860		5,353,471
Petroleum Prospecting License drilling programs at cost		36,281,375		4,638,067		1,251,889

		54,524,347		19,738,927		6,605,360

The following table discloses a breakdown of the exploration expenses presented in the statements of operations for the periods ended:


	December 31,		December 31,		December 31,
	2006		2005		2004
	$ (Restated)		$ (Restated)		$

Exploration costs, excluding exploration impairment		6,176,866		11,009,434		2,903,313
Exploration impairment
Costs incurred in prior years		—		2,059,367		16,576,982
Costs incurred in current year		1,647,185		17,510,706		18,989,779

Total exploration impairment		1,647,185		19,570,073		35,566,761

		7,824,051		30,579,507		38,470,074

13. Income taxes (Restated)

The combined income tax expense in the consolidated statements of operations reflects an effective tax rate which differs from the expected statutory rate (combined federal and provincial rates). Differences for the years ended were accounted for as follows:


	December 31,			December 31,			December 31,
	2006			2005			2004
	$ (Restated)			$ (Restated)			$

(Loss) before income taxes and non controlling interest		(43,719,889	)		(59,606,317	)		(51,134,909	)
Statutory income tax rate		35.10	%		35.10	%		35.12	%

Computed tax (benefit)		(15,345,681	)		(20,921,817	)		(17,958,580	)

Effect on income tax of:
Losses in foreign jurisdictions not deductible		251,639			2,834,689			2,273,530
Non-deductible stock compensation expense		693,601			585,783			424,924
Gains and losses on foreign exchange		(1,687,001	)		268,843			58,659
Tax rate differential in foreign jurisditions		1,103,122			696,307			(341,613	)
Over provision for tax in prior years		(51,632	)		(113,950	)		(42,874	)
Tax losses for which no future tax benefit has been brought to account		12,166,624			8,390,975			2,696,330
Temporary differences for which no future tax benefit has been brought to account		3,124,836			11,104,170			14,552,726
Temporary differences brought to account on acquisition of subsidiary		1,135,181			(34,902	)		(488,027	)
Other — net		952,183			21,896			699,988

		2,342,872			2,831,994			1,875,063


InterOil Corporation Notes to Revised Consolidated Financial Statements (Expressed in United States dollars)

13. Income taxes (Restated) (cont’d)

The future income tax asset comprised the tax effect of the following:


	December 31,			December 31,			December 31,
	2006			2005			2004
	$ (Restated)			$ (Restated)			$

Future tax assets
Temporary differences
Plant and equipment		3,030,479			2,665,173			2,263,654
Exploration expenditure		41,870,390			26,940,837			11,541,022
Other — net		122,713			99,833			127,240

		45,023,582			29,705,843			13,931,916
Losses carried forward		27,754,495			15,390,109			4,850,380

		72,778,077			45,095,952			18,782,296
Less valuation allowance		(71,354,064	)		(44,037,054	)		(17,478,665	)

		1,424,013			1,058,898			1,303,631

All future tax assets recorded in the consolidated balance sheet relate to Papua New Guinea. The amounts are non current at December 31, 2006.

The valuation allowance for deferred tax assets increased by $27,317,010 (2005 – $26,558389, 2004 – $16,114,573) in the year ended December 31, 2006. In assessing the realizability of deferred tax assets, management considers whether it is more likely than not that some portion or all of the deferred tax assets will not be realized. The ultimate realization of deferred tax assets is dependent upon the generation of future taxable income during the periods in which those temporary differences become deductible. Management considers the actual levels of past taxable income, scheduled reversal of deferred tax liabilities, projected future taxable income, projected tax rates and tax planning strategies in making this assessment. Management has determined that a 100% valuation allowance of the net operating loss carry-forward is appropriate as of December 31, 2006 in respect of losses generated from the operations.

The Refinery Project Agreement gives “pioneer” status to InterOil Limited. This status gives the Company a tax holiday beginning upon the date of the commencement of commercial production, January 1, 2005 and ending in four years on December 31, 2010.

In relation to the refinery, tax losses incurred prior to January 1, 2005 will be frozen during the five year tax holiday and will become available for use after the tax holiday ceases on December 31, 2010. Tax losses carried forward to offset against future earnings total K169,689,231 (US $54,690,839) at December 31, 2006. All losses incurred by InterOil have a twenty year carry forward period.

14. Working capital facility – crude feedstock

As at the beginning of 2006, InterOil has a working capital credit facility with BNP Paribas (Singapore branch) with a maximum availability of $150,000,000. During the year this facility was increased to a maximum availability of $170,000,000.

This financing facility supports the ongoing procurement of crude oil for the refinery and includes related hedging transactions. The facility comprises a base facility to accommodate the issuance of letters of credit followed by secured loans in the form of short term advances. In addition to the base facility, the agreement offers both a cash secured short term facility and a discounting facility on specific monetary receivables (note 9). The facility is secured by sales contracts, purchase contracts, certain cash accounts associated with the refinery, all crude and refined products of the refinery and trade receivables.

The facility bears interest at LIBOR + 2.5% on the short term advances. During the year the weighted average interest rate was 7.28% (2005 – 5.81%, 2004 – 4.36%).


InterOil Corporation Notes to Revised Consolidated Financial Statements (Expressed in United States dollars)

14. Working capital facility – crude feedstock (cont’d)

The following table outlines the facility and the amount available for use at year end:


	December 31,			December 31,			December 31,
	2006			2005			2004
	$			$			$

Working capital credit facility		170,000,000			150,000,000			100,000,000

Less amounts included in the working capital facility liability:
Short term advances		(13,201,940	)		(47,527,408	)		(63,485,637	)
Discounted receivables (note 9)		(23,671,568	)		(23,196,914	)		(13,034,904	)

		(36,873,508	)		(70,724,322	)		(76,520,541	)
Less: other amounts outstanding under the facility:
Letters of credit outstanding		(79,000,000	)		(33,765,000	)		(14,000,000	)
Hedging facility		(1,500,000	)		(1,500,000	)		—

Working capital credit facility available for use		52,626,492			44,010,678			9,479,459

At December 31, 2006, the company had two letters of credit outstanding for $79,000,000, which expire in January 2007. A letter of credit of $42,000,000 relates to a December crude receipt and expires on January 1, 2007 and a letter of credit of $37,000,000 relates to January crude receipt and expires on January 25, 2007.

The cash deposit on working capital facility, as separately disclosed in note 8, included restricted cash of $29,301,940 (2005 — $16,452,216, 2004 — $15,497,127) which was being maintained as a security market for the facility. In addition, inventory of $35,171,272 (2005 — $30,986,937, 2004 — $20,368,957) and trade receivables of $55,955,400 (2005 — $34,371,072, 2004 — $46,911,393) also secured the facility. The trade receivable balance securing the facility includes $20,186,665 (2005 — $5,059,192, 2004 — $3,078,447) of inter-company receivables which were eliminated on consolidation.

15. Acquisition of a subsidiary

IPL PNG Ltd.

On October 1, 2006, InterOil, through its wholly owned subsidiary, InterOil Products Limited acquired 100% of the outstanding common shares of Shell Papua New Guinea Limited which was subsequently renamed IPL PNG Ltd (“IPL PNG”). IPL PNG is a distributor of refined petroleum products in Papua New Guinea.

The results of IPL PNG’s operations have been included in the consolidated financial statements since October 1, 2006, the date on which control of IPL PNG’s shares was transferred to InterOil. The purchase price is $10,000,000 plus an amount equal to the net current assets of Shell based on the year ended 2005 accounts. However, if the net current assets at the transfer date exceed the net current assets in the year end 2005 accounts by more than Kina 500,000, then InterOil will pay the amount of excess to the vendor.

The transfer date accounts are being reviewed by an independent accountant to establish the final settlement of the purchase price. As at December 31, 2006, InterOil has paid $30,639,000 in cash to Shell and this balance will be further subject to a working capital adjustment. As at December 31, 2006, InterOil has accrued $1,771,000 as expected adjustment to purchase price for the working capital adjustment. In addition to the amounts paid and accrued by IPL, $171,410 of acquisition related costs have been incurred on the transaction.


InterOil Corporation Notes to Revised Consolidated Financial Statements (Expressed in United States dollars)

15. Acquisition of a subsidiary (cont’d)

The following table summarizes the estimated fair value of the assets acquired and liabilities assumed at the date of acquisition.


	$

Cash		4,989,895
Trade receivables		6,288,834
Inventory		20,429,728
Other assets		2,190,226
Future income tax benefit		1,698,224
Property, plant and equipment		8,799,691

Total assets acquired		44,396,598

Accounts payable and accrued liabilities		(11,815,188	)



Net assets acquired		32,581,410

The net cash paid on purchase of IPL PNG of $25,820,515 is comprised of $30,639,000 paid to Shell during the year and $171,410 transaction costs incurred, less $4,989,895 held by IPL PNG at the time of acquisition.

PNG LNG Inc. and Liquid Niugini Gas Ltd

In 2006, InterOil acquired 100% of the issued share capital of PNG LNG, Inc. and Liquid Niugini Gas Ltd for a total cost of $1,001. The purchase price reflected the book value of the shares at the time of acquisition as both were dormant shelf companies at the time of acquisition. These companies comprise the Midstream – liquefaction segment reported in these financials.

Direct Employment Services Company and SPI InterOil Holdings Limited

In 2005, InterOil acquired 100% of the issued share capital of Direct Employment Services Company (“DESC”) and SPI InterOil Holdings Limited for a total cost of $2,000 which was paid in cash. The purchase price reflected the book value of the shares at the time of acquisition.

DESC was initially established for the purposes of providing non-profit management services to the Company for its U.S. employees and it has continued to provide management services to the Company since its acquisition. Prior to its acquisition, DESC was partially owned by Christian Vinson, the Company’s Chief Operating Officer.

SPI InterOil Holdings Limited is a dormant shelf company to be used for a future business endeavor.

InterOil Products Limited

On April 28, 2004, InterOil, through its wholly owned subsidiary, SPI Distribution Limited, acquired 100% of the outstanding common shares of BP Papua New Guinea Limited which was subsequently renamed InterOil Products Limited (“IPL”). IPL is a distributor of refined petroleum products in Papua New Guinea.

The results of IPL’s operations have been included in the consolidated financial statements since April 28, 2004, the date control of IPL’s shares was transferred to InterOil. Under the purchase agreement, InterOil Corporation was entitled to the profit of IPL from March 1, 2004. The profit earned after tax between March 1, 2004 and April 28, 2004 of $1,243,746 was recognized as a reduction in the acquisition cost.

The adjusted purchase price is $13,226,854, including a service agreement for $1,000,000 related to the purchase. A deposit of $1,000,000 of the purchase price was paid in 2004. The remaining $12,226,854 (discounted amount $12,123,106) was paid on March 1, 2005 and was included in current liabilities in the financial statements at December 31, 2004.


InterOil Corporation Notes to Revised Consolidated Financial Statements (Expressed in United States dollars)

15. Acquisition of a subsidiary (cont’d)

The following table summarizes the estimated fair value of the assets acquired and liabilities assumed at the date of acquisition.


	$

Cash		5,859,517
Trade receivables		8,241,400
Inventory		6,759,089
Other assets		1,614,249
Future income tax benefit		640,284
Property, plant and equipment		3,180,530

Total assets acquired		26,295,069
Accounts payable and accrued liabilities		(13,399,720	)

Net assets acquired		12,895,349

The net cash received from the purchase of IPL (excluding the deferred settlement) of $4,631,904 is comprised of $5,859,517 held by IPL at the time of acquisition less $1,000,000 paid relating to the acquisition price and $227,613 paid in transaction costs and in stamp duty.

16. Related parties

Petroleum Independent and Exploration Corporation (“P.I.E”)

P.I.E is controlled by Phil Mulacek, an officer and director of InterOil and acts as a sponsor of the Company’s oil refinery project. Articles of association of SPI InterOil LDC (“SPI”) provide for the business and affairs of the entity to be managed by a general manager appointed by the shareholders of SPI and its U.S. sponsor under the Overseas Private Investment Corporation (“OPIC” - which is an agency of the U.S. Government) loan agreement. SPI does not have a Board of Directors, instead P.I.E has been appointed as the general manager of SPI. Under the laws of the Commonwealth of The Bahamas, the general manager exercises all powers which would typically be exercised by a Board of Directors, being those which are not required by laws or by SPI’s constituting documents to be exercised by the members (shareholders) of SPI.

During the year, $150,000 (2005 — $150,000, 2004 — $150,410) was expensed for the sponsor’s legal, accounting and reporting costs. These costs were included in accrued liabilities at December 31, 2006.

During the prior year ended December 31, 2005, a balance outstanding from 2004 of $1,056,251 was repaid in full. The loan had interest charged at 5.75% per annum while it was outstanding in 2005. For the year ended December 31, 2005, the Company incurred total interest to P.I.E amounting to $9,376 (2004 – $246,745). All of the interest collected by P.I.E on this loan was used to pay interest incurred under the Wells Fargo facility.

Breckland Limited

The entity is controlled by Roger Grundy, a director of InterOil, and provides technical and advisory services to the Company on normal commercial terms. Amounts paid or payable to Breckland during the year amounted to $140,165 (2005 — $179,608, 2004 — $120,426).

Direct Employment Services Company (“DESC”)

The services of certain executive officers and senior management of the Company are provided under a management services agreement with DESC. DESC is a U.S. private Company that was partially owned by Christian Vinson, the Company’s Chief Operating Officer prior to its acquisition by InterOil on November 23, 2005 (note 15). In 2005, InterOil acquired 100% of the issued share capital of the entity for a total cost of $1,000 which was paid in cash. Christian Vinson received $500 for his 50% interest in the entity. The purchase price reflects the book value of the shares at the time of acquisition. Prior to the acquisition, DESC was paid $549,978 for its management services in the nine months ended September 30, 2005 (year ended 2004 – $708,104).


InterOil Corporation Notes to Revised Consolidated Financial Statements (Expressed in United States dollars)

16. Related parties (cont’d)

Director fees

Amounts due to Directors and executives at December 31, 2006 totaled $18,000 for Directors fees (2005 — $30,500, 2004 — $61,000) and $nil for executive bonuses (2005 — $573,571, 2004- $320,000). These amounts are included in accounts payable and accrued liabilities.

BNP Paribas

One of our Directors — Edward Speal, is the President and CEO of BNP Paribas (Canada). InterOil has a working capital facility with BNP Paribas (Singapore) of $170,000,000 (as per note 14) - Management does not consider this to be related party transaction as the Director does not have the ability to exercise, directly or indirectly, control, joint control or significant influence over BNP (Singapore).

17. Unsecured loan

On January 28, 2005, InterOil obtained a $20 million term loan facility. The loan had an interest rate equal to 5% per annum payable quarterly in arrears and includes a 1% arrangement fee of the face amount. On July 21, 2005, the short term loan facility increased from $20 million to $25 million. The term of the loan was fifteen months from the initial disbursement dates, and was repayable at any time prior to expiry with no penalty.

The loan and all accrued interest was repaid during 2006 and therefore the total balance outstanding at December 31, 2006 is $nil (2005 — $21,453,132).

18. Secured loan


	December 31,		December 31,		December 31,
	2006		2005		2004
	$		$		$

Secured loan (OPIC) — current portion		13,500,000		9,000,000		9,000,000

Secured loan (OPIC) — non current portion		62,500,000		71,500,000		76,000,000
Secured loan (bridging facility) — non current portion		121,666,433		—		—

Total non current secured loan		184,166,433		71,500,000		76,000,000

Total secured loan		197,666,433		80,500,000		85,000,000

OPIC Secured Loan

On June 12, 2001, the Company entered into a loan agreement with OPIC to secure a project financing facility of $85,000,000. The loan is secured over the assets of the refinery project which have a carrying value of $228,704,267 at December 31, 2006 (2005 — $225,669,179, 2004 — $236,132,247).

The interest rate on the loan is equal to the treasury cost applicable to each promissory note outstanding plus the OPIC spread (3%). During 2006 the weighted average interest rate was 7.01% (2005 — 7.10%, 2004 — 6.65%) and the total interest expense included in long term borrowing costs was $5,512,975 (2005 — $6,038,887, 2004 — $nil).

The loan agreement was last amended on December 29, 2006. Under the amendment, the half yearly principal payment due in December 2006 and June 2007 of $4,500,000 each have been deferred until December 31, 2007 and interest previously due on December 31, 2006 and June 30, 2007 were deferred until September 30, 2007. The normal repayment of interest and principal will recommence on September 30, 2007 and December 31, 2007 respectively. Interest relating to the loan is accrued in the financial statements and has been included in accounts payable and accrued liabilities. Fees of $500,000 associated with the amendment have been included in deferred financing costs and accrued financing costs at December 31, 2006.


InterOil Corporation Notes to Revised Consolidated Financial Statements (Expressed in United States dollars)

18. Secured loan (cont’d)

Due to the amendment of the loan agreement, three installment payments amounting to $13,500,000 which become due for payment on December 31, 2007 have been reclassified into the current portion of the liability. The agreement contains certain financial covenants which include the maintenance of minimum levels of tangible net worth and limitations on the incurrence of additional indebtedness. Under the amendment, the covenants related to minimum levels of tangible net worth have been waived until June 2008.

Deferred financing costs relating to OPIC loan of $1,582,555 (2005 — $1,256,816, 2004 — $1,311,488) are being amortized over the period until December 2014.

The accrued financing costs of $1,450,000 (2005 — $921,109, 2004 — $863,329) included discounting of the liability. The total liability is $1,450,000 and will be due for payment in four quarterly installments of $362,500 commencing on December 31, 2007. As at December 31, 2006 $1,087,500 is included under non-current liabilities and the balance is included under current liabilities.

Bridging Facility

InterOil entered into a loan agreement for $130,000,000 on May 3, 2006. The loan is divided into two Tranche’s — Tranche 1, which represents $100,000,000 and Tranche 2, which represented the remaining balance of $30,000,000. As at December 31, 2006, InterOil has drawn down the full facility of $130,000,000. The agreement contains certain financial covenants which include the maintenance of minimum levels of fixed charge ratios, a maximum leverage ratio and limitations on the incurrence of additional indebtedness. The loan is secured over the assets of the downstream business and secondary security over refinery assets.

The full balance of the loan will be repayable on May 3, 2008 with interest payable quarterly in arrears. The interest rate on the loan will be 4% commencing on May 3, 2006 and ending on May 3, 2008. The discounted interest rate of 4% rate is applicable as definitive LNG/NGL Project Agreement has been executed by InterOil and the lenders subsequent to the year ended December 31, 2006, on July 30, 2007.

The loan is valued on the balance sheet based on the present value of the expected cash flows. The expected cash flows include not only interest payments but also a 3.5% commitment fee payable to the lenders at the time of each draw down. The expected cash flows have been adjusted to take into account the likelihood of different interest rate outcomes relevant to the second year of the facility. Interest expense is recognized based on the market rate of interest InterOil would be expected to pay on such a borrowing should it not be connected to an LNG/NGL Project. The effective rate used in the calculation is 9.18%.

The difference between the book value of the loan at the time of the cash being received and the actual funds drawn down is the Deferred liquefaction project liability in the current liability section of the balance sheet. This liability of $6,553,080 will be transferred to the profit and loss account as income if a definitive LNG/NGL Project Agreement is executed by InterOil and the lenders on or before March 31, 2007.

Annual administration fees of $100,000 has been included under deferred financing costs and amortized over the year until May 2007. The balance as at December 31, 2006 was $33,333.

Bank covenants under the above facilities currently restrict the payment of dividends by the Company.

19. Indirect participation interests (Restated)

Indirect participation interest (“IPI”)

December 31,

2006

2005

2004

$ (Restated)

Indirect participation interest (“IPI”)

96,861,259

13,749,852

For detailed reconciliation of the restated and superseded balance relating to the IPI liability, refer note 2 above.

The IPI balance relates to $125,000,000 received by InterOil subject to the terms of the agreement dated February 25, 2005 between the corporation and certain investors. In exchange InterOil has provided the investors with a 25% interest in an eight well drilling program to be conducted in InterOil’s petroleum prospecting licenses 236, 237 and 238. Prior to December 31, 2004, the Company received deposits of $13,749,852 and the remaining $111,250,148 was received in 2005.


InterOil Corporation Notes to Revised Consolidated Financial Statements (Expressed in United States dollars)

19. Indirect participation interests (Restated) (cont’d)

Under the agreement, all or part of this indirect participation interest may be converted to a maximum of 3,333,334 common shares in the company between June 15, 2006 and the later of December 15, 2006, or until 90 days after the completion of the eighth well at a price of $37.50 per share. Should the conversion to shares not be exercised, the indirect participation interest in the eight well drilling program will be maintained and distributions from success in these wells will be paid in accordance with the agreements. Any partial conversion of an indirect participation interest into common shares will result in a corresponding decrease in the investors’ interest in the eight well drilling program.

Under the IPI agreement, InterOil is responsible for drilling the eight wells, four of which will be in PPL 238, one in PPL 236, and one in PPL 237. The investors will be able to approve the location of the final two wells to be drilled. In the instance that InterOil proposes completion of an exploration or development well, the investors will be asked to contribute to the completion work in proportion to their IPI percentage and InterOil will bear the remaining cost. Should an investor choose not to participate in the completion works, the investor will forfeit their right to the well in question as well as their right to convert into common shares.

The non-financial liability has been valued at $105,000,000, being the estimated expenditures to complete the eight well drilling program, and the residual value of $20,000,000 has been allocated to conversion option presented under Shareholder’s equity. InterOil paid financing fees and transaction costs of $8,138,741 related to the indirect participation interest on behalf of the indirect participation interest investors in 2005. These fees have been allocated against the non-financial liability, reducing the liability to $96,861,259.

InterOil will maintain the liability at its initial value till conveyance is triggered on the lapse of conversion option available to the investors and they elect to participate in the PDL for a successful well. InterOil will account for the exploration costs relating to the eight well program under successful efforts accounting policy adopted by the Company. All G&G costs relating to the exploration program will be expensed as incurred and all drilling costs will be capitalized and assessed for recovery at each period. When conveyance is triggered on election by the investors to participate in a PDL or when the investor forfeits the conversion option, conveyance accounting will be applied. This would entail determination of proceeds for the interests conveyed and the cost of that interest as represented in the ‘Oil and gas properties’ in the balance sheet. The difference between proceeds on conveyance and capitalized costs to the interests conveyed will be recognized as gain or loss in the Statement of operations following the guidance in paragraphs 47(h) and 47(j) of SFAS 19.

If conversion option is exercised by an investor, the non-financial liability relating to that investor would be transferred to share capital for the number of shares issued. There were no exercise of conversion option to InterOil shares during the financial years ended December 31, 2006 and 2005.

Indirect participation interest – PNGDV (Restated)


	December 31,		December 31,		December 31,
	2006		2005		2004
	$ (Restated)		$ (Restated)		$

Current portion		730,534		—		—
Non current portion		1,190,633		9,685,830		10,608,830

Total indirect participation interest — PNGDV		1,921,167		9,685,830		10,608,830

For detailed reconciliation of the restated and superseded balance relating to the Indirect Participation Interest – PNGDV liability, refer note 2 above.

As at December 31, 2006, the balance of the PNG Drilling Ventures Limited (“PNGDV”) indirect participation interest in the Company’s phase one exploration program within the area governed by petroleum prospecting licenses 236, 237 and 238 is $1,921,167 (2005 — $9,685,830, 2004 - $10,608,830). This is the result of an amendment to the original agreement whereby PNG Drilling Ventures Limited converted their remaining balance of $9,685,830 into 575,575 InterOil common shares and also retained a 6.75% interest in the next four wells (the first of the four wells is Elk-1). PNGDV also has the right to participate in the 16 wells that follow the first four mentioned above up to an interest of 5.75% at a cost of $112,500 per 1% per well (with higher amounts to be paid if the depth exceed 3,500 meters and the cost exceeds $8,500,000).

The accounting for the amendment to the agreement resulted in the fair value of the shares issue of $7,948,691 being recognized as share capital. The Company has also recognized an initial liability relating to its obligation to drill four wells on behalf of the investors of $3,184,040. Initial liability taken up on amendment of the agreement is $3,588,560. The difference between the opening balance and the amount allocated to share capital and the revised amount allocated to the liability of $1,851,421 has been expensed as a cost of amending the original transaction.


InterOil Corporation Notes to Revised Consolidated Financial Statements (Expressed in United States dollars)

19. Indirect participation interests (Restated) (cont’d)

During the year ended December 31, 2006, $1,667,396 of geological and geophysical costs and drilling costs have been allocated against the liability of $3,588,560 bringing the remaining balance to $1,921,167. PNGDV liability has been accounted using conveyance accounting as there are no conversion options attached to the liability, unlike IPI non-financial liability noted above.

Other

In addition to the above, PNG Energy Investors (“PNGEI”), an indirect participation interest investor, that converted all of its interest to common shares in fiscal year 2004, has the right to participate up to a 4.25% interest in wells 9 to 24. In order to participate, PNGEI would be required to contribute a proportionate amount of drilling costs related to these wells.

20. Non controlling interest

On September 11, 1998 Enron Papua New Guinea Ltd (“Enron”), SPI’s former joint venture partner, exercised its option (pursuant to a January 1997 joint venture agreement with SPI) to terminate the joint venture agreement. Consequently, SPI purchased Enron’s voting, non-participating shares in E.P. InterOil Limited (“EPI”), a wholly owned subsidiary of SPI, for a nominal amount. Enron no longer actively participates in the refinery operations but continues to be a non-voting participating shareholder in EPI. SPI now holds all voting non-participating shares issued from EPI and has sole responsibility for managing the refinery. Enron does not hold any transfer or conversion rights into shares of InterOil Corporation.

At December 31, 2006, a subsidiary, SP InterOil LDC, holds 98.92% (2005 — 98.83%) of the non-voting participating shares issued from EPI.

21. Share capital

The authorized share capital of the Company consists of an unlimited number of common shares with no par value. Each common share entitles the holder to one vote.

Common shares — Changes to issued share capital were as follows:


	Number of shares		$

January 1, 2004		24,815,961		157,449,200

Shares issued for debt		3,184,828		56,698,121
Shares issued on exercise of options		310,095		2,666,333

December 31, 2004		28,310,884		216,813,654

Shares issued for debt		52,000		923,000
Shares issued on exercise of warrants		19,168		540,346
Shares issued on exercise of options		781,268		5,657,500

December 31, 2005		29,163,320		223,934,500

Shares issued on exercise of options		132,285		2,006,175
Shares issued on amendment of indirect participation interest — PNGDV		575,575		7,948,691

December 31, 2006		29,871,180		233,889,366


InterOil Corporation Notes to Revised Consolidated Financial Statements (Expressed in United States dollars)

22. Stock compensation

At December 31, 2006, there were 2,570,500 (2005 – 911,068) common shares reserved for issuance under the Company stock option plan.

Options are issued at no less than market price to directors, staff and contractors. Options are exercisable on a 1:1 basis. Options vest at various dates in accordance with the applicable option agreement, have an exercise period of three to five years assuming continuous employment by the InterOil Company and may be exercised at any time after vesting within the exercise period. Upon resignation or retirement, vested options must be exercised within 30 days for employees and 90 days for directors.


	December 31, 2006						December 31, 2005						December 31, 2004
	Number of			Weighted average			Number of			Weighted average			Number of			Weighted average
Stock options outstanding	options			exercise price $			options			exercise price $			options			exercise price $

Outstanding at beginning of year		746,800			22.23			1,162,322			9.91			1,363,265			7.55
Granted		725,500			15.87			516,450			25.82			224,460			26.30
Exercised		(132,285	)		(11.14	)		(781,322	)		(6.50	)		(310,095	)		(6.52	)
Forfeited		(285,433	)		(18.01	)		(74,000	)		(13.11	)		(100,308	)		(25.28	)
Expired		(41,082	)		(15.36	)		(76,650	)		(26.01	)		(15,000	)		(8.00	)

Outstanding at end of year		1,013,500			20.59			746,800			22.23			1,162,322			9.91


	Options issued and outstanding						Options exercisable
Range of exercise			Weighted average		Weighted average				Weighted average
prices $	Number of options		exercise price $		remaining term (years)		Number of options		exercise price $

5.01 to 8.00		10,000		5.27		0.39		10,000		5.27
13.01 to 24.00		714,000		18.03		3.63		150,000		18.84
24.00 to 31.00		289,500		27.44		1.93		77,500		30.27

		1,013,500		20.59		2.97		237,500		22.00

The fair value of the 725,500 (2005 — 516,450, 2004 — 224,460) options granted subsequent to January 1, 2006 has been estimated at the date of grant in the amount of $6,447,315 (2005 - $4,834,139, 2004 — $1,122,938) using a Black-Scholes pricing model. An amount of $1,976,072 (2005 - $1,668,896, 2004 — $1,202,921) has been recognized as compensation expense for the year ended December 31, 2006. Of the current year compensation expense of $1,976,072 (2005 — $1,668,896, 2004 - $1,202,921), $1,443,840 (2005 – $1,091,810, 2004 – $656,338) was adjusted against contributed surplus under equity and $532,230 (2005 – $577,086, 2004 – $546,583) was applied to share capital.

The assumptions contained in the Black Scholes pricing model are as follows:


								Weighted average
		Risk free interest rate						expected life for
Year	Period	(%)		Dividend yield		Volatility (%)		options

2006	October 1 to December 31		4.6		—		65		5.0
2006	July 1 to September 30		5.1		—		68		4.2
2006	January 1 to June 30		4.4		—		60		4.8
2005	July 1 to December 31		2.5		—		55		3.6
2005	January 1 to June 30		2.5		—		45		3.2
2004	January 1 to December 31		2.5		—		45		3.8


InterOil Corporation Notes to Revised Consolidated Financial Statements (Expressed in United States dollars)

23. Debentures and warrants

In 2004, InterOil issued a total of $45,000,000 in senior convertible debentures. The debentures were to mature on August 28, 2009 and bore interest at a rate of 8.875% per annum, payable quarterly. The debentures were converted into 2,232,143 common shares of the Company at a fixed conversion price of $20.16 per share on December 31, 2004 at the investors’ option.

In 2004, in connection with the issuance of senior convertible debentures, InterOil issued five-year warrants to purchase 359,415 common shares at an exercise price equal to $21.91. A total of 340,247 (2005 – 340,247, 2004 – 359,415) were outstanding at December 31, 2006. The warrants are exercisable between August 27, 2004 and August 27, 2009. The warrants are recorded at the fair value calculated at inception as a separate component of equity. The fair value was calculated using a Black-Scholes pricing model with the following assumptions: risk-free interest rate of 2.5%, dividend yield of nil, volatility factor of the expected market price of the Company’s common stock of 45% and a weighted average expected life of the warrants of five years.

24. Loss per share

Warrants, conversion options and stock options totaling 4,687,081 common shares at prices ranging from $5.27 to $37.50 were outstanding as at December 31, 2006 but were not included in the computation of the diluted loss per share because they caused the loss per share to be anti-dilutive.

25. Commitments and contingencies

Payments due by period contractual obligations are as follows:


			Less than 1										More than 5
	Total		year		1-2 years		2-3 years		3-4 years		4-5 years		years

	’000		’000		’000		’000		’000		’000		’000

Secured loan obligations		197,666		13,500		130,666		9,000		9,000		9,000		26,500
Accrued financing costs		1,450		363		1,087		—		—		—		—
Acquisition of subsidiary — IPL PNG Ltd		1,771		1,771		—		—		—		—		—
Indirect participation interest — PNGDV (note 19)		1,921		731		1,190		—		—		—		—
Indirect participation interest (note 19) (a)		96,861		—		96,861		—		—		—		—
Petroleum prospecting and retention licenses (b)		5,237		1,877		3,360		—		—		—		—

		304,906		18,242		233,164		9,000		9,000		9,000		26,500


(a)		The liability presented in relation to indirect participation interest is not a cash commitment and will be resolved once the IPI investors have elected to convert their interests into a joint venture interest or shares in InterOil Corporation. InterOil’s commitment is to complete the eight well drilling program. As at December 31, 2006, management estimate that a further $48,126,000 will be required to be spent to fulful this commitment.

(b)		The amount pertaining to the petroleum prospecting and retention licenses represents the amount InterOil has committed to spend to its joint venture partners. In addition to this amount, InterOil must drill an exploration well on PPL 237 in the two year period commencing March 2007. As the cost of drilling this well cannot be estimated, it is not included within the above table.

The Company is involved in various claims and litigation arising in the normal course of business. While the outcome of these matters is uncertain and there can be no assurance that such matters will be resolved in the Company’s favour, the Company does not currently believe that the outcome of adverse decisions in any pending or threatened proceedings related to these and other matters or any amount which it may be required to pay by reason thereof would have a material adverse impact on its financial position, results of operations or liquidity.

The Company currently has an outstanding $10.6 million cost of control insurance claim for the Elk well which is being assessed by the loss adjusters. The amount and timing of any payment related to this claim is currently unknown.

The Company has income tax filings that are subject to audit and potential reassessment. The findings may impact the tax liability of the Company. The final results are not reasonably determinable at this time and management believes that it has adequately provided for current and future income taxes.

26. Subsequent events

The definitive LNG/NGL Project Agreement which was required to be executed by InterOil and the bridging facility lenders for the discounted interest rate of 4% rate being applicable till the end of the facility was executed subsequent to the year ended December 31, 2006, on July 30, 2007.


InterOil Corporation Notes to Revised Consolidated Financial Statements (Expressed in United States dollars)

27. Reconciliation to accounting principles generally accepted in the United States (Restated)

The audited consolidated financial statements of the Company for the twelve month periods ended December 31, 2006, 2005 and 2004 have been prepared in accordance with generally accepted accounting principles in Canada (“Canadian GAAP”) which, in most respects, conforms to generally accepted accounting principles in the United States (“U.S. GAAP”). The reconciliations and other information presented in this note are solely in relation to the consolidated financial statements. The significant differences between Canadian GAAP and U.S. GAAP as they relate to the Company are presented throughout this note. Additionally, where there is no significant conflict with Canadian GAAP requirements some of the additional U.S. GAAP disclosure requirements have been incorporated throughout the Canadian GAAP financial statements.

Restatement of Consolidated financial statements for the year ended December 31, 2006 and 2005

Restatement to Consolidated Balance Sheets


	December 31, 2006									December 31, 2005									Canadian	U.S.
	Original						Restated			Original						Restated			GAAP	GAAP
	Balance			Adjustments			Balance			Balance			Adjustments			Balance			Reference	Reference
	$			$			$			$			$						$ (Note 2)	(below)

Non-current assets
Oil and gas properties (note 12)		37,449,734			17,074,613			54,524,347			16,399,492			3,339,435			19,738,927		(i), (ii)

Current and Non-current liabilities
Indirect participation interest (note 19)		74,763,970			42,097,289			116,861,259			86,454,953			30,406,306			116,861,259		(i), (iii), (iv)	(i), (ii)
Indirect participation interest — PNGDV (note 19)		1,743,533			177,634			1,921,167			9,685,830			—			9,685,830		(vi)

Shareholders’ Equity

Accumulated deficit (Refer ‘Restatement to Consolidated Statement of Operations’ below )		(187,776,004	)		(9,724,577	)		(197,500,581	)		(125,375,528	)		(27,066,871	)		(152,442,399	)


InterOil Corporation Notes to Revised Consolidated Financial Statements (Expressed in United States dollars)

27. Reconciliation to accounting principles generally accepted in the United States (Restated) (cont’d)

Restatement to Consolidated Statement of Operations


	Year ended December 31, 2006							Year ended December 31, 2005								Canadian	U.S.
	Original					Restated		Original						Restated		GAAP	GAAP
	Balance		Adjustments			Balance		Balance			Adjustments			Balance		Reference	Reference
	$		$			$		$			$			$		(Note 2)	(below)

Expenses
Exploration costs, excluding exploration impairment (note 12)		1,657,671		4,519,195			6,176,866		—			11,009,434			11,009,434	(ii)

Exploration impairment (note 12)		416,923		1,230,262			1,647,185		2,144,429			17,425,644			19,570,073	(ii)

Accretion expense (note 19)		3,741,254		(3,741,254	)		—		5,647,491			(5,647,491	)		—	(iv), (vi)

Loss on amendment of indirect participation interest — PNGDV (note 19)		1,446,901		404,520			1,851,421		—			—			—	(vi)

Loss/(gain) on revaluation of conversion options		19,755,017		(19,755,017	)		—		(4,279,284	)		4,279,284			—		(ii)

Total restated expenses		27,017,766		(17,342,294	)		9,675,472		3,512,636			27,066,871			30,579,507



Net loss		62,400,476		(17,342,294	)		45,058,182		34,971,620			27,066,871			62,038,491

In addition to the changes made under Canadian GAAP (refer note 2), the following adjustments were made to the U.S. GAAP treatment of the IPI agreement to reflect the U.S. GAAP differences and reconcile the differences between both GAAP’s.

(i)

Under U.S. GAAP, the conversion option feature in the IPI Agreement was valued and bifurcated on day one as a result of adopting the allocation method for the hybrid instrument required by DIG issue B6 “Allocating the Basis of a Hybrid Instrument to the Host Contract and the Embedded Derivative”. Based on the revised model agreed with the SEC, the conversion option will no longer be bifurcated as Company has opted to utilize the scope exception under SFAS 133 Para 10(f) for ‘derivatives that serve as impediments to sales accounting’. This will result in non-financial liability maintained at full value of $125,000,000 less the transaction costs. This adjustment has the effect of increasing the IPI liability from the superseded balance as at December 31, 2006 by $27,249,587 (2005 — $27,249,587). The IPI liability balance will also be impacted by the revaluation of the conversion option noted below.

(ii)

The conversion option feature in superseded financial statements had also resulted in GAAP differences between Canadian and U.S. GAAP as under U.S. GAAP the fair value of the option was treated as a separate liability (rather than equity under Canadian GAAP which was not revalued) which had to be revalued to fair value at each period end. As a result of adopting the revised model, the conversion option will no longer be bifurcated and revalued under US GAAP. The revised model does not bifurcate the conversion option feature under U.S. GAAP resulting in reversal of all revaluations performed at each period end. This adjustment will have the impact of reducing the US GAAP loss for year ended December 31, 2006 by $19,755,017 (2005 — increase the loss by $4,279,284). This adjustment will also have the corresponding effect on ‘IPI liability’ balance carried forward in the balance sheet. The IPI liability balance as at December 31, 2006 will decrease by $15,475,733, and as at December 2005 will increase by $4,279,284 from the superseded balances due to this adjustment.

(iii)

Under U.S. GAAP, the impact of all the adjustments as explained under Note 2 and noted above on the consolidated statement of income for the years ended December 31, 2006 and 2005 has been an decrease in the loss by $17,342,294 ($0.59 per share) and increase in the loss by $27,066,871 ($0.94 per share) respectively. The difference between this U.S. GAAP and Canadian GAAP impact to statement of income is the reversal of revaluations as explained above which has reduced the US GAAP loss for year ended December 31, 2006 by $19,755,017 (2005 - increase the loss by $4,279,284).


InterOil Corporation Notes to Revised Consolidated Financial Statements (Expressed in United States dollars)

27. Reconciliation to accounting principles generally accepted in the United States (Restated) (cont’d)

Consolidated statements of operations (Restated)

The following table presents the consolidated statements of operations under U.S. GAAP compared to Canadian GAAP:


	Year ended
	December 31, 2006						December 31, 2005						December 31, 2004
	$ (Restated)						$ (Restated)						$
	Canadian GAAP			U.S. GAAP			Canadian GAAP			U.S. GAAP			Canadian GAAP			U.S. GAAP

Revenue
Sales and operating revenues (1)		511,087,934			511,189,438			481,180,645			481,180,645			70,644,486			121,974,268
Interest income		3,223,995			—			1,830,808			—			382,461			—
Other income		3,747,603			—			528,270			—			196,337			—

		518,059,532			511,189,438			483,539,723			481,180,645			71,223,284			121,974,268


Expenses
Cost of sales and operating expenses (excluding depreciation shown below) (1)		499,494,540			499,584,532			467,246,990			467,400,576			65,344,516			129,871,126
Administrative and general expenses (1), (2)		20,728,618			20,762,574			14,672,793			14,687,717			7,831,550			8,081,740
Depreciation and amortization (1)		12,352,672			11,591,513			11,036,550			10,836,696			639,075			1,462,953
Exploration costs, excluding exploration impairment		6,176,866			6,176,866			11,009,434			11,009,434			2,903,313			2,903,313
Exploration impairment		1,647,185			1,647,185			19,570,073			19,570,073			35,566,761			35,566,761
Legal and professional fees (1)		3,937,517			3,937,517			3,606,415			3,606,415			3,573,727			3,655,631
Short term borrowing costs		8,478,540			8,478,540			8,855,857			8,855,857			4,705,190			4,705,190
Long term borrowing costs (1)		11,856,872			11,856,872			6,351,337			6,351,337			1,401,256			1,897,029
Debt conversion expense (5)		—			—			—			—			—			6,976,800
Loss on amendment of indirect participation interest -
PNGDV		1,851,421			1,851,421			—			—			—			—
Foreign exchange loss/(gain) (2)		(4,744,810	)		(4,744,810	)		796,590			796,590			392,805			392,805
Non-controlling interest (7)		(263,959	)		(265,865	)		(368,312	)		(368,475	)		(70,091	)		(265,624	)
Interest income		—			(3,223,995	)		—			(1,830,808	)		—			(382,461	)
Other income		—			(3,747,603	)		—			(528,270	)		—			(196,337	)

		561,515,462			553,904,747			542,777,727			540,387,142			122,288,102			194,668,926

Loss before income taxes		(43,455,930	)		(42,715,309	)		(59,238,004	)		(59,206,497	)		(51,064,818	)		(72,694,658	)

Income tax expense (3)		(2,342,873	)		(2,342,873	)		(2,831,994	)		(2,831,994	)		(1,875,063	)		(1,875,063	)

Loss before cumulative effect of accounting change		(45,798,803	)		(45,058,182	)		(62,069,998	)		(62,038,491	)		(52,939,881	)		(74,569,721	)
Cumulative effect of accounting change (4)		—			—			—			—			—			(737,650	)

Net loss		(45,798,803	)		(45,058,182	)		(62,069,998	)		(62,038,491	)		(52,939,881	)		(75,307,371	)


InterOil Corporation Notes to Revised Consolidated Financial Statements (Expressed in United States dollars)

27. Reconciliation to accounting principles generally accepted in the United States (Restated) (cont’d)

Reconciliation of Canadian GAAP net income/(loss) to U.S. GAAP net income/(loss) — (Restated)


	Year ended
	December 31,			December 31,			December 31,
	2006			2005			2004
	$ (Restated)			$ (Restated)			$

Net loss as shown in the Canadian GAAP financial statements		(45,798,803	)		(62,069,998	)		(52,939,881	)
Description of items having the effect of increasing reported income
Decrease in depreciation and amortization due to difference in date of commencement of operations of refinery (1)		761,159			199,854			—
Decrease in non-controlling interest expense (7)		1,907			163			195,533

Decrease in administrative and general expenses from ineffective portion of hedges (2)		—			22,456			—
Increase in sales as a result of items being ineligible for capitalization due to difference in date of commencement of operations of refinery(1)		—			—			51,329,782
Increase in sales from ineffective portion of hedges (2)		101,504			—			—
Description of items having the effect of decreasing reported income
Increase in depreciation and amortization due to difference in date of commencement of operations of refinery (1)		—			—			(823,878	)

Increase in cost of sales and operating expenses as a result of items being ineligible for capitalization due to difference in date of commencement of operations of refinery (1)		—			(153,586	)		(64,526,610	)
Increase in cost of sales from ineffective portion of hedges (2)		(89,992	)		—			—

Increase in administrative and general expenses from ineffective portion of hedges (2)		(33,956	)		—			—

Increase in administrative and general expenses as a result of items being ineligible for capitalization due to difference in date of commencement of operations of refinery (1)		—			(37,380	)		(250,190	)

Increase in legal and professional fees as a result of items being ineligible for capitalization due to difference in date of commencement of operations of refinery (1)		—			—			(81,904	)

Increase in long term borrowing costs as a result of items being ineligible for capitalization due to difference in date of commencement of operations of refinery (1)		—			—			(495,773	)
Debt conversion expense (5)		—			—			(6,976,800	)
Cumulative effect of accounting change relating to stock compensation (4)		—			—			(737,650	)

Net loss according to US GAAP		(45,058,182	)		(62,038,491	)		(75,307,371	)

Statements of comprehensive income/(loss), net of tax (Restated)


				Year ended
	December 31,			December 31,			December 31,
	2006			2005			2004
	$ (Restated)			$ (Restated)			$

Net loss in accordance with U.S. GAAP, net of tax		(45,058,182	)		(62,038,491	)		(75,307,371	)
Foreign currency translation reserve, net of tax		1,015,426			14,243			463,200
Deferred hedge gain, net of tax		(993,153	)		457,184			537,358

Total other comprehensive income, net of tax		22,273			471,427			1,000,558

Comprehensive loss, net of tax		(45,035,909	)		(61,567,064	)		(74,306,813	)

Statements of cash flows

There are no material differences in the statement of cash flows between Canadian and U.S. GAAP except for the classification of ‘Expenditure on oil and gas properties’ which is classified under investing activities under Canadian GAAP. Under U.S. GAAP this item is classified as an operating activity.


InterOil Corporation Notes to Revised Consolidated Financial Statements (Expressed in United States dollars)

27. Reconciliation to accounting principles generally accepted in the United States (Restated) (cont’d)

Statements of accumulated other comprehensive income, net of tax (AOCI)


						Total
						accumulated
	Foreign currency					other
	translation		Deferred hedge			comprehensive
	reserve		gain			income

AOCI balance as of December 31, 2003		—		—			—
Current period change		463,200		537,358			1,000,558

AOCI balance as of December 31, 2004		463,200		537,358			1,000,558
Current period change		14,243		457,184			471,427

AOCI balance as of December 31, 2005		477,443		994,542			1,471,985
Current period change		1,015,426		(993,153	)		22,273

AOCI balance as of December 31, 2006		1,492,869		1,389			1,494,258

Per share amounts (Restated)

Basic per share amounts are computed by dividing net income available to shareholders by the weighted average number of shares outstanding for the reporting period. Diluted per share amounts reflects the potential dilution that could occur if options or contracts to issue shares were exercised or converted into shares.

For the calculation of diluted per share amounts, the basic weighted average number of shares is increased by the dilutive effect of stock options determined using the treasury method. No potential shares in options on issue were dilutive for the years ended December 31, 2006, 2005 and December 31, 2004.


Weighted average number of shares on which earnings per share	Year ended December 31,
calculations are based in accordance with U.S. GAAP	2006			2005			2004

Basic		29,602,360			28,832,263			25,373,575
Effect of dilutive options		—			—			—

Diluted		29,602,360			28,832,263			25,373,575

Net income/(loss) per share in accordance with U.S. GAAP	(Restated)			(Restated)
Basic		(1.52	)		(2.15	)		(2.97	)

Diluted		(1.52	)		(2.15	)		(2.97	)

Consolidated balance sheets (Restated)


	December 31, 2006				December 31, 2005				December 31, 2004
	(Restated)				(Restated)
	Canadian GAAP		U.S. GAAP		Canadian GAAP		U.S. GAAP		Canadian GAAP		U.S. GAAP

Current assets		201,714,996		201,714,996		173,232,689		173,232,689		132,258,350		132,258,350
Oil and gas properties		54,524,347		54,524,347		19,738,927		19,738,927		6,605,360		6,605,360
Capital assets (1), (2)		242,642,077		231,175,281		237,399,148		225,171,193		244,363,355		232,496,306
Deferred financing costs		1,716,757		1,716,757		1,256,816		1,256,816		1,311,488		1,311,488
Restricted Cash		3,217,284		3,217,284		210,053		210,053		—		—
Future income tax benefit (3)		1,424,014		1,424,014		1,058,898		1,058,898		1,303,631		1,303,631

Total assets		505,239,475		493,772,679		432,896,531		420,668,576		385,842,184		373,975,135

Current liabilities (2), (6)		133,753,876		133,752,491		132,099,945		131,082,948		142,197,050		141,659,692
Accrued financing costs		1,087,500		1,087,500		921,109		921,109		863,329		863,329
Long term debt (6)		282,218,325		302,218,325		178,047,089		198,047,089		86,608,830		86,608,830
Non-controlling interest (7)		5,759,206		5,416,831		6,023,149		5,682,695		6,404,262		6,063,971
Shareholders’ equity (1) (2) (4) (5) (6)		82,420,568		51,297,532		115,805,239		84,934,735		149,768,713		138,779,313

Total liabilities and shareholders’ equity		505,239,475		493,772,679		432,896,531		420,668,576		385,842,184		373,975,135

*(1)*		*Operations*

		The Company determined that refinery operations commenced under U.S. GAAP at December 1, 2004, which is the date management assessed that construction of the refinery was substantially complete and ready for its intended use. The Company ceased capitalization of certain costs to the refinery project at this date and recognized one month’s results from sales, related costs of sales and operating expenses and administrative and general expenses in the statement of operations for the year ended December 31, 2004.


InterOil Corporation Notes to Revised Consolidated Financial Statements (Expressed in United States dollars)

27. Reconciliation to accounting principles generally accepted in the United States (Restated) (cont’d)

		As disclosed in note 3(q) in the consolidated financial statements, operations commenced on January 1, 2005 under Canadian GAAP. Therefore, the Company continued to capitalize December 2004’s results to the refinery project. Due to the difference in the cost basis of the refinery, the depreciation expense recorded under U.S. GAAP differs from that recorded under Canadian GAAP during 2005.

		In the prior year, in addition to recognizing December 2004’s results in the statement of operations, one month of depreciation expense was also recorded under U.S. GAAP for the refinery during 2004. The useful life for the refinery under U.S. GAAP is the same as that disclosed under Canadian GAAP in note 3(q) in the consolidated financial statements.

*(2)*		*Derivative instruments and hedging*

		The Company accounts for derivatives and hedging activities in accordance with FASB Statement No. 133, “Accounting for Derivative Instruments and Certain Hedging Activities”, as amended (“SFAS No. 133”), which requires that all derivative instruments be recorded on the balance sheet at their respective fair values.

		The Canadian Institute of Chartered Accountants issued Accounting Guideline 13 “Hedging Relationships” (“AcG-13”), which became effective January 1, 2004. This guideline was issued to align certain accounting principles under Canadian GAAP with SFAS No. 133, including hedge documentation and assessing hedge effectiveness. The Company adopted the hedge accounting provisions in AcG-13 and SFAS No. 133 in respect of the commodity forward contracts it transacted beginning in July 2004. Under Canadian GAAP, the Company includes hedges which are unsettled at period end in current liabilities based on a marked to market calculation. Under SFAS No. 133 the marked to market amount for the unsettled hedges is included in other comprehensive income to the extent that they are effective. The ineffective portion is expensed. Details of hedge accounting is disclosed in notes 3(o) and 8 in the consolidated financial statements of the Company for the year ended December 31, 2006.

*(3)*		*Income tax effect of adjustments*

		The income tax effect of U.S. GAAP adjustments was a reduction to the future tax asset of $259,957 (2005 – reduction of $11,059) for the year ended December 31, 2006 due to an decrease in the loss carry-forwards. A corresponding decrease in the valuation allowance was recorded. No income tax expense was recorded in the years ended December 31, 2006, 2005 and 2004 due to the tax holiday period in Papua New Guinea through five years after the refinery commences operations.

*(4)*		*Stock based compensation*

		At January 1, 2004, the Company adopted the provisions of CICA 3870 in respect of the employee stock-based awards, which resulted in recognition of compensation expense for such awards under Canadian GAAP on a basis consistent with the fair value provisions of SFAS No. 123. As disclosed in note 3(t) to the consolidated financial statements, the Company retroactively applied the fair value method to all employee stock options granted on or after January 1, 2002, without restatement to prior years.

		This is not consistent with the modified prospective transition method allowed for a voluntary change to the fair value method under FASB Statement No. 148 “Accounting for Stock-Based Compensation — Transition and Disclosure, an amendment of FASB Statement No. 123” (“SFAS No. 148”). The modified prospective method requires retroactive consideration of all employee stock awards granted, modified or settled on or after January 1, 1995. The Company did not adjusted for this GAAP difference as there were no options granted, modified or settled between January 1, 1995 and January 1, 2002 that would have materially impacted net income for the years ended December 31, 2005, 2004 and 2003.

		The cumulative effect of this change in accounting principle of $737,650 was recorded to opening accumulated deficit under Canadian GAAP. This is required to be disclosed as a cumulative change in accounting principle in the statement of operations under U.S. GAAP.


InterOil Corporation Notes to Revised Consolidated Financial Statements (Expressed in United States dollars)

27. Reconciliation to accounting principles generally accepted in the United States (Restated) (cont’d)

(5)		*Debt conversion expense*

		As disclosed in note 23 in the consolidated financial statements, 100% of the convertible debentures were converted before December 31, 2004. The Company issued an additional 180,000 shares to induce conversion before the end of the year. Under Canadian GAAP, the fair value of these shares was recorded as an increase in share capital of $6,976,800 with offsetting adjustments to retained earnings of $6,899,211 and a conversion expense of $77,589.

		FASB Statement No. 84, “Induced Conversions of Convertible Debt” requires an expense to be recorded when convertible debt is converted under an inducement. The Company recognized the entire fair value of the inducement shares of $6,976,800 as a conversion expense under U.S. GAAP.

*(6)*		*Indirect participation interest*

		As disclosed in note 2 in the consolidated financial statements, the Company entered into an indirect participation interest agreement in exchange for proceeds of $125,000,000. Under Canadian GAAP, this amount was apportioned between non financial liabilities and equity. Under U.S. GAAP, Company has not bifurcated the amount as the Company has opted to utilize the scope exception under SFAS 133 Para 10(f) for ‘derivatives that serve as impediments to sales accounting’.

(7)		*Non controlling interest*

		The non-controlling interest movements are the result of the U.S. GAAP adjustments relating to the midstream operations described in points 1 to 4 above.

Acquisition of InterOil Products Limited (“IPL”)

The following summary unaudited pro forma condensed consolidated financial information for the twelve month periods ended December 31, 2004 and 2003 shows the estimated pro forma impact on the Company’s consolidated financial statements of the acquisition of IPL as of April 28, 2004. Refer to note 15 of the consolidated financial statements. This pro forma information is based on management’s current estimates of, and good faith assumptions regarding, the adjustments arising from the transactions described above. The pro forma adjustments are based on currently available information and actual adjustments could differ materially from current estimates.

The pro forma information does not purport to represent what the financial position and results of operations would actually have been had the acquisition of IPL been consummated on the dates indicated or to project the financial position of any future date of operations of any future period.

The following pro forma statements of earnings for the years ended December 31, 2004 and 2003 give effect to the acquisition of IPL as if it had occurred on January 1, 2003.


	InterOil			IPL (1)		Pro forma
Twelve months ended December 31, 2004	(audited)			(unaudited)		(unaudited)

Sales and operating revenue — Canadian GAAP		70,644,486			27,317,000		97,961,486
Sales and operating revenue — US GAAP		121,974,268			27,317,000		149,291,268
Net profit/(loss) — Canadian GAAP		(52,939,881	)		2,350,000		(50,589,881	)
Net profit/(loss) — U.S. GAAP		(75,307,371	)		2,350,000		(72,957,371	)


Basic loss per share (cents per share)
Canadian GAAP (2)		(208	)				(199	)
U.S. GAAP (3)		(297	)				(287	)
Diluted loss per share (cents per share)
Canadian GAAP (2)		(208	)				(199	)
U.S. GAAP (3)		(297	)				(287	)


InterOil Corporation Notes to Revised Consolidated Financial Statements (Expressed in United States dollars)

27. Reconciliation to accounting principles generally accepted in the United States (Restated) (cont’d)


	InterOil			IPL (1)		Pro forma
Twelve months ended December 31, 2003	(audited)			(unaudited)		(unaudited)

Sales and operating revenue — Canadian and U.S. GAAP		—			69,897,000		69,897,000
Net profit/(loss) — Canadian GAAP		(3,517,569	)		6,474,000		2,956,431
Net profit — U.S. GAAP		4,435,965			6,474,000		10,909,965


Basic earnings/(loss) per share (cents per share)
Canadian GAAP (2)		(15	)				14
U.S. GAAP (3)		20					49
Diluted earnings/(loss) per share (cents per share)
Canadian GAAP (2)		(15	)				13
U.S. GAAP (3)		18					45

(1)

Financial data for the year ended December 31, 2004 represents results for the period from January 1, 2004 to April 28, 2004, the effective date the Company gained control of IPL, and is derived from the unaudited management accounts of IPL. Financial data for the year ended December 31, 2003 represents the actual results for the year ended December 31, 2003.

(2)

The weighted average number of shares used in the earnings per share information is consistent with that used under Canadian GAAP for the respective periods.

(3)

The weighted average number of shares used in the earnings per share information is consistent with that used under U.S. GAAP for the respective periods.

Recent Accounting Pronouncements

Fair value measurements

In September 2006, the FASB issued FAS 157 which defines fair value, establishes a framework for measuring fair value in U.S. GAAP, and expands disclosures about fair value measurements. The standard is effective for fiscal years beginning after November 15, 2007 and all interim periods within those fiscal years. The Company does not expect that the application of FAS 157 will have a material impact on the financial statements.

Accounting for uncertainty in income taxes

In June 2006, the FASB issued FIN 48 which clarifies the accounting for uncertainty in income taxes recognized in an enterprise’s financial statements in accordance with FASB Statement No. 109, Accounting for Income Taxes. This Interpretation prescribes a recognition threshold and measurement attribute for the financial statement recognition and measurement of a tax position taken or expected to be taken in a tax return. This Interpretation also provides guidance on derecognition, classification, interest and penalties, accounting in interim periods, disclosure, and transition. The standard is effective for fiscal years beginning after December 15, 2006. The Company does not expect that the application of FIN 48 will have a material impact on the financial statements.

Accounting for certain hybrid financial instruments

In March 2006, the FASB issued FAS 155 which amends FASB Statements No. 133, Accounting for Derivative Instruments and Hedging Activities, and No. 140, Accounting for Transfers and Servicing of Financial Assets and Extinguishments of Liabilities. The standard is effective for all financial instruments acquired, issued, or subject to a remeasurement event occurring after the beginning of an entity’s first fiscal year that begins after September 15, 2006. The Company does not expect that the application of FAS 155 will have a material impact on the financial statements.


Management’s Report			1
Auditor’s Report to the Shareholders			4
Revised Consolidated Balance Sheets			6
Revised Consolidated Statements of Operations			7
Revised Consolidated Statements of Cash Flows			8
Revised Consolidated Statements of Shareholders’ Equity			9
Notes to the Revised Consolidated Financial Statements			10
Revised Reconciliation to accounting principles generally accepted in the United States			39