UNITED STATES SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-Q

(MARK ONE)

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

For the quarterly period ended DECEMBER 31, 2006

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

For the transition period from                      to                     

Commission file number 1-5507

MAGELLAN PETROLEUM CORPORATION

(Exact name of registrant as specified in its charter)

DELAWARE (State or other jurisdiction of incorporation or organization)	06-0842255 (I.R.S. Employer Identification No.)
10 Columbus Boulevard, Hartford, Connecticut (Address of principal executive offices)	06106 (Zip Code)

(860) 293-2006
(Registrant’s telephone number, including area code)

(Former name, former address and former fiscal year, if changed since last report)

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

     Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). o Yes þ No

     Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, or a non-accelerated filer. See definition of “accelerated filer and large accelerated filer” in Rule 12b-2 of the Exchange Act. (Check one):

Large accelerated filer o Accelerated filer o       Non-accelerated filer þ

     The number of shares outstanding of the issuer’s single class of common stock as of February 6, 2007 was 41,500,325.

MAGELLAN PETROLEUM CORPORATION

FORM 10-Q

DECEMBER 31, 2006

TABLE OF CONTENTS

	PAGE
PART I — FINANCIAL INFORMATION
ITEM 1 Condensed financial statements (unaudited)		3
Condensed consolidated balance sheets at December 31, 2006 and June 30, 2006		3
Condensed consolidated statements of operations for the three and six months ended December 31, 2006 and 2005		4
Condensed consolidated statements of cash flows for the six months ended December 31, 2006 and 2005		5
Notes to condensed consolidated financial statements		6
ITEM 2 Management’s Discussion and Analysis of Financial Condition and Results of Operations		9
ITEM 3 Quantitative and Qualitative Disclosures About Market Risk		17
ITEM 4 Controls and Procedures		17
PART II — OTHER INFORMATION
ITEM 1 Legal Proceedings		18
ITEM 2 Unregistered Sales of Equity Securities and Use of Proceeds		18
ITEM 4 Submission Of Matters To a Vote Of Security Holders		18
ITEM 6 Exhibits		19
Signatures		20
Certifications		21
EX-31: CERTIFICATIONS		21
EX-32: CERTIFICATIONS		22
EX-31: CERTIFICATION
EX-32: CERTIFICATION

2

MAGELLAN PETROLEUM CORPORATION
FORM 10-Q

PART I — FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

CONDENSED CONSOLIDATED BALANCE SHEETS

	DECEMBER 31,			JUNE 30,
	2006			2006
	(UNAUDITED)			(NOTE)
ASSETS
Current assets:
Cash and cash equivalents	$	29,052,509		$	21,882,882
Accounts receivable-trade		6,434,113			4,809,051
Accounts receivable-working interest partners		—			413,786
Marketable securities		385,348			539,675
Inventories		766,904			734,887
Income tax receivable		385,622			—
Other assets		255,749			317,496
Total current assets		37,280,245			28,697,777
Deferred income taxes		240,874			1,129,719
Property and equipment:
Oil and gas properties (successful efforts method)		96,834,561			87,831,709
Land, buildings and equipment		2,695,925			2,448,790
Field equipment		851,699			789,921
		100,382,185			91,070,420
Less accumulated depletion, depreciation and amortization		(73,057,672	)		(63,287,726	)
Net property and equipment		27,324,513			27,782,694
Intangible exploration rights		5,323,347			5,323,347
Goodwill		5,219,167			5,646,747
Total assets	$	75,388,146		$	68,580,284
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities:
Accounts payable	$	2,614,326		$	1,856,515
Accounts payable-working interest partners		690,629			—
Accrued liabilities		1,534,866			1,919,739
Income taxes payable		—			101,746
Total current liabilities		4,839,821			3,878,000
Long term liabilities:
Deferred income taxes		1,638,213			1,435,583
Asset retirement obligations		7,976,905			7,147,261
Total long term liabilities		9,615,118			8,582,844
Contingencies (Note 9)		—			—
Stockholders’ equity:
Common stock, par value $.01 per share:
Authorized 200,000,000 shares: Outstanding 41,500,325 and 41,500,138 shares		415,001			415,001
Capital in excess of par value		73,150,527			73,145,577
Accumulated deficit		(13,390,459	)		(14,412,688	)
Accumulated other comprehensive income (loss)		758,138			(3,028,450	)
Total stockholders’ equity		60,933,207			56,119,440
Total liabilities and stockholders’ equity	$	75,388,146		$	68,580,284

Note: The balance sheet at June 30, 2006 has been derived from the audited consolidated financial statements at that date.

See accompanying notes.

3

MAGELLAN PETROLEUM CORPORATION
FORM 10-Q

PART I — FINANCIAL INFORMATION
December 31, 2006

ITEM 1. FINANCIAL STATEMENTS

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
(unaudited)

	THREE MONTHS ENDED						SIX MONTHS ENDED
	DECEMBER 31,						DECEMBER 31,
	2006			2005			2006			2005
REVENUES:
Oil sales	$	3,227,393		$	2,184,124		$	6,152,907		$	4,639,172
Gas sales		4,490,952			3,715,290			7,894,350			6,933,228
Other production related revenues		695,740			559,604			1,189,992			981,298
Total revenues		8,414,085			6,459,018			15,237,249			12,553,698
COSTS AND EXPENSES:
Production costs		1,806,267			1,949,329			3,597,406			4,158,983
Exploration and dry hole costs		2,541,280			846,517			2,973,263			2,157,958
Salaries and employee benefits		394,972			334,588			710,102			681,040
Depletion, depreciation and amortization		2,762,867			1,539,840			4,764,819			2,902,144
Auditing, accounting and legal services		148,204			118,152			324,009			215,589
Accretion expense		134,413			108,747			266,179			218,716
Shareholder communications		159,342			85,181			235,890			137,530
Loss (gain) on sale of field equipment		—			5,339			—			(149,767	)
Other administrative expenses		644,969			1,032,540			1,167,581			1,717,669
Total costs and expenses		8,592,314			6,020,233			14,039,249			12,039,862
Operating (loss) income		(178,229	)		438,785			1,198,000			513,836
Interest income		425,793			321,117			770,913			661,226
Income before income taxes and minority interests		247,564			759,902			1,968,913			1,175,062
Income tax provision		(255,471	)		(424,910	)		(946,684	)		(615,257	)
(Loss) income before minority interests		(7,907	)		334,992			1,022,229			559,805
Minority interests		—			(561,176	)		—			(814,044	)
NET (LOSS) INCOME		(7,907	)		(226,184	)		1,022,229			(254,239	)
Average number of shares outstanding
Basic		41,500,325			25,783,243			41,500,325			25,783,243
Diluted		41,500,325			25,783,243			41,500,325			25,783,243
NET (LOSS) INCOME PER SHARE (BASIC AND DILUTED)	$	(.00	)	$	(.01	)	$	.02		$	(.01	)

See accompanying notes

4

MAGELLAN PETROLEUM CORPORATION
FORM 10-Q

PART I — FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(unaudited)

	SIX MONTHS ENDED
	DECEMBER 31,
	2006			2005
OPERATING ACTIVITIES:
Net income (loss)	$	1,022,229		$	(254,239	)
Adjustments to reconcile net income loss to net cash provided by operating activities:
Gain from sale of field equipment		—			(149,767	)
Depletion, depreciation and amortization		4,764,819			2,905,331
Accretion expense		266,179			218,716
Deferred income taxes		1,180,020			(661,172	)
Minority interests		—			814,044
Exploration and dry hole costs		2,861,197			1,917,812
Stock option expense		4,950			520,774
Increase (decrease) in operating assets and liabilities:
Accounts receivable		(1,234,337	)		(370,086	)
Other assets		61,748			59,592
Inventories		26,709			(237,161	)
Accounts payable and accrued liabilities		(600,474	)		(305,355	)
Income taxes payable		(469,226	)		(57,249	)
Net cash provided by operating activities		7,883,814			4,401,240
INVESTING ACTIVITIES:
Proceeds from sale of field equipment		—			149,767
Additions to property and equipment		(2,260,338	)		(1,150,482	)
Increase (decrease) in construction payables		1,830,464			(868,723	)
Oil and gas exploration activities		(2,861,197	)		(1,917,812	)
Marketable securities matured		539,675			1,952,880
Marketable securities purchased		(385,347	)		(2,018,433	)
Deferred acquisition costs		—			(869,609	)
Net cash used in investing activities		(3,136,743	)		(4,722,412	)
FINANCING ACTIVITIES:
Dividends to MPAL minority shareholders		—			(765,641	)
Net cash used in financing activities		—			(765,641	)
Effect of exchange rate changes on cash and cash equivalents		2,422,556			(986,811	)
Net increase (decrease) in cash and cash equivalents		7,169,627			(2,073,624	)
Cash and cash equivalents at beginning of period		21,882,882			21,733,375
CASH AND CASH EQUIVALENTS AT END OF PERIOD	$	29,052,509		$	19,659,751
Cash Payments:
Income Taxes		487,312			1,326,997

See accompanying notes.

5

MAGELLAN PETROLEUM CORPORATION
FORM 10-Q
PART I — FINANCIAL INFORMATION
December 31, 2006

ITEM 1: NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Note 1: Basis of Presentation

     Magellan Petroleum Corporation (the Company or MPC) is engaged in the sale of oil and gas and the exploration for and development of oil and gas reserves. At December 31, 2005, MPC’s principal asset was a 55.13% equity interest in its subsidiary, Magellan Petroleum Australia Limited (MPAL). At December 31, 2006, MPAL is a wholly-owned subsidiary of MPC (See Note 2). MPAL’s major assets are two petroleum production leases covering the Mereenie oil and gas field (35% working interest), three petroleum production leases covering the Nockatunga oil field (41% working interest) and one petroleum production lease covering the Palm Valley gas field (52% working interest). Both the Mereenie and Palm Valley fields are located in the Amadeus Basin in the Northern Territory of Australia. The Nockatunga filed is located in the Cooper Basin in South Australia. MPC has a direct 2.67% carried interest in the Kotaneelee gas field in the Yukon Territory of Canada.

     The accompanying unaudited consolidated financial statements include the accounts of MPC and MPAL, collectively the Company, and have been prepared in accordance with accounting principles generally accepted in the United States for interim financial information and with the instructions to Form 10-Q and Rule 10-01 of Regulation S-X. Accordingly, they do not include all of the information and footnotes required by generally accepted accounting principles for complete financial statements. In the opinion of management, all adjustments considered necessary for a fair presentation have been included. All such adjustments are of a normal recurring nature. Operating results for the three and six months ended December 31, 2006 are not necessarily indicative of the results that may be expected for the year ending June 30, 2007. For further information, refer to the consolidated financial statements and footnotes thereto included in the Company’s Annual Report on Form 10-K for the year ended June 30, 2006. All amounts presented are in United States dollars, unless otherwise noted.

     Certain reclassifications of prior period data included in the accompanying consolidated financial statements have been made to conform with current financial statement presentation. Reclassifications associated with the 2005 consolidated statements of operations primarily resulted in a decrease in salaries and employee benefits and an increase in other administrative expenses. For the three months and six months ended December 31, 2005, these amounts were $298,410 and $628,187, respectively.

     Recent Accounting Pronouncements

     In July 2006, the Financial Accounting Standards Board (FASB) issued FASB Interpretation No. 48, “Accounting for Uncertainty in Income Taxes” (“FIN 48”). FIN 48 is an interpretation of FASB Statement No. 109 “Accounting for Income Taxes” and must be adopted by the Company no later than July 1, 2007. FIN 48 prescribes a comprehensive model for recognizing, measuring, presenting, and disclosing in the financial statements uncertain tax positions that the company has taken or expects to take in its tax returns. The Company is currently evaluating the impact of adopting FIN 48 (see Note 9).

     On September 13, 2006, the Securities Exchange Commission issued Staff Accounting Bulletin No. 108 (“SAB 108”) which is effective for the Company’s fiscal year ended June 30, 2007. SAB 108 provides guidance on the consideration of the effects of prior year misstatements in quantifying current year misstatements. The Company believes that SAB 108 will not have a material impact on the consolidated financial statements.

     In September 2006, the FASB issued Statement of Financial Accounting Standards (“SFAS”) No. 157, “Fair Value Measurements,” which provides guidance on how to measure assets and liabilities that use fair value. SFAS 157 will apply whenever another US GAAP standard requires (or permits) assets or liabilities to be measured at fair value but does not expand the use of fair value to new circumstances. The standard will also require additional disclosures in both annual and quarterly reports. SFAS 157 will be effective for financial statements issued for fiscal years beginning after November 15, 2007. The company is currently evaluating the potential impacts of SFAS No. 157 on its financial statements.

6

Note 2. Acquisition of Minority Interest of MPAL

     During the fourth quarter of fiscal 2006, MPC completed an exchange offer (the Offer) to acquire all of the 44.87% of ordinary shares of MPAL that it did not own. Reasons for the Offer included: (1) simplification of Magellan’s corporate structure, (2) greater liquidity for investors, (3) access to capital on potentially more favorable terms for future strategic initiatives or exploration activities, (4) opportunities for cost reductions leading to organizational efficiencies and (5) the potential improvements in cash flow and tangible asset value per share for Magellan. The Offer consideration was .75 newly-issued shares of MPC common stock and A$0.10 in cash consideration for each of the 20,952,916 MPAL shares that the Company did not own. New MPC shares were issued to MPAL’s Australian shareholders either as MPC registered shares or in the form of CDIs (CHESS Depository Interests), which have been listed on the Australian Stock Exchange (“ASX”), effective April 26, 2006, under the symbol “MGN.”

     The Offer was accounted for using the purchase method of accounting. Under the purchase method of accounting, the total purchase price was allocated to the minority interests’ proportionate interest in MPAL’s identifiable assets and liabilities acquired by MPC based upon their estimated fair values. The fair value of the significant assets acquired (primarily oil and gas properties and intangible exploration rights) and the liabilities assumed was determined by management with the assistance of third party valuation experts. This process is not yet complete, thus the purchase price allocation is subject to future refinement through June 30, 2007 (one year after the consummation of the purchase). During the six month period ended December 31, 2006, goodwill was reduced by $427,580, representing an increase of $667,285 to oil and gas properties and a decrease of $200,185 related to deferred income tax liabilities in connection with the ongoing refinement of the purchase price allocation.

Note 3. Capital and stock options

     MPC has a stock repurchase plan to purchase up to one million shares of its common stock in the open market. Through December 31, 2006, MPC had purchased 680,850 of its shares at a cost of approximately $686,000, all of which were cancelled. No shares have been repurchased during fiscal 2006 and 2007.

     The Company’s 1998 Stock Option Plan (the “Plan”) provides for grants of non-qualified stock options principally at an option price per share of 100% of the fair value of the Company’s common stock on the date of the grant and for a term not greater than 10 years. The Plan has 1,000,000 shares authorized for awards of equity share options. Stock options are generally granted with a 3-year vesting period and a 10-year term. The stock options vest in equal annual installments over the vesting period, which is also the requisite service period. The 400,000 options granted to Directors on November 28, 2005 had an immediate vesting period.

     Under the modified prospective application permitted by SFAS 123(R), the Company is required to record compensation expense for all awards granted after the date of adoption and for the unvested portion of previously granted awards that remain outstanding at the date of adoption. Compensation expense has been and will continue to be recorded for the unvested portion of previously issued awards that were outstanding at July 1, 2005 (date of adoption of SFAS 123(R)) using the same estimate of the grant date fair value and the same attribution method used to determine the pro forma disclosure under SFAS No. 123. For the three month periods ended December 31, 2006 and 2005, the Company recorded stock-based compensation expense for the cost of stock options of $1,239 and $518,296 (both pre-tax and post-tax or $.00 per basic and diluted share), respectively. For the six month periods ended December 31, 2006 and 2005, the Company recorded stock-based compensation expense for the cost of stock options of $4,950 and $520,774 (both pre-tax and post-tax or $.00 per basic and diluted share), respectively.

     The Company determined the fair value of the options at the date of grant using the Black-Scholes option pricing model. Option valuation models require the input of highly subjective assumptions including the expected stock price volatility. The assumptions used to value the Company’s grants on July 1, 2004 and November 28, 2005, respectively were: risk free interest rate - 4.95% and 4.58%, expected life — 10 years and 5 years, expected volatility -.518 and .627, expected dividend -0. The expected life of the options granted on November 28, 2005 was determined under the “simplified” method described in SEC Staff Accounting Bulletin No. 107.

						Fair Market
	Expiration	Number of				Value at
Options Outstanding	Dates	Shares			Exercise Prices($)	Grant Date
June 30, 2004			595,000		(1.28 weighted average price)
Granted	Jul. 2014		30,000		1.45	$	43,500
Expired			(595,000	)	1.28
June 30, 2005			30,000		1.45
Granted	Nov. 2015		400,000		1.60	$	640,000
December 31, 2006			430,000		(1.59 weighted average price)

7

     The weighted average remaining contractual term as of December 31 and June 30, 2006 is 8.4 and 8.8 years respectively.

     As of December 31 and June 30, 2006, there was $4,950 and $3,300, respectively of total unrecognized compensation costs related to stock options, which is expected to be recognized in fiscal 2007.

SUMMARY OF OPTIONS OUTSTANDING AT DECEMBER 31, 2006

	EXPIRATION					EXERCISE
	DATES	TOTAL		VESTED		PRICES ($)
Granted 2004	Jul. 2014		30,000		20,000		1.45
Granted 2006	Nov. 2015		400,000		400,000		1.60
OPTIONS RESERVED FOR FUTURE GRANTS			395,000

Note 4. Comprehensive income (loss)

     Total comprehensive income (loss) during the three and six month periods ended December 31, 2006 and 2005 was as follows:

	THREE MONTHS ENDED						SIX MONTHS ENDED
	DECEMBER 31,						DECEMBER 31,					ACCUMULATED OTHER
												COMPREHENSIVE
	2006			2005			2006		2005			(INCOME)LOSS
Balance at June 30, 2006												$	(3,028,450	)
Net (loss) income		(7,907	)		(226,184	)		1,022,229		(254,239	)
Foreign currency translation adjustments		2,510,633			(1,148,430	)		3,786,588		(1,214,190	)		3,786,588
Total comprehensive income (loss)	$	2,502,726		$	(1,374,614	)	$	4,808,817	$	(1,468,429	)
Balance at December 31, 2006												$	758,138

Note 5. Earnings per share

     Earnings per common share are based upon the weighted average number of common and common equivalent shares outstanding during the period. The only reconciling item in the calculation of diluted EPS is the dilutive effect of stock options which were computed using the treasury stock method. For the three and six month periods ended December 31, 2006, the Company did not have any stock options that were issued that had a strike price below the average stock price for the quarter. For the three and six month periods ended December 31, 2005, the Company had 430,000 and 30,000 outstanding options that were antidilutive as the Company reported a loss from continuing operations for the respective periods.

Note 6. Segment Information

     The Company has two reportable segments, MPC and its wholly owned subsidiary, MPAL. Segment information (in thousands) for the Company’s two operating segments is as follows:

	THREE MONTHS ENDED						SIX MONTHS ENDED
	DECEMBER 31,						DECEMBER 31,
	2006			2005			2006			2005
Revenues:
MPC	$	—		$	30		$	1		$	51
MPAL		8,414			6,429			15,236			12,503
Total consolidated revenues	$	8,414		$	6,459		$	15,237		$	12,554
Net (loss) income:
MPC	$	(432	)	$	(875	)		(855	)		(1,178	)
MPAL		424			649			1,877			924
Consolidated net (loss) income	$	(8	)	$	(226	)		1,022			(254	)

	SIX MONTHS ENDED			YEAR ENDED
	DECEMBER 31, 2006			JUNE 30, 2006
Assets:
MPC(1)		63,078			62,248
MPAL		68,748			61,811
Equity elimination		(56,438	)		(55,479	)
Total consolidated assets		75,388			68,580

(1)  Goodwill of $5,219,000 is attributable to MPC.

8

Note 7. Exploration and Dry Hole Costs

     These costs relate primarily to the exploration work being performed on MPAL’s properties. The dry holes were drilled on MPAL properties in Australia. During the quarter ended December 31, 2006, the Company incurred costs of $1,900,000 for PELA 107 and $55,000 for PEL 95 in the Cooper Basin.

Note 8. Asset Retirement Obligations

     A reconciliation of the Company’s asset retirement obligations for the six months ended December 31, 2006 was as follows:

Balance at July 1, 2006	$	7,147,261
Liabilities incurred		—
Liabilities settled		—
Accretion expense		266,179
Revisions to estimate		—
Exchange effect		563,465
Balance at December 31, 2006	$	7,976,905

Note 9 Contingencies

     MPAL, the Company’s wholly-owned Australian subsidiary, has been notified that the Australian Taxation Office (“ATO”) is conducting an audit of the Australian income tax returns of MPAL and its wholly owned subsidiaries for the years 1997- 2005. The Company believes that the ATO inquiry is focused on certain income tax deductions claimed by Paroo Petroleum Pty. Ltd., a wholly-owned subsidiary of MPAL. MPAL has been and will continue to cooperate with the ATO’s inquiry and provide relevant information as requested by the ATO staff. Due to the preliminary and uncertain nature of this matter, the Company is unable at this time to determine 1) whether a possible assessment will result from the ATO’s audit or 2) the magnitude of any possible assessment if any such assessment is issued. Therefore, no loss contingency has been recorded at December 31, 2006. However, the Company believes that if an assessment is issued by the ATO and if such assessment is upheld, it could have a material adverse impact on the Company’s financial condition and results of operations.

ITEM 2 MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

FORWARD LOOKING STATEMENTS

     Statements included in Management’s Discussion and Analysis of Financial Condition and Results of Operations which are not historical in nature are intended to be, and are hereby identified as, forward looking statements for purposes of the “Safe Harbor” Statement under the Private Securities Litigation Reform Act of 1995. The Company cautions readers that forward looking statements are subject to certain risks and uncertainties that could cause actual results to differ materially from those indicated in the forward looking statements. The results reflect fully consolidated financial statements of MPC and MPAL. Among these risks and uncertainties are pricing and production levels from the properties in which the Company has interests, and the extent of the recoverable reserves at those properties. In addition, the Company has a large number of exploration permits and faces the risk that any wells drilled may fail to encounter hydrocarbons in commercially recoverable quantities. The Company undertakes no obligation to update or revise forward-looking statements, whether as a result of new information, future events, or otherwise.

CRITICAL ACCOUNTING POLICIES

Oil and Gas Properties

     The Company follows the successful efforts method of accounting for its oil and gas operations. Under this method, the costs of successful wells, development dry holes and productive leases are capitalized and amortized on a units-of-production basis over the life of the related reserves. Cost centers for amortization purposes are determined on a field-by-field basis. The Company records its proportionate share in joint venture operations in the respective classifications of assets, liabilities and expenses. Unproved properties with significant acquisition costs are periodically assessed for impairment in value, with any impairment charged to expense. The successful efforts method also imposes limitations on the carrying or book value of proved oil and gas properties. Oil and gas properties are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amounts may not be

9

recoverable. The Company estimates the future undiscounted cash flows from the affected properties to determine the recoverability of carrying amounts. In general, analyses are based on proved developed reserves, except in circumstances where it is probable that additional resources will be developed and contribute to cash flows in the future. For Mereenie and Palm Valley, proved developed reserves are limited to contracted quantities. If such contracts are extended, the proved developed reserves will be increased to the lesser of the actual proved developed reserves or the contracted quantities.

     Exploratory drilling costs are initially capitalized pending determination of proved reserves but are charged to expense if no proved reserves are found. Other exploration costs, including geological and geophysical expenses, leasehold expiration costs and delay rentals, are expensed as incurred. Because the Company follows the successful efforts method of accounting, the results of operations may vary materially from quarter to quarter. An active exploration program may result in greater exploration and dry hole costs.

Goodwill and Intangibles

     Goodwill and intangible exploration rights are not amortized. The Company evaluates goodwill and intangible exploration rights for impairment annually or whenever events or changes in circumstances indicate that the carrying value may be impaired in accordance with methodologies prescribed in Statement of Financial Accounting Standards (“SFAS”) SFAS No. 142 “Goodwill and Other Intangible Assets.” During the six month period ended December 31, 2006, goodwill was reduced by $427,580, representing an increase of $667,285 to oil and gas properties and a decrease of $200,185 related to deferred income tax liabilities in connection with the ongoing refinement of the purchase price allocation. There was no impairment of goodwill or intangible exploration rights as of December 31, 2006.

Asset Retirement Obligations

     SFAS 143, “Accounting for Asset Retirement Obligations” requires legal obligations associated with the retirement of long-lived assets to be recognized at their fair value at the time that the obligations are incurred. Upon initial recognition of a liability, that cost is capitalized as part of the related long-lived asset (oil & gas properties) and amortized on a units-of-production basis over the life of the related reserves. Accretion expense in connection with the discounted liability is recognized over the remaining life of the related reserves.

     The estimated liability is based on the future estimated cost of land reclamation, plugging the existing oil and gas wells and removing the surface facilities equipment in the Palm Valley, Mereenie, Kotaneelee, Nockatunga fields and the Cooper Basin. The liability is a discounted liability using a credit-adjusted risk-free rate on the date such liabilities are determined. A market risk premium was excluded from the estimate of asset retirement obligations because the amount was not capable of being estimated. Revisions to the liability could occur due to changes in the estimates of these costs, acquisition of additional properties and as new wells are drilled.

     Estimates of future asset retirement obligations include significant management judgment and are based on projected future retirement costs. Judgments are based upon such things as field life and estimated costs. Such costs could differ significantly when they are incurred.

Revenue Recognition

     The Company recognizes oil and gas revenue from its interests in producing wells as oil and gas is produced and sold from those wells. Oil and gas sold is not significantly different from the Company’s share of production. Revenues from the purchase, sale and transportation of natural gas are recognized upon completion of the sale and when transported volumes are delivered. Shipping and handling costs in connection with such deliveries are included in production costs. Revenue under carried interest agreements is recorded in the period when the net proceeds become receivable, measurable and collection is reasonably assured. The time when the net revenues become receivable and collection is reasonably assured depends on the terms and conditions of the relevant agreements and the practices followed by the operator. As a result, net revenues may lag the production month by one or more months.

Recent Accounting Pronouncements

     In July 2006, the Financial Accounting Standards Board (FASB) issued FASB Interpretation No. 48, “Accounting for Uncertainty in Income Taxes” (“FIN 48”). FIN 48 is an interpretation of FASB Statement No. 109 “Accounting for Income Taxes” and must be adopted by the Company no later than July 1, 2007. FIN 48 prescribes a comprehensive model for recognizing, measuring, presenting,

10

and disclosing in the financial statements uncertain tax positions that the company has taken or expects to take in its tax returns. The Company is currently evaluating the impact of adopting FIN 48 (see Item 2, income taxes).

     On September 13, 2006, the Securities Exchange Commission issued Staff Accounting Bulletin No. 108 (“SAB 108”) which is effective for the Company’s fiscal year ended June, 2007. SAB 108 provides guidance on the consideration of the effects of prior year misstatements in quantifying current year misstatements. The Company believes that SAB 108 will not have a material impact on the consolidated financial statements.

     In September 2006, the FASB issued Statement of Financial Accounting Standards (“SFAS”) No. 157, “Fair Value Measurements,” which provides guidance on how to measure assets and liabilities that use fair value. SFAS 157 will apply whenever another US GAAP standard requires (or permits) assets or liabilities to be measured at fair value but does not expand the use of fair value to new circumstances. The standard will also require additional disclosures in both annual and quarterly reports. SFAS 157 will be effective for financial statements issued for fiscal years beginning after November 15, 2007. The company is currently evaluating the potential impacts of SFAS No. 157 on its financial statements.

Executive Summary

     Magellan Petroleum Corporation (MPC) is engaged in the sale of oil and gas and the exploration for and development of oil and gas reserves.

     MPAL’s major assets are two petroleum production leases covering the Mereenie oil and gas field (35% working interest), and three petroleum production leases covering the Nockatunga oil field (41% working interest) and one petroleum production lease covering the Palm Valley gas field (52% working interest). Both the Mereenie and Palm Valley fields are located in the Amadeus Basin in the Northern Territory of Australia. The Nockatunga field is located in the Cooper Basin in South Australia. Santos Ltd., a publicly owned Australian company, owns a 48% interest in the Palm Valley field and a 65% interest in the Mereenie field.

     MPAL is refocusing its exploration activities into two core areas, the Cooper Basin in onshore Australia and the Weald Basin in the onshore southern United Kingdom with an emphasis on developing a low to medium risk acreage portfolio.

     MPC also has a direct 2.67% carried interest in the Kotaneelee gas field in the Yukon Territory of Canada.

LIQUIDITY AND CAPITAL RESOURCES

Consolidated

     At December 31, 2006 the Company on a consolidated basis had approximately $29.1 million of cash and cash equivalents and $0.4 million of marketable securities.

     Net cash provided by operations was $7,833,814 in 2006 versus $4,401,240 in 2005. The increase in cash provided by operations is primarily related to an increase in net income of $1,276,468, an increase in non cash items of $3,511,427 and a decrease in operating assets of $1,305,321.

     The Company invested $3,291,071 and $3,937,017 in oil and gas exploration activities during the six months ended December 31, 2006 and 2005, respectively. The net decrease is due to an increase in construction payables offset by increased expenditures for property and equipment and oil and gas exploration activities for the six months ended December 31, 2006. The Company continues to invest in exploratory projects that result in exploratory and dry hole expenses in the consolidated financial statements.

Effect of exchange rate changes

     The value of the Australian dollar relative to the U.S. dollar increased 7.8% to $.7872 at December 31, 2006, compared to a value of $.7301 at June 30, 2006.

11

As to MPC

     At December 31, 2006, MPC, on an unconsolidated basis, had working capital of approximately $1.4 million. Working capital is comprised of current assets less current liabilities. MPC’s current cash position and its annual MPAL dividend should be adequate to meet its current and future cash requirements.

     In August 2006, a dividend of approximately $5.9 million was received from MPAL. Also in August 2006, MPC loaned approximately $4.1 million to MPAL payable August, 2011. Interest at the rate of 5.84% on the loan will be paid annually. The tax effect of these transactions was recorded in fiscal year 2006.

     MPC has a stock repurchase plan to purchase up to one million shares of its common stock in the open market. Through December 31, 2006, MPC had purchased 680,850 of its shares at a cost of approximately $686,000, all of which were cancelled. No shares have been repurchased during fiscal 2006 and 2007.

As to MPAL

     At December 31, 2006, MPAL had working capital of approximately $31.1 million. MPAL has budgeted approximately $13.4 million for specific exploration projects in fiscal year 2007 as compared to $3.6 million expended in the six months ended December 31, 2006. However, the total amount to be expended may vary depending on when various projects reach the drilling phase. The current composition of MPAL’s oil and gas reserves are such that MPAL’s future revenues in the long-term are expected to be derived from the sale of gas in Australia. MPAL’s current contracts for the sale of Palm Valley and Mereenie gas will expire during fiscal year 2012 and 2009, respectively. Unless MPAL is able to obtain additional contracts for its remaining gas reserves or be successful in its current exploration program, its revenues will be materially reduced after 2009. The Palm Valley Producers are actively pursuing gas sales contracts for the remaining uncontracted reserves at both the Mereenie and Palm Valley gas fields in the Amadeus Basin. While opportunities exist to contract additional gas sales in the Northern Territory market after these dates, there is strong competition within the market and there are no assurances that the Palm Valley producers will be able to contract for the sale of the remaining uncontracted reserves.

     MPAL expects to fund its exploration costs through its cash and cash equivalents and cash flow from Australian operations. MPAL also expects that it will continue to seek partners to share its exploration costs. If MPAL’s efforts to find partners are unsuccessful, it may be unable or unwilling to complete the exploration program for some of its properties.

OFF BALANCE SHEET ARRANGEMENTS

     The Company does not use off-balance sheet arrangements such as securitization of receivables with any unconsolidated entities or other parties. The Company does not engage in trading or risk management activities and does not have material transactions involving related parties. The following is a summary of our consolidated contractual obligations:

CONTRACTUAL OBLIGATIONS

	PAYMENTS DUE BY PERIOD
									MORE
			LESS THAN						THAN
CONTRACTUAL OBLIGATIONS	TOTAL		1 YEAR		1-3 YEARS		3-5 YEARS		5 YEARS
Operating Lease Obligations		470,000		191,000		279,000		—		—
Purchase Obligations(1)		3,380,000		3,380,000		—		—		—
Asset Retirement Obligations		7,977,000		183,000		5,233,000		—		2,561,000
Total	$	11,827,000	$	3,754,000	$	5,512,000	$	—		2,561,000

(1) Represents firm commitments for exploration and capital expenditures. The Company is committed to these expenditures, however some may be farmed out to third parties. Exploration contingent expenditures of $15,284,000 which are not legally binding have been excluded from the table above and based on exploration decisions would be due as follows: $1,158,000 (less than 1 year), $14,126,000 (1-3 years), $0 (3-5 years).

12

THREE MONTHS ENDED DECEMBER 31, 2006 VS. DECEMBER 31, 2005

REVENUES

     OIL SALES INCREASED 48% in the 2006 quarter to $3,227,000 from $2,184,000 in 2005 because of the 52% increase in volume due mostly to the Nockatunga project, partially offset by the 4% decrease in average sales price per barrel. Oil unit sales (after deducting royalties) in barrels (bbls) and the average price per barrel sold during the periods indicated were as follows:

	THREE MONTHS ENDED DECEMBER 31,
	2006 SALES				2005 SALES
			AVERAGE PRICE				AVERAGE PRICE
	BBLS		A.$ PER BBL		BBLS		A.$ PER BBL
Australia:
Mereenie field		27,871		74.01		25,806		75.02
Cooper Basin		4,010		72.41		3,680		82.62
Nockatunga project		23,037		69.27		6,762		71.14
Total		54,918		71.92		36,248		75.05

     GAS SALES INCREASED 21% to $4,491,000 in 2006 from $3,715,000 in 2005 due mostly to the 14% increase in the average price per mcf sold. Due to a development well (L-38) drilled in the Kotaneelee gas field in which MPC has a carried interest, MPC will not receive any revenue from the operator of this field until its share of the drilling cost is absorbed. Accordingly, the Company does not expect to receive any revenues from the L-38 well until the fourth quarter of fiscal 2007 at the earliest.

     Gas sales by country are as follows:

	THREE MONTHS ENDED
	DECEMBER 31,
	2006		2005
Australia	$	4,491,000	$	3,686,000
Canada		—		29,000
Total	$	4,491,000	$	3,715,000

     The volumes in billion cubic feet (bcf) (after deducting royalties) and the average price of gas per thousand cubic feet (mcf) sold during the periods indicated were as follows:

	THREE MONTHS ENDED DECEMBER 31,
	2006 SALES				2005 SALES
			A.$ AVERAGE				A.$ AVERAGE
			PRICE PER				PRICE PER
	BCF		MCF		BCF		MCF
Australia: Palm Valley		.385		2.20		.448		2.17
Australia: Mereenie		1.250		3.57		1.135		3.11
Total		1.636		3.24		1.583		2.83

     OTHER PRODUCTION RELATED REVENUES INCREASED 24% to $696,000 in 2006 from $560,000 in 2005. Other production related revenues are primarily MPAL’s share of gas pipeline tariff revenues. The revenue increase is due to higher sales volume from the Mereenie field in 2006.

COSTS AND EXPENSES

     PRODUCTION COSTS DECREASED 7% in 2006 to $1,806,000 from $1,949,000 in 2005. The decrease in 2006 was primarily the result of decreased expenditures in the Mereenie field due to the completion of the workover program in 2005 ($247,000), offset partially by increased expenditures in the Nockatunga field ($62,000) and the Cooper Basin ($42,000).

     EXPLORATION AND DRY HOLE COSTS INCREASED 200% to $2,541,000 in 2006 from $847,000 in 2005. These costs related to the exploration work performed on MPAL’s properties. The primary reason for the increase in 2006 was the increased drilling costs related to the Cooper Basin. ($1,530,000).

13

     DEPLETION, DEPRECIATION AND AMORTIZATION INCREASED 79% from $1,540,000 in 2005 to $2,763,000 in 2006. This increase is mostly due to the higher book values of MPAL’s oil and gas properties acquired during fiscal 2006 ($472,000) (see note 2), depreciation of the revised asset retirement obligation recorded in fiscal 2006 ($181,000), and increased depletion in the Nockatunga project due to increased production ($342,000).

     AUDITING, ACCOUNTING AND LEGAL EXPENSES INCREASED 25% in 2006 to $148,000 from $118,000 in 2005 due to higher accounting and auditing costs relating to the reviews and audit of the Company’s consolidated financial statements.

     ACCRETION EXPENSE INCREASED 23% in 2006 from $109,000 in 2005 to $134,000 in 2006. This is due mostly to accretion of the revised asset retirement obligation recorded in fiscal 2006 ($24,000).

     SHAREHOLDER COMMUNICATIONS COSTS INCREASED 87% from $85,000 in 2005 to $159,000 in 2006 primarily because of MPC’s increased costs due to the Exchange Offer and an increase in MPC’s public company costs.

     OTHER ADMINISTRATIVE EXPENSES DECREASED 38% from $1,033,000 in 2005 to $645,000 in 2006. The decrease in the 2006 period is primarily due to a non cash charge for directors’ stock option expense of $516,000 recorded during the quarter ended December 31, 2005.

INCOME TAXES

     INCOME TAX PROVISION DECREASED in 2006 to $255,471 from $424,910 in 2005. The components of the income tax (in thousands) between MPC and MPAL are as follows:

	2006			2005
Income before income taxes and minority interests	$	248		$	760
Tax at 30%		74			228
MPC’s non Australian loss (a)		129			260
Non-taxable revenue from Australian government sources		(114	)		(91	)
MPAL non-taxable foreign income (New Zealand)		2			12
Depletion on step up basis of oil & gas properties		165			12
Australian income tax provision		256			421
MPC income tax provision(a)		—			4
Consolidated income tax provision	$	256		$	425
Current income tax provision	$	19		$	561
Deferred income tax provision (benefit)		237			(136	)
Income tax provision	$	256		$	425
Effective tax rate		103	%		56	%

(a) While MPC did recognize a deferred tax for its non-Australian income tax losses during the 2005 and 2006 quarters, it is not likely that such deferred assets will be realized and therefore have been fully reserved for.

     MPAL, the Company’s wholly-owned Australian subsidiary, has been notified that the ATO is conducting an audit of the Australian income tax returns of MPAL and its wholly owned subsidiaries for the years 1997- 2005. The Company believes that the ATO inquiry is focused on certain income tax deductions claimed by Paroo Petroleum Pty. Ltd., a wholly-owned subsidiary of MPAL. MPAL has been and will continue to cooperate with the ATO’s inquiry and provide relevant information as requested by the ATO staff. Due to the preliminary and uncertain nature of this matter, the Company is unable at this time to determine 1) whether a possible assessment will result from the ATO’s audit or 2) the magnitude of any possible assessment if any such assessment is issued. Therefore, no loss contingency has been recorded at December 31, 2006. However, the Company believes that if an assessment is issued by the ATO and if such assessment is upheld, it could have a material adverse impact on the Company’s financial condition and results of operations.

EXCHANGE EFFECT

     THE VALUE OF THE AUSTRALIAN DOLLAR RELATIVE TO THE U.S. DOLLAR INCREASED TO $.7872 AT DECEMBER 31, 2006 compared to a value of $.7499 at September 30, 2006. This resulted in a $2,510,633 credit to the foreign

14

currency translation adjustments account for the three months ended December 31, 2006. The average exchange rate used to translate MPAL’s operations in Australia was $.7700 for the quarter ended December 31, 2006, which was a 3.4% increase compared to the $.7447 rate for the quarter ended December 31, 2005.

SIX MONTHS ENDED DECEMBER 31, 2006 VS. DECEMBER 31, 2005

REVENUES

     OIL SALES INCREASED 33% in the six months to $6,153,000 from $4,639,000 in 2005 primarily because of a 31% volume increase due mostly to volume increases in Kiana-1 in the Cooper Basin and the Nockatunga project. Oil unit sales (after deducting royalties) in barrels (bbls) and the average price per barrel sold during the periods indicated were as follows:

	SIX MONTHS ENDED DECEMBER 31,
	2006 SALES				2005 SALES
			AVERAGE				AVERAGE
			PRICE				PRICE
	BBLS		A.$ PER BBL		BBLS		A.$ PER BBL
Australia:
Mereenie field		52,782		81.25		53,043		80.60
Cooper Basin		11,013		85.39		4,621		84.78
Nockatunga project		31,002		73.93		14,835		74.18
Total		94,797		79.33		72,499		79.55

     GAS SALES INCREASED 14% to $7,894,000 in 2006 from $6,933,000 in 2005. The increase was the result of an increase in volume and an increase in price per mcf sold.

	SIX MONTHS ENDED
	DECEMBER 31,
	2006		2005
Australia	$	7,893,000	$	6,882,000
Canada		1,000		51,000
Total	$	7,894,000	$	6,933,000

     During the 2006 period, the volume of gas sold in Australia increased 2%, and the average price of gas sold increased 11%. The volumes in billion cubic feet (bcf) (after deducting royalties) and the average price of gas per thousand cubic feet (mcf) sold during the periods indicated were as follows:

	SIX MONTHS ENDED DECEMBER 31,
			2006 SALES				2005 SALES
			A.$ AVERAGE				A.$ AVERAGE
			PRICE				PRICE
			PER				PER
	BCF		MCF		BCF		MCF
Australia: Palm Valley		.781		2.20		.912		2.16
Australia: Mereenie		2.289		3.39		2.101		3.05
Total		3.070		3.08		3.013		2.77

     OTHER PRODUCTION RELATED REVENUES INCREASED 21% to $1,190,000 in 2006 from $981,000 in 2005. Other production related revenues are primarily MPAL’s share of gas pipeline tariff revenues. The revenue increase is due to higher sales volume from the Mereenie field in 2006.

15

COSTS AND EXPENSES

     PRODUCTION COSTS DECREASED 14% IN 2006 to $3,597,000 from $4,159,000 in 2005. The decrease in 2006 was primarily the result of decreased expenditures in the Mereenie field due to the completion of the workover program in 2005 ($806,000), offset partially by increased expenditures in the Nockatunga field ($115,000) and the Cooper Basin ($130,000).

     EXPLORATION AND DRY HOLE COSTS INCREASED 38% to $2,973,000 in 2006 from $2,158,000 in 2005. These costs related to the exploration work performed on MPAL’s properties. The primary reason for the increase in 2006 was the higher drilling costs related to the Cooper Basin. ($1,075,000) partially offset by lower expenditures in New Zealand ($109,000) and the Nockatunga project ($178,000)

     DEPLETION, DEPRECIATION AND AMORTIZATION INCREASED 64% from $2,902,000 in 2005 to $4,765,000 in 2006. This increase is mostly due to the higher book values of MPAL’s oil and gas properties acquired during fiscal 2006 ($863,000) (see note 2) and the depreciation of the revised asset retirement obligation recorded in fiscal 2006 ($305,000), and increased depletion in the Nockatunga project due to increased production ($393,000).

     AUDITING, ACCOUNTING AND LEGAL EXPENSES INCREASED 50% in 2006 to $324,000 from $216,000 in 2005 due to higher accounting and auditing costs relating to the reviews and audit of the Company’s consolidated financial statements.

     ACCRETION EXPENSE INCREASED 21% in 2006 from $219,000 in 2005 to $266,000 in 2006. This is due mostly to accretion of the revised asset retirement obligation recorded in fiscal 2006 ($47,000).

     SHAREHOLDER COMMUNICATIONS COSTS INCREASED 71% from $138,000 in 2005 to $236,000 in 2006 primarily because of MPC’s increased costs due to the Exchange Offer and an increase in MPC’s public company costs.

     OTHER ADMINISTRATIVE EXPENSES DECREASED 32% from $1,718,000 in 2005 to $1,168,000 in 2006. The decrease in the 2006 period is primarily due to a non cash charge for directors’ stock option expense of $516,000 recorded during the six months ended December 31, 2005.

INCOME TAXES

     INCOME TAX PROVISION INCREASED IN 2006 to $946,684 from $615,257 in 2005. The components of the income tax (in thousands) between MPC and MPAL are as follows:

	2006			2005
Income before income taxes and minority interests	$	1,969		$	1,175
Tax at 30%		591			353
MPC’s non Australian loss (a)		257			349
Non-taxable revenue from Australian government sources		(199	)		(166	)
MPAL non-taxable foreign income (New Zealand)		5			55
Depletion on step up basis of oil & gas properties		293			12
Australian income tax provision		947			603
MPC income tax provision(a)		—			12
Consolidated income tax provision	$	947		$	615
Current income tax provision	$	889		$	1,231
Deferred income tax provision (benefit)		58			(616	)
Income tax provision	$	947		$	615
Effective tax rate		48	%		52	%

a) While MPC did recognize a deferred tax for its non-Australian income tax losses during the 2005 and 2006 six month periods, it is not likely that such deferred assets will be realized and have been fully reserved for.

16

     MPAL, the Company’s wholly-owned Australian subsidiary, has been notified that the ATO is conducting an audit of the Australian income tax returns of MPAL and its wholly-owned subsidiaries for the years 1997- 2005. The Company believes that the ATO inquiry is focused on certain income tax deductions claimed by Paroo Petroleum Pty. Ltd., a wholly-owned subsidiary of MPAL. MPAL has been and will continue to cooperate with the ATO’s inquiry and provide relevant information as requested by the ATO staff. Due to the preliminary and uncertain nature of this matter, the Company is unable at this time to determine 1) whether a possible assessment will result from the ATO’s audit or 2) the magnitude of any possible assessment if any such assessment is issued. Therefore, no loss contingency has been recorded at December 31, 2006. However, the Company believes that if an assessment is issued by the ATO and if such assessment is upheld, it could have a material adverse impact on the Company’s financial condition and results of operations.

EXCHANGE EFFECT

     THE VALUE OF THE AUSTRALIAN DOLLAR RELATIVE TO THE U.S. DOLLAR INCREASED TO $.7872 at December 31, 2006 compared to a value of $.7301 at June 30, 2006. This resulted in a $3,787,000 credit to the foreign currency translation adjustments account for the six months ended December, 2006. The average exchange rate used to translate MPAL’s operations in Australia was $.7636 for the six month period ended December 31, 2006, which was a 1.5% increase compared to the $.7524 rate for the six month period ended December 31, 2005.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURE ABOUT MARKET RISK

     The Company does not have any significant exposure to market risk, other than as previously discussed regarding foreign currency risk and the risk of fluctuations in the world price of crude oil, as the only market risk sensitive instruments are its investments in marketable securities. At December 31, 2006, the carrying value of our investments in marketable securities including those classified as cash and cash equivalents was approximately $29.4 million, which approximates the fair value of the securities. Since the Company expects to hold the investments to maturity, the maturity value should be realized. A 10% change in the Australian foreign currency rate compared to the U.S. dollar would increase or decrease revenues and costs and expenses by $1,524,000 and $1,404,000, for the six months, respectively. For the six month period ended December 31, 2006, oil sales represented approximately 44% of production revenues. Based on the current six month’s sales volume and revenue, a 10% change in oil price would increase or decrease oil revenues by $615,000. Gas sales, which represented approximately 56% of production revenues in the current six months, are derived primarily from the Palm Valley and Mereenie fields in the Northern Territory of Australia and the gas prices are set according to long term contracts that are subject to changes in the Australian Consumer Price Index (ACPI) for the six months ended December 31, 2006.

ITEM 4. CONTROLS AND PROCEDURES

     Disclosure Controls and Procedures

     An evaluation was performed under the supervision and with the participation of the Company’s management, including Daniel J. Samela, the Company’s President, Chief Executive Officer and Chief Financial Officer, of the effectiveness of the design and operation of the Company’s disclosure controls and procedures (as defined in Rule 13a-15(e) and Rule 15d-15(e) promulgated under the Securities and Exchange Act of 1934) as of December 31, 2006. Based on this evaluation, the Company’s President concluded that the Company’s disclosure controls and procedures were effective such that the material information required to be included in the Company’s SEC reports is recorded, processed, summarized and reported within the time periods specified in SEC rules and forms relating to the Company, including its consolidated subsidiaries, and the information required to be disclosed was accumulated and communicated to management as appropriate to allow timely decisions for disclosure.

     Internal Control Over Financial Reporting.

     There have not been any changes in the Company’s internal control over financial reporting (as such term is defined in Rules 13a-15(f) and 15d-15(f) under the Exchange Act) during the fiscal quarter ended December 31, 2006 that have materially affected, or are reasonably likely to materially affect, the Company’s internal control over financial reporting.

17

MAGELLAN PETROLEUM CORPORATION
FORM 10-Q

PART II — OTHER INFORMATION

DECEMBER 31, 2006

ITEM 1 LEGAL PROCEEDINGS

     MPAL, the Company’s wholly-owned Australian subsidiary, has been notified that the ATO is conducting an audit of the Australian income tax returns of MPAL and its wholly-owned subsidiaries for the years 1997- 2005. The Company believes that the ATO inquiry is focused on certain income tax deductions claimed by Paroo Petroleum Pty. Ltd., a wholly-owned subsidiary of MPAL. MPAL has been and will continue to cooperate with the ATO’s inquiry and provide relevant information as requested by the ATO staff. Due to the preliminary and uncertain nature of this matter, the Company is unable at this time to determine 1) whether a possible assessment will result from the ATO’s audit or 2) the magnitude of any possible assessment if any such assessment is issued. Therefore, no loss contingency has been recorded at December 31, 2006. However, the Company believes that if an assessment is issued by the ATO and if such assessment is upheld, it could have a material adverse impact on the Company’s financial condition and results of operations.

ITEM 2 UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

     The following schedule sets forth the number of shares that the Company has repurchased under any of its repurchase plans for the stated periods, the cost per share of such repurchases and the number of shares that may yet be repurchased under the plans:

					TOTAL NUMBER OF SHARES
					PURCHASED AS PART OF		MAXIMUM NUMBER OF SHARES
	TOTAL NUMBER OF		AVERAGE PRICE		PUBLICLY ANNOUNCED PLAN		THAT MAY YET BE
PERIOD	SHARES PURCHASED		PAID SHARE		(1)		PURCHASED UNDER PLAN
July 1-31, 2006		0		0		0		319,150
Aug. 1-31, 2006		0		0		0		319,150
Sept. 1-30, 2006		0		0		0		319,150

(1) The Company through its stock repurchase plan may purchase up to one million shares of its common stock in the open market. Through December 31, 2006, the Company had purchased 680,850 of its shares at an average price of $1.01 per share or a total cost of approximately $686,000, all of which shares have been cancelled.

ITEM 4 SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS

     (a) On December 7, 2006, the Company held its 2006 Annual General Meeting of Stockholders.

     (b) The following directors were elected as directors of the Company. The vote was as follows:

	Shares				Stockholders
	For		Withheld		For		Withheld
Donald Basso		32,276,578		848,951		1,200		124
Robert Mollah		32,198,327		927,202		1,210		114

     (c) The firm of Deloitte & Touche LLP was appointed as the Company’s independent auditors for the year ending June 30, 2007. The vote was as follows:

	Shares		Stockholders
For		32,707,555		1,219
Against		212,493		45
Abstain		205,481		60

18

ITEM 6. EXHIBITS

31. Rule 13a-14(a) Certifications.

Certification of Daniel J. Samela, President, Chief Executive Officer and Chief Financial and Accounting Officer, pursuant to Rule 13a-14(a) under the Securities Exchange Act of 1934 is filed herein.

32. Section 1350 Certifications.

Certification of Daniel J. Samela, President, Chief Executive Officer and Chief Financial and Accounting Officer, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, is furnished herein.

19

MAGELLAN PETROLEUM CORPORATION
FORM 10-Q
DECEMBER 31, 2006

SIGNATURES

     Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized:

	MAGELLAN PETROLEUM CORPORATION                               Registrant
Date: February 13 , 2007	By	/s/ Daniel J. Samela
		Daniel J. Samela, President and Chief Executive Officer,
		Chief Financial and Accounting Officer

20