Exhibit 99.1

 

 

 

 Gran Tierra Energy Announces Fourth Quarter and 2011 Year-End Results

 

Company Reports Record Levels of Proved Reserves, Production Volumes, and Revenues

 

CALGARY, Alberta, February 27, 2012, Gran Tierra Energy Inc. (“Gran Tierra Energy”) (NYSE Amex: GTE, TSX: GTE), a company focused on oil exploration and production in South America, today announced financial and operating results for the quarter and year ended December 31, 2011.  All dollar amounts are in United States dollars unless otherwise indicated.

 

Financial and operating highlights for the year include:

 

·

In 2011, oil and natural gas production net after royalty (“NAR”) and inventory adjustments averaged 17,408 barrels of oil equivalent per day (“BOEPD”), an increase of 20% over 2010;

·

Estimated proved oil and natural gas liquids (“NGL”) reserves, NAR, as at December 31, 2011, were 30.9 million barrels (“MMbbl”), a 31% increase from Gran Tierra Energy’s estimated proved reserves as at December 31, 2010;

·

Estimated proved gas reserves, NAR, as at December 31, 2011, were 18.3 billion cubic feet (“Bcf”) compared with 1.2 Bcf as at December 31, 2010;

·

Revenue and other income increased by 60% to $597.4 million in 2011 compared with $374.5 million in 2010;

·

Net income grew by 241% from the prior year to $126.9 million, representing basic net income per share of $0.46 and diluted net income per share of $0.45. This compares with net income of $37.2 million, or $0.15 per share basic and $0.14 per share diluted, in 2010;

·

Funds flow from operations increased 57% to $319.0 million in 2011 from $203.1 million in 2010;

·

Cash and cash equivalents was $351.7 million as at December 31, 2011 compared to $355.4 million as at December 31, 2010;

·

Completed the acquisition of Petrolifera Petroleum Limited (“Petrolifera”) on March 18, 2011;

·

Commenced production from the Moqueta field in Colombia in June of 2011 and successfully drilled three additional appraisal wells;

·

Discovered oil on the Rinconada Norte Block in Argentina with the RN x-1004 exploration well and made a second oil discovery on the Garibay Block in Colombia with the Melero-1 exploration well;

·

Stabilized production from the Puesto Morales Block in Argentina and drilled two new development wells on the Puesto Morales Este Block;

·

Announced two farm-in agreements with Statoil do Brasil Ltda. (“Statoil”). Statoil is a partner in a joint venture with PetróleoBrasileiro S.A. in the two blocks in Brazil’s deepwater offshore Camamu-Almada Basin; and

·

Expanded Gran Tierra Energy’s partnership with Compania Espanola de Petroleos, S.A.U. (“CEPSA”) with two farm-in agreements, adding new exploration acreage in the Llanos Basin.

“2011 was another year of success strategically, operationally and financially.  Strategically, we added new exploration acreage and drilling prospects to the portfolio in all four countries of operations, and established partnerships with strategic players in the region.  Operationally, we attained record levels of production and reserves through a combination of superior reservoir management of existing reserves, appraisal success of recent exploration discoveries, and the acquisition of Petrolifera.  Financially, revenues, net income and funds flow from operations reached record levels due to record production levels and robust oil markets,” said Dana Coffield, President and CEO of Gran Tierra Energy. “Although we had a number of exploration disappointments last year, this year is starting with positive indications at Ramiriqui-1 in Colombia, and we have several other very exciting exploration wells to be drilled this year in Peru and Brazil.  As before, our balance sheet remains strong, with our 2012 capital program expected to be funded out of cash flow and cash at current oil prices, as we diligently execute on the continued growth of Gran Tierra Energy.”

 

 

 

 Production Review

 

		Three Months Ended December 31, 2011																Three Months Ended December 31, 2010
(Barrels of Oil Equivalent)		Colombia				Argentina				Brazil				Total				Colombia				Argentina				Brazil				Total
Gross Production			1,938,687				303,374				22,620				2,264,681				1,877,879				86,153				-				1,964,032
Royalties			(513,372	)			(35,690	)			(2,822	)			(551,884	)			(505,372	)			(9,922	)			-				(515,294	)
Inventory Adjustment			(2,390	)			(4,298	)			(2,177	)			(8,865	)			17,180				(514	)			-				16,666
Production Net After Royalties (NAR)			1,422,925				263,386				17,621				1,703,932				1,389,687				75,717				-				1,465,404
Barrels of Oil Equivalent Per Day (BOEPD) (NAR)			15,467				2,863				192				18,521				15,105				823				-				15,928

  

		Year Ended December 31, 2011																Year Ended December 31, 2010
(Barrels of Oil Equivalent)		Colombia				Argentina				Brazil				Total				Colombia				Argentina				Brazil				Total
Gross Production			7,470,409				1,040,349				53,830				8,564,588				6,784,261				324,674				-				7,108,935
Royalties			(2,066,860	)			(119,545	)			(6,657	)			(2,193,062	)			(1,799,947	)			(37,727	)			-				(1,837,674	)
Inventory Adjustment			(10,062	)			(3,446	)			(4,115	)			(17,623	)			4,992				(2,903	)			-				2,089
Production Net After Royalties (NAR)			5,393,487				917,358				43,058				6,353,903				4,989,306				284,044				-				5,273,350
Barrels of Oil Equivalent Per Day (BOEPD) (NAR)			14,777				2,513				118				17,408				13,670				778				-				14,448

 

Financial Review 

 

		Three Months Ended December 31,												Year Ended December 31,
		2011				2010				% Change				2011				2010				% Change
(Thousands of U.S. Dollars)
Revenue and Other Income		$	161,735			$	112,667				44			$	597,407			$	374,460				60
Net income (loss)		$	32,552			$	13,118				148			$	126,917			$	37,172				241
(US Dollars per Share)
Net Income (Loss) Per Share - Basic		$	0.12			$	0.05				140			$	0.46			$	0.15				207
Net Income (Loss) Per Share - Diluted		$	0.11			$	0.04				175			$	0.45			$	0.14				221

 

 

 Funds flow From Operations - Non-GAAP Measure 

 

		Three Months Ended December 31,								Year Ended December 31,
		2011				2010				2011				2010
(Thousands of U.S. Dollars)
Net income		$	32,552				13,118			$	126,917				37,172
Adjustments to reconcile net income to funds flow from operations
Depletion, depreciation, accretion and impairment			71,061				56,335				231,235				163,573
Deferred taxes			(13,734	)			7,936				(29,222	)			(20,090	)
Stock-based compensation			3,384				2,601				12,767				8,025
Unrealized gain on financial instruments			-				-				(1,354	)			(44	)
Unrealized foreign exchange (gain) loss			(1,831	)			(12,350	)			(1,695	)			14,786
Settlement of asset retirement obligation			(36	)			(23	)			(345	)			(286	)
Equity taxes payable long-term			(999	)			-				2,442				-
Gain on acquisition			-				-				(21,699	)			-
Funds flows from operations		$	90,397			$	67,617			$	319,046			$	203,136

 

(1)

Funds flow from operations is a non-GAAP measure which does not have any standardized meaning prescribed under generally accepted accounting principles in the United States of America (“GAAP”). Management uses this financial measure to analyze operating performance and the income generated by the principal business activities prior to the consideration of how non-cash items affect that income, and believes that this financial measure is also useful supplemental information for investors to analyze operating performance and financial results. Investors should be cautioned that this measure should not be construed as an alternative to net income or other measures of financial performance as determined in accordance with GAAP. The method of calculating this measure may differ from other companies and, accordingly, it may not be comparable to similar measures used by other companies. Funds flow from operations, as presented, is net income adjusted for depletion, depreciation, accretion and impairment (“DD&A”), deferred taxes, stock-based compensation, gain on financial instruments, unrealized foreign exchange (gain) loss, settlement of asset retirement obligation, equity tax and gain on acquisition.

 

Fiscal 2011 Highlights

 

Net income was $126.9 million, or $0.46 per share basic and $0.45 per share diluted, in 2011 compared with $37.2 million, or $0.15 per share basic and $0.14 per share diluted, in 2010. Increased oil and natural gas sales due to increased production and higher realized oil prices, a $21.7 million gain on the Petrolifera acquisition and the absence of foreign exchange losses were partially offset by a $42.0 million impairment loss in the Peru cost center, a $25.7 million impairment loss in the Argentina cost center, a Colombian equity tax of $8.3 million and increased operating, depreciation, depletion, and accretion and general and administrative (“G&A”) expenses.

 

Oil and NGL production, NAR and inventory changes, in 2011 increased to 6.1 MMbbl, a 17% increase compared with 5.2 MMbbl in 2010. The increase was due to improved production from the Moqueta, Jilguero and Juanambu fields, production from Petrolifera and the reduced impact of pipeline interruptions. Petrolifera’s oil and NGL production for the period since the acquisition date, NAR, was 0.5 MMbbl.

 

Average realized oil prices in 2011 increased by 36% to $96.60 per barrel from $71.19 per barrel in 2010 reflecting higher West Texas Intermediate (“WTI”) oil prices and the premium to WTI received in Colombia during 2011. The average WTI oil price for 2011 was $95.06 as compared to $79.43 in 2010.

 

Increased production and higher oil prices resulted in a 60% increase in revenue and other income to $597.4 million for 2011 compared with 2010.

 

Operating expenses for 2011 amounted to $86.5 million, or $13.61 per barrel of oil equivalent (“BOE”), compared with $59.4 million or $11.27 per BOE, in 2010. The increase in operating expenses was primarily due to an increase of $18.3 million in operating costs in Argentina ($15.9 million related to properties acquired from Petrolifera) and increases of $7.7 million in Colombia and $1.0 million in Brazil as a result of expanded operations.

 

 

DD&A expenses for 2011 increased to $231.2 million compared with $163.6 million in 2010. DD&A expenses for 2011 includes a $42.0 million ceiling test impairment for the Peru cost center relating to seismic and drilling costs from two blocks which were relinquished, a $25.7 million impairment loss in the Argentina cost center related to an increase in estimated future operating and capital costs to produce the remaining Argentine proved reserves and a decrease in reserve volumes and $18.4 million of depletion, depreciation and accretion related to properties acquired from Petrolifera. DD&A expenses in 2010 included a $23.6 million ceiling test impairment in the Argentina cost center, of which $17.9 million related to the abandonment of the GTE.St.VMor-2001 sidetrack operations. On a BOE basis, DD&A in 2011 was $36.39 compared with $31.02 for 2010, representing a 17% increase resulting from the same factors.

 

G&A expenses of $60.4 million for 2011 were 50% higher than in 2010 due to increased employee related costs reflecting the expanded operations in all business segments, $1.2 million of expenses associated with the acquisition of Petrolifera and the inclusion of Petrolifera G&A expenses of $7.3 million (including interest on bank debt of $1.6 million, which was retired in August 2011). G&A expenses per BOE increased 25% to $9.50 per BOE compared with $7.63 per BOE for 2010 due to the same factors.

 

Equity tax represents a Colombian tax of 6% on a legislated measure which is based on the Colombian segment’s balance sheet equity at January 1, 2011. The equity tax is assessed every four years.

 

The gain on acquisition in 2011 relates to the acquisition of Petrolifera. This gain reflects the impact on Petrolifera’s pre-acquisition market value of its lack of liquidity and capital resources required to maintain production and reserves and further develop and explore its inventory of prospects.

 

There were essentially no foreign exchange gains or losses as a result of an unrealized non-cash foreign exchange gain of $1.7 million being offset by realized foreign exchange losses. The non-cash foreign exchange gain primarily relates to the translation of deferred tax liabilities. This compares to a foreign exchange loss of $16.8 million recorded in 2010, of which $14.8 million was an unrealized non-cash foreign exchange loss. Under GAAP, deferred taxes are considered a monetary liability and require translation from local currency to U.S. dollar functional currency at each balance sheet date. This translation results in the recognition of unrealized exchange losses or gains. The Colombian Peso devalued by 1.5% against the US dollar in the year ended December 31, 2011 resulting in an unrealized foreign exchange gain which was offset by realized foreign exchange losses. In 2010, the Colombian Peso strengthened against the US dollar by 6%.

 

Income tax expense for 2011 was $107.3 million compared with $57.2 million in 2010. This represents an increase of 103%, primarily as a result of higher net income in Colombia. For the year ended December 31, 2011, the effective income tax rate was 46% compared with 61% in 2010 due to a decrease in non-taxable foreign currency translation adjustments and the non-taxable gain on acquisition in 2011, partially offset by an increase in the valuation allowance on deferred tax assets mainly in Peru. The variance in the effective tax rates compared with the 35% U.S. statutory rate was attributable to the same factors and other permanent differences.

 

Balance Sheet Highlights

 

Cash and cash equivalents was $351.7 million as at December 31, 2011 compared to $355.4 million as at December 31, 2010. The change in cash and cash equivalents during 2011 was primarily the result of $333.2 million of capital expenditures offset by funds flow from operations of $319.0 million and a decrease in non-cash working capital of $37.8 million. Gran Tierra Energy is debt free.

 

Reserve and Production Highlights

 

Estimated proved oil and NGL reserves, NAR, as at December 31, 2011, were 30.9 MMbbl, a 31% increase from the estimated proved reserves as at December 31, 2010. The increase was due to the acquisition of Petrolifera which had reserves in Argentina and Colombia, positive technical revisions to Costayaco reserves (based on reservoir performance), the drilling of additional appraisal wells in the Moqueta field and the acquisition of a 70% working interest in Block 155 in Brazil which more than offset 2011 oil production of approximately 6.1 MMbbl NAR. Estimated probable and possible oil and NGL reserves, NAR, as at December 31, 2011 were 10.5 MMbbl and 17.6 MMbbl, respectively.

 

Estimated proved gas reserves, NAR, as at December 31, 2011, were 18.3 Bcf compared with 1.2 Bcf at December 31, 2010. The increase was due to the acquisition of Petrolifera. At December 31, 2011, 75% of proved gas reserves were in the Sierra Nevada Block and 19% were in the Puesto Morales Block, both of which were acquired in the Petrolifera acquisition. Estimated probable and possible gas reserves, NAR, as at December 31, 2011 were 25.7 Bcf and 116.5 Bcf, respectively

 

As per Canadian National Instrument 51-101 - Standards of Disclosure for Oil and Gas Activities (“NI 51-101”) and the reserves definitions in the Canadian Oil and Gas Evaluation Handbook (“COGEH”), oil reserves NAR to Gran Tierra Energy as at December 31, 2011 are approximately 31.0 MMbbl proved, 10.6 MMbbl probable, and 18.2 MMbbl possible, and 59.8 MMbbl total 3P reserves. This compares to reserves as at December 31, 2010 of 23.3 MMbbl proved, 7.3 MMbbl probable and 16.2 MMbbl possible, and total 3P reserves of approximately 46.8 MMbbl.

 

 

Similarly, as per NI 51-101 and COGEH, gas reserves NAR to Gran Tierra Energy as at December 31, 2011 are approximately 18.3 Bcf proved, 25.8 Bcf probable, and 116.5 Bcf possible, and 160.6 Bcf total 3P reserves. This compares to reserves as at December 31, 2010 of 1.2 Bcf proved, 0.1 Bcf probable and 42.1 Bcf possible, and total 3P reserves of approximately 43.4 Bcf.

 

Possible reserves are those additional reserves that are less certain to be recovered than probable reserves. There is a 10% probability that the quantities actually recovered will equal or exceed the sum of proved plus probable plus possible (3P) reserves.

 

Annual production for 2011 averaged approximately 23,400 company interest BOEPD before royalties, or 17,408 BOEPD NAR, an increase of approximately 21% versus 14,440 BOEPD NAR in 2010. Production in the fourth quarter of 2011 averaged approximately 18,600 BOEPD NAR.

 

BOEs may be misleading, particularly if used in isolation. A BOE conversion ratio of 6 thousand cubic feet to one barrel is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead.

 

Fourth Quarter 2011 Operational Highlights

 

Colombia

 

Gran Tierra Energy announced that it had entered into a farm-in agreement with CEPSA Colombia S.A., a wholly-owned subsidiary of CEPSA, whereby Gran Tierra Energy will earn a 45% working interest (“WI”) in Concession Contract Llanos-22 (CEPSA will retain a 55% WI and Operatorship) and CEPSA will farm-in for a 30% WI on the Piedemonte Norte Block (Gran Tierra Energy will retain a 70% WI and Operatorship). The completion of the two transactions is subject to obtaining regulatory approval from Colombia’s Agencia Nacional de Hidrocarburos (“ANH”) and other customary conditions of closing.

 

Gran Tierra Energy announced the Rumiyaco-1 and Brillante SE-2 wells were plugged and abandoned. New 3-D seismic data over the Brillante field indicates the original fault block with the discovery well is larger than originally interpreted from old 2-D seismic data; future drilling will focus on proving additional reserves in that area.

 

Brazil

 

Drilling of the 1-GTE-01-BA vertical pilot oil exploration well was completed on November 24, 2011. The well is located in Block REC-T-142 in the prolific onshore Recôncavo Basin. Core samples were acquired from the prospective reservoir section of the pilot well and Gran Tierra Energy plans to drill a horizontal sidetrack in mid-2012 to test the productivity of the light oil sandstone reservoir targets.

 

Drilling of the 1-GTE-02-BA oil exploration well began on November 23, 2011. This well is located in Block REC-T-129 in the Recôncavo Basin. The well reached total depth of approximately 6,412 feet measured depth (“MD”) and is suspended while plans are finalized for drilling a horizontal leg in mid-2012.

 

Drilling of the 3-GTE-03-BA delineation well began on December 1, 2011 to further develop the existing discovery on Block REC-T-155 in the Recôncavo Basin. The well is situated 1.2 kilometers north of the 1-ALV-2-BA discovery well. Oil bearing reservoir intervals in the Sergi and Agua Grande formations were encountered and the company is moving forward with plans to complete and place the well on production.

 

Peru

 

A drilling location was identified for the first exploration well on Block 95, with civil construction initiated in the third quarter of 2011. Drilling is expected to be undertaken in the second half of 2012, pending regulatory approvals. An oil field has already been discovered on Block 95, with the discovery well drilled in 1974 flowing 807 BOPD naturally without pumps. The new exploration well is expected to further delineate this field and explore deeper reservoir horizons not penetrated by the discovery well.

 

Permitting for drilling on Block 107 was advanced. A 390 km infill 2D seismic program is planned for the second half of 2012 on Block 107 in the Ucayali Basin in preparation for oil exploration drilling in 2013. The prospects on Block 107 are on trend with the world class gas-condensate discoveries that have been made in the Camisea region in southern Peru. Both oil and gas seeps are present on Block 107. Geologic studies are ongoing on the adjacent Block 133 in preparation for seismic acquisition in 2013.

 

 

Gran Tierra Energy is evaluating the prospectivity of Blocks 123 and 129 based on recently acquired 2D seismic data together with its joint venture partners ConocoPhillips (Operator) and Talisman.  An infill seismic program consisting of 567 km of 2D seismic is planned to be acquired in the first half of 2012.

 

Argentina 

 

Gran Tierra Energy has completed drilling PME.a-1003 and PMEa-1004, the first of four new development wells planned in the Puesto Morales field of the Neuquen Basin, with the purpose of improving recovery and growing production from this mature oil field. Since taking over operatorship in March, the production decline of the last several years has been halted with a work-over program on existing wellbores.

 

Operational Events Subsequent to Year-End 2011

 

In Colombia, drilling continues on the Ramiriqui-1 exploration well in the Llanos-22 Block, located in the Andean foothills trend of the Llanos Basin. The Mirador formation is interpreted as oil bearing with up to 130 feet MD gross thickness based on cuttings and logging while drilling. Casing has been set and drilling is continuing in order to evaluate deeper reservoir potential. Testing is planned after the completion of drilling.

 

Also in Colombia, the Pacayaco-1ST1 exploration well reached total true vertical depth of 5,343 feet. Approximately ten feet of oil column in the T-Sandstone was interpreted from cuttings and evaluation of wireline logs. It was determined that the formation did not contain economic quantities of hydrocarbons so the well was plugged and abandoned.

 

In Brazil, drilling of the 3-GTE-04-BA delineation well in Block REC-T-155 began on January 8, 2012. The well is situated 0.70 kilometers south-southeast of the 1-ALV-2-BA discovery well.

 

Also in Brazil, on February 17, 2012, in accordance with the terms of a farmout agreement, Gran Tierra Energy gave notice to Statoil that Gran Tierra Energy would not enter into and assume its share of the work obligations of the second exploration period of Block BM-CAL-10. As a result, the farmout agreement has terminated and Gran Tierra Energy will not receive any interest in the block. Pursuant to the farmout agreement, Gran Tierra Energy is obligated to make payment for a certain percentage of the costs relating to Block BM-CAL-10, which relate primarily to the well that was drilled during the term of the farmout agreement. Gran Tierra Energy expects to make that payment, in the approximate amount of $26 million, in March 2012.  In the first quarter of 2012, Gran Tierra Energy received government approval relating to the farmout agreement for Block BM-CAL-7.

 

In Peru, on January 17, 2012, PeruPetro signed the assignment documents for Block 95, officially transferring a 60% WI in the Block to Gran Tierra Energy.

 

2012 Work Program and Capital Expenditure Program

 

Gran Tierra Energy previously announced a $367 million planned capital program for its exploration and production operations in Colombia, Brazil, Peru and Argentina in 2012. The capital spending program allocates $246 million for drilling, $39 million for facilities, equipment, pipelines, and $82 million for seismic activities.  The budget currently contemplates the drilling of 11 wells in Colombia, 13 wells in Argentina, two wells in Brazil and one well in Peru. The approved 2012 capital spending program also includes funds for 1,154 km of 2D and 427 km² of 3D seismic acquisition programs in Colombia, Peru, Argentina and Brazil, primarily in preparation for additional exploration and production drilling operations in 2013 and beyond. The 2012 work program and budget is expected to be funded primarily from cash flows from operations, with the balance from cash on hand as necessary, at current oil prices.

 

Excluding potential exploration success, production in 2012 is expected to range between 26,000 to 27,000 BOEPD gross, or 20,000 to 21,000 BOEPD NAR. Approximately 95% of this production consists of light oil, with the balance consisting of natural gas.

 

In early February 2012, a pipeline disruption on the Ecopetrol-operated OTA pipeline in Colombia resulted in reduced oil sales for a portion of early February. Gran Tierra Energy production from January 1, 2012 to February 21, 2012, has averaged approximately 18,300 BOEPD NAR. Production has now resumed to approximately 19,000 BOEPD NAR.

 

Conference Call Information:

 

Gran Tierra Energy Inc. will host its fourth quarter and year-end 2011 results conference call on Tuesday , February 27th at 4:00 p.m. Eastern Standard Time (EST). Prior to the conference call, Gran Tierra Energy will release its financial results on February 27^th before markets open.

 

 

President and CEO Dana Coffield, COO Shane O’Leary and acting CFO James Rozon will discuss Gran Tierra Energy’s financial and operating results for the quarter and then take questions from securities analysts and institutional shareholders.

  

Interested parties may access the conference call by dialing 1-800-299-7635 (domestic) or 617-786-2901 (international), pass code 28864986. The call will also be available via web cast at www.grantierra.com, www.streetevents.com, or www.fulldisclosure.com. The web cast will be available on Gran Tierra Energy’s website until the next earnings call.

 

If you are unable to participate, an audio replay of the call will be available beginning two hours after the call until 11:59 p.m. on March 12, 2012.  To access the replay dial 888-286-8010 (domestic) or 617-801-6888 (international) pass code 44218592.

 

Please connect at least 15 minutes prior to the conference call to ensure adequate time for any software download that may be required to join the webcast.

 

About Gran Tierra Energy Inc.

 

Gran Tierra Energy is an international oil and gas exploration and production company, headquartered in Calgary, Canada, incorporated in the United States, trading on the NYSE Amex Exchange (GTE) and the Toronto Stock Exchange (GTE), and operating in South America. Gran Tierra Energy holds interests in producing and prospective properties in Argentina, Colombia, Peru, and Brazil. Gran Tierra Energy has a strategy that focuses on establishing a portfolio of producing properties, plus production enhancement and exploration opportunities to provide a base for future growth.

 

Gran Tierra Energy’s Securities and Exchange Commission filings are available on a web site maintained by the Securities and Exchange Commission at http://www.sec.gov and on SEDAR at http://www.sedar.com.

 

Additional information concerning Gran Tierra Energy is available at www.grantierra.com, on SEDAR (www.sedar.com) and with the Securities and Exchange Commission (www.sec.gov).

 

Forward Looking Statements:

 

The statements in this news release regarding Gran Tierra Energy’s expected funding of its 2012 capital spending program out of cash flow and current cash, its planned drilling and explorations activities for 2012, and expected production for 2012, together with all other statements regarding expected or planned development, testing, drilling or exploration, or that otherwise reflect expected future results or events, constitute forward looking information and forward looking statements or financial outlook (collectively, “forward-looking statements”) under the meaning of applicable securities laws, including Canadian Securities Administrators’ National Instrument 51-102 Continuous Disclosure Obligations and the United States Private Securities Litigation Reform Act of 1995. Words such as “will,” “expected,” “plans, “planned” and similar words identify statements as forward-looking statements.

 

The forward-looking statements contained in this news release reflect several material factors and expectations and assumptions of Gran Tierra Energy including, without limitation, assumptions relating to the accuracy of Gran Tierra Energy’s reserves estimates, the accuracy of test results, that Gran Tierra Energy will continue to conduct its operations in a manner consistent with past operations and the general continuance of current or, where applicable, assumed operational and industry conditions. Gran Tierra Energy believes the material factors, expectations and assumptions reflected in the forward-looking statements are reasonable at this time but no assurance can be given that these factors, expectations and assumptions will prove to be correct.

 

These statements are subject to risks, uncertainties and other factors that could cause actual results or outcomes to differ materially from those contemplated by the forward-looking statements, including, among others: Gran Tierra Energy’s operations are located in South America, and unexpected problems can arise due to guerilla activity, technical difficulties and operational difficulties which impact its testing and drilling operations and the production, transport or sale of its products; geographic, political and weather conditions can impact testing and drilling operations and the production, transport or sale of its products; and the risk that the current global economic and credit crisis may impact oil prices and oil consumption more than Gran Tierra Energy currently predicts, which could cause Gran Tierra Energy to modify its exploration activities. Although the current capital spending program of Gran Tierra Energy is based upon the current expectations of the management of Gran Tierra Energy, there may be circumstances where, for unforeseen reasons a reallocation of funds may be necessary as may be determined at the discretion of Gran Tierra Energy and there can be no assurance as at the date of this press release as to how those funds may be reallocated. Should any one of a number of issues arise, Gran Tierra Energy may find it necessary to alter its current business strategy and/or capital spending program. Accordingly, readers should not place undue reliance on the forward-looking statements contained herein. Further information on potential factors that could affect Gran Tierra Energy are included in risks detailed from time to time in Gran Tierra Energy’s Securities and Exchange Commission filings, including, without limitation, under the caption “Risk Factors” in Gran Tierra Energy’s Annual Report on Form 10-K filed February 27, 2012.These filings are available on a Web site maintained by the Securities and Exchange Commission at http://www.sec.gov and on SEDAR at www.sedar.com.  The forward-looking statements contained herein are expressly qualified in their entirety by this cautionary statement. The forward-looking statements included in this press release are made as of the date of this press release and Gran Tierra Energy disclaims any intention or obligation to update or revise any forward-looking statements, whether as a result of new information, future events or otherwise, except as expressly required by applicable securities legislation.

 

  

Contact Information

 

For media and investor inquiries please contact Jason Crumley, Director, Investor Relations at 403-265-3221, 403-218-2839, info@grantierra.com.

 

Basis of Presentation of Financial Results:

 

Gran Tierra Energy’s financial results are reported in United States dollars and prepared in accordance with generally accepted accounting principles in the United States. 

  

		Three Months Ended December 31,								Year Ended December 31,
		2011				2010				2011				2010
REVENUE AND OTHER INCOME
Oil and natural gas sales		$	161,407			$	112,527			$	596,191			$	373,286
Interest			328				140				1,216				1,174
			161,735				112,667				597,407				374,460
EXPENSES
Operating			25,214				20,418				86,497				59,446
Depletion, depreciation, accretion, and impairment			71,061				56,335				231,235				163,573
General and administrative			14,025				12,393				60,389				40,241
Equity tax			-				-				8,271				-
Financial instruments gain			-				-				(1,522	)			(44	)
Gain on acquisition			-				-				(21,699	)			-
Foreign exchange (gain) loss			(3,784	)			(16,902	)			(11	)			16,838
			106,516				72,244				363,160				280,054
INCOME BEFORE INCOME TAXES			55,219				40,423				234,247				94,406
Income tax expense			(22,667	)			(27,305	)			(107,330	)			(57,234	)
NET INCOME  AND COMPREHENSIVE INCOME			32,552				13,118				126,917				37,172
RETAINED EARNINGS, BEGINNING OF PERIOD			152,462				44,979				58,097				20,925
RETAINED EARNINGS, END OF PERIOD		$	185,014			$	58,097			$	185,014			$	58,097
NET INCOME PER SHARE — BASIC		$	0.12			$	0.05			$	0.46			$	0.15
NET INCOME PER SHARE — DILUTED		$	0.11			$	0.04			$	0.45			$	0.14
WEIGHTED AVERAGE SHARES OUTSTANDING - BASIC			277,897,512				257,286,475				273,491,564				253,697,076
WEIGHTED AVERAGE SHARES OUTSTANDING - DILUTED			287,547,237				268,150,493				281,287,002				264,304,831

 

 

		As at December 31,
		2011				2010
ASSETS
Current Assets
Cash and cash equivalents		$	351,685			$	355,428
Restricted cash			1,655				250
Accounts receivable			69,362				43,035
Inventory			7,116				5,669
Taxes receivable			21,485				6,974
Prepaids			3,597				1,940
Deferred tax assets			3,029				4,852
Total Current Assets			457,929				418,148
Oil and Gas Properties (using the full cost method of accounting)
Proved			618,982				442,404
Unproved			417,868				278,753
Total Oil and Gas Properties			1,036,850				721,157
Other capital assets			7,992				5,867
Total Property, Plant and Equipment			1,044,842				727,024
Other Long Term Assets
Restricted cash			13,227				1,190
Deferred tax assets			4,747				-
Other long term assets			3,454				311
Goodwill			102,581				102,581
Total Other Long Term Assets			124,009				104,082
Total Assets		$	1,626,780			$	1,249,254
LIABILITIES AND SHAREHOLDERS’ EQUITY
Current Liabilities
Accounts payable		$	82,189			$	76,023
Accrued liabilities			66,832				32,120
Taxes payable			95,482				43,832
Asset retirement obligation			326				338
Total Current Liabilities			244,829				152,313
Long Term Liabilities
Deferred tax liability			186,799				204,570
Equity tax payable			6,484				-
Asset retirement obligation			12,343				4,469
Other long term liabilities			2,007				1,036
Total Long Term Liabilities			207,633				210,075
Shareholders’ Equity
Common shares			7,510				4,797
(262,304,249 and 240,440,830 common shares and 16,323,819 and 17,681,123 exchangeable shares, par value $0.001 per share, issued and outstanding as at December 31, 2011 and 2010 respectively)
Additional paid in capital			980,014				821,781
Warrants			1,780				2,191
Retained earnings			185,014				58,097
Total Shareholders’ Equity			1,174,318				886,866
Total Liabilities and Shareholders’ Equity		$	1,626,780			$	1,249,254

 

 

 

		Three Months Ended December 31								Year Ended December 31
		2011				2010				2011				2010
Operating Activities
Net income		$	32,552			$	13,118			$	126,917			$	37,172
Adjustments to reconcile net income to net cash provided by operating activities:
Depletion, depreciation and accretion and impairment			71,061				56,335				231,235				163,573
Deferred taxes			(13,734	)			7,936				(29,222	)			(20,090	)
Stock based compensation			3,384				2,601				12,767				8,025
Gain on financial instruments			-				-				(1,354	)			(44	)
Unrealized foreign exchange (gain) loss			(1,831	)			(12,350	)			(1,695	)			14,786
Settlement of asset retirement obligations			(36	)			(23	)			(345	)			(286	)
Equity taxes			(999	)			-				2,442				-
Gain on acquisition			-				-				(21,699	)			-
Net changes in non-cash working capital			-				-
Accounts receivable			74,387				29,872				(15,627	)			(5,323	)
Inventory			(552	)			(1,222	)			(548	)			(1,221	)
Prepaids			(1,545	)			(130	)			(1,321	)			(120	)
Accounts payable and accrued liabilities			27,905				5,190				19,918				(3,212	)
Taxes receivable and payable			25,764				1,067				35,422				10,522
Net cash provided by operating activities			216,356				102,394				356,890				203,782
Investing Activities
Restricted cash			(10,457	)			(304	)			(10,197	)			352
Oil and gas property expenditures			(79,924	)			(63,345	)			(333,194	)			(152,299	)
Proceeds from disposition of oil and gas property			-				6,386				4,450				7,986
Cash acquired on acquisition			-				-				7,747				-
Proceeds on sale of asset backed commercial paper			-				-				22,679				-
Long term assets and liabilities			(3,201	)			8				(3,138	)			36
Net cash used in investing activities			(93,582	)			(57,255	)			(311,653	)			(143,925	)
Financing Activities
Settlement of bank debt			-				-				(54,103	)			-
Proceeds from issuance of common stock			2,541				1,893				5,123				24,785
Net cash (used in) provided by financing activities			2,541				1,893				(48,980	)			24,785
Net increase (decrease) in cash and cash equivalents			125,315				47,032				(3,743	)			84,642
Cash and cash equivalents, beginning of period			226,370				308,396				355,428				270,786
Cash and cash equivalents, end of period		$	351,685			$	355,428			$	351,685			$	355,428
Cash		$	172,645			$	272,151			$	172,645			$	272,151
Term deposits			179,040				83,277				179,040				83,277
Cash and cash equivalents, end of period		$	351,685			$	355,428			$	351,685			$	355,428