Form 10-Q
Table of Contents

 

 

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

 

 

Form 10-Q

 

 

QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(D)

OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended June 30, 2012

Commission file number: 000-30586

 

 

 

LOGO

Ivanhoe Energy Inc.

(Exact name of registrant as specified in its charter)

 

 

 

Yukon, Canada   98-0372413
(State or other jurisdiction of   (IRS Employer
incorporation or organization)   Identification No.)

654-999 Canada Place

Vancouver, BC, Canada V6C 3E1

(604) 688-8323

(Address and telephone number of the registrant’s principal executive offices)

 

 

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.    x  Yes     ¨  No

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).    ¨  Yes    ¨  No

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

 

Large accelerated filer   ¨    Accelerated filer   x
Non-accelerated filer   ¨      Smaller reporting company   ¨

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

As at July 31, 2012, Ivanhoe Energy Inc. had 344,139,428 Common Shares outstanding with no par value.

 

 

 


Table of Contents

TABLE OF CONTENTS

 

PART I

  

ITEM 1: Financial Statements

  

Unaudited Condensed Consolidated Statements of Financial Position

     3   

Unaudited Condensed Consolidated Statements of Loss and Comprehensive Loss

     4   

Unaudited Condensed Consolidated Statements of Changes in Equity

     5   

Unaudited Condensed Consolidated Statements of Cash Flows

     6   

Notes to the Unaudited Condensed Consolidated Financial Statements

     7   

ITEM 2: Management’s Discussion and Analysis of Financial Condition and Results of Operations

     20   

ITEM 3. Quantitative and Qualitative Disclosures About Market Risk

     28   

ITEM 4: Controls and Procedures

     28   
PART II   

ITEM 1: Legal Proceedings

     29   

ITEM 1A: Risk Factors

     29   

ITEM 6: Exhibits

     30   

 

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Table of Contents

PART I FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

IVANHOE ENERGY INC.

Condensed Consolidated Statements of Financial Position

(Unaudited)

 

(US$000s)

   Note      June 30,
2012
    December 31,
2011
 

Assets

       

Current Assets

       

Cash and cash equivalents

     3         27,416        16,890   

Restricted cash

     4         20,500        20,500   

Accounts receivable

        5,377        7,859   

Note receivable

        225        227   

Prepaid and other

        1,282        1,411   

Assets held for sale

     5         52,660        41,902   
     

 

 

   

 

 

 
        107,460        88,789   

Intangible

     6         295,723        273,986   

Property, plant and equipment

     7         49,002        46,979   

Long term receivables

        5,295        3,956   
     

 

 

   

 

 

 
        457,480        413,710   
     

 

 

   

 

 

 

Liabilities and Shareholders’ Equity

       

Current Liabilities

       

Accounts payable and accrued liabilities

        34,181        15,548   

Debt

     8         38,348        —     

Derivative instruments

     9         —          183   

Income taxes

        947        641   
     

 

 

   

 

 

 
        73,476        16,372   

Long term debt

     8         62,235        61,892   

Long term derivative instruments

     9, 10         60        1,617   

Long term provisions

        2,727        1,919   

Deferred income taxes

        18,041        17,773   
     

 

 

   

 

 

 
        156,539        99,573   
     

 

 

   

 

 

 

Shareholders’ Equity

       

Share capital

     12         586,108        586,108   

Contributed surplus

     13         28,693        26,524   

Accumulated deficit

        (313,860     (298,495
     

 

 

   

 

 

 
        300,941        314,137   
     

 

 

   

 

 

 
        457,480        413,710   
     

 

 

   

 

 

 

Nature of operations and going concern

     1        

(See accompanying Notes to the Unaudited Condensed Consolidated Financial Statements)

 

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IVANHOE ENERGY INC.

Condensed Consolidated Statements of Loss and Comprehensive Loss

(Unaudited)

 

           

Three Months Ended

June 30,

   

Six Months Ended

June 30,

 

(US$000s, except share and per share amounts)

   Note      2012     2011     2012     2011  

Revenue

           

Oil

        11,292        9,389        19,200        17,508   

Interest

        5        143        11        210   
     

 

 

   

 

 

   

 

 

   

 

 

 
        11,297        9,532        19,211        17,718   
     

 

 

   

 

 

   

 

 

   

 

 

 

Expenses and other

           

Operating

     15         4,846        5,339        9,494        9,862   

Exploration and evaluation

     6         152        —          152        —     

General and administrative

        10,400        11,744        20,887        25,161   

Depletion and depreciation

     7         2,401        1,891        4,237        3,722   

Foreign currency exchange gain

        (1,760     (238     (794     (463

Derivative instruments gain

     9         (1,262     (6,071     (1,732     (7,200

Finance

        470        359        586        367   

Other expenses

     8         —          —          309        —     
     

 

 

   

 

 

   

 

 

   

 

 

 
        15,247        13,024        33,139        31,449   
     

 

 

   

 

 

   

 

 

   

 

 

 

Loss before income taxes

        (3,950     (3,492     (13,928     (13,731

Recovery of (provision for) income taxes

           

Current

        (821     (477     (1,169     (799

Deferred

        68        (142     (268     (707
     

 

 

   

 

 

   

 

 

   

 

 

 
        (753     (619     (1,437     (1,506
     

 

 

   

 

 

   

 

 

   

 

 

 

Net loss and comprehensive loss

        (4,703     (4,111     (15,365     (15,237
     

 

 

   

 

 

   

 

 

   

 

 

 

Net loss per common share, basic and diluted

        (0.01     (0.01     (0.04     (0.04
     

 

 

   

 

 

   

 

 

   

 

 

 

Weighted average number of common shares

           

Basic and diluted (000s)

        344,139        338,432        344,139        341,197   
     

 

 

   

 

 

   

 

 

   

 

 

 

(See accompanying Notes to the Unaudited Condensed Consolidated Financial Statements)

 

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Table of Contents

IVANHOE ENERGY INC.

Condensed Consolidated Statements of Changes in Equity

(Unaudited)

 

            Share Capital                     

(US$000s, except share amounts)

   Note      Shares
(000s)
     Amount      Contributed
Surplus
    Accumulated
Deficit
    Total  

Balance January 1, 2011

        334,365         550,562         23,141        (273,219     300,484   

Net loss and comprehensive loss

        —           —           —          (15,237     (15,237

Exercise of stock options

        984         4,164         (2,231     —          1,933   

Exercise of purchase warrants

        8,621         31,047         —          —          31,047   

Share-based compensation expense

     13         —           —           3,235        —          3,235   
     

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

Balance June 30, 2011

        343,970         585,773         24,145        (288,456     321,462   
     

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 
            Share Capital                     

(US$000s, except share amounts)

   Note      Shares
(000s)
     Amount      Contributed
Surplus
    Accumulated
Deficit
    Total  

Balance January 1, 2012

        344,139         586,108         26,524        (298,495     314,137   

Net loss and comprehensive loss

              —          (15,365     (15,365

Funding of equity-settled share-based awards

        —           —           (54     —          (54

Share-based compensation expense

     13         —           —           2,223        —          2,223   
     

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

Balance June 30, 2012

        344,139         586,108         28,693        (313,860     300,941   
     

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

(See accompanying Notes to the Unaudited Condensed Consolidated Financial Statements)

 

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IVANHOE ENERGY INC.

Condensed Consolidated Statements of Cash Flows

(Unaudited)

 

            Three Months Ended
June 30,
    Six Months Ended
June 30,
 

(US$000s)

   Note      2012     2011     2012     2011  

Operating Activities

           

Net loss

        (4,703     (4,111     (15,365     (15,237

Adjustments to reconcile net loss to cash from operating activities

           

Depletion and depreciation

     7         2,401        1,891        4,237        3,722   

Exploration and evaluation expense

     6         152        —          152        —     

Share-based compensation expense

     13         1,003        1,471        2,239        3,247   

Unrealized foreign currency exchange loss (gain)

        (1,669     (1,553     (620     (1,780

Unrealized derivative instruments gain

     9         (1,262     (6,071     (1,732     (7,200

Current income tax expense

        821        477        1,169        799   

Deferred income tax expense

        (68     142        268        707   

Finance expense

        470        359        586        367   

Finance costs

        —          269        —          269   

Other expenses

     8         —          —          309        —     

Other

        (2     (106     (1     (12

Current income tax paid

        (381     (267     (864     (324

Interest paid

        (302     —          (302     —     

Share-based payments

        (110     —          (166     —     

Changes in non-cash working capital items

     16         (534     1,044        (986     1,978   
     

 

 

   

 

 

   

 

 

   

 

 

 

Net cash used in operating activities

        (4,184     (6,455     (11,076     (13,464
     

 

 

   

 

 

   

 

 

   

 

 

 

Investing Activities

           

Intangible expenditures

        (19,509     (13,906     (28,050     (23,772

Property, plant and equipment expenditures

        (5,110     (3,514     (5,494     (7,463

Long term receivables

        (964     (316     (1,338     (463

Interest paid

        (2,553     15        (2,553     (1,003

Changes in non-cash working capital items

     16         17,538        1,082        21,673        4,578   
     

 

 

   

 

 

   

 

 

   

 

 

 

Net cash used in investing activities

        (10,598     (16,639     (15,762     (28,123
     

 

 

   

 

 

   

 

 

   

 

 

 

Financing Activities

           

Debt proceeds, net of transaction costs

     8         —          72,914        37,282        72,914   

Proceeds from exercise of options and warrants

        —          59        —          29,873   

Changes in non-cash working capital items

     16         —          (28     —          (47
     

 

 

   

 

 

   

 

 

   

 

 

 

Net cash provided by financing activities

        —          72,945        37,282        102,740   
     

 

 

   

 

 

   

 

 

   

 

 

 

Foreign exchange gain on cash and cash equivalents held in a foreign currency

        (62     2,659        82        3,838   
     

 

 

   

 

 

   

 

 

   

 

 

 

(Decrease) increase in cash and cash equivalents, for the period

        (14,844     52,510        10,526        64,991   

Cash and cash equivalents, beginning of period

        42,260        80,798        16,890        68,317   
     

 

 

   

 

 

   

 

 

   

 

 

 

Cash and cash equivalents, end of period

        27,416        133,308        27,416        133,308   
     

 

 

   

 

 

   

 

 

   

 

 

 

(See accompanying Notes to the Unaudited Condensed Consolidated Financial Statements)

 

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Table of Contents

IVANHOE ENERGY INC.

Notes to the Unaudited Condensed Consolidated Financial Statements

(tabular amounts in US$000s, except share and per share amounts)

1. NATURE OF OPERATIONS AND GOING CONCERN

Ivanhoe Energy Inc. (the “Company” or “Ivanhoe”) is a publicly listed company incorporated in Canada, with limited liability under the legislation of the Yukon. Ivanhoe’s common shares are listed on the Toronto Stock Exchange (“TSX”) and the NASDAQ Stock Market (“NASDAQ”). The head office and principal address of the Company are located at 999 Canada Place, Suite 654, Vancouver, British Columbia, Canada, V6C 3E1. The registered and records office of the Company is located at 300-204 Black Street, Whitehorse, Yukon, Canada, Y1A 2M9.

Ivanhoe is an independent international heavy oil development and production company focused on pursuing long term growth in its reserves and production. Ivanhoe plans to utilize advanced technologies, such as its HTL™ technology, that are designed to improve recovery of heavy oil resources. In addition, the Company seeks to expand its reserve base and production through conventional exploration and production of oil and gas.

The June 30, 2012 unaudited condensed consolidated financial statements (“Financial Statements”) have been prepared using International Financial Reporting Standards (“IFRS”) as issued by the International Accounting Standards Board (“IASB”), applicable to a going concern, which contemplates the realization of assets and settlement of liabilities in the normal course of business as they become due and assumes that Ivanhoe will be able to meet its obligations and continue operations for at least its next fiscal year. Realization values may be substantially different from carrying values as shown and these Financial Statements do not give effect to adjustments that may be necessary to the carrying values and classification of assets and liabilities should the Company be unable to continue as a going concern. Such adjustments could be material.

At June 30, 2012, Ivanhoe had an accumulated deficit of $313.9 million and working capital deficit of $18.7 million, excluding assets held for sale. In the six months ended June 30, 2012, cash used in operating activities was $11.1 million and the Company expects to incur further losses in the development of its business. Continuing as a going concern is dependent upon attaining future profitable operations to repay liabilities arising in the normal course of operations and accessing additional capital to develop the Company’s properties. Ivanhoe intends to finance its future funding requirements through a combination of strategic investors and/or public and private debt and equity markets, either at a parent company level or at the project level, and through the sale of interests in existing oil and gas properties. There is no assurance that the Company will be able to obtain such financing, or obtain it on favorable terms. Without access to additional financing or other cash generating activities in 2012, there is material uncertainty that casts substantial doubt that the Company will be able to continue as a going concern.

The June 30, 2012 Financial Statements were approved by the Board of Directors and authorized for issue on July 27, 2012.

The Financial Statements are presented in US dollars and all values are rounded to the nearest thousand dollars except where otherwise indicated.

2. BASIS OF PRESENTATION

2.1 Statement of Compliance

The Financial Statements have been prepared in accordance with IAS 34, “Interim Financial Reporting” (“IAS 34”), using accounting policies consistent with IFRS as issued by the IASB. The Financial Statements are not subject to qualification relating to the application of IFRS as issued by the IASB.

The Financial Statements should be read in conjunction with the Company’s annual financial statements for the year ended December 31, 2011 prepared in accordance with IFRS. The same accounting policies, presentation and methods of computation have been followed in these Financial Statements as were applied in the Company’s first annual IFRS consolidated financial statements for the year ended December 31, 2011.

2.2 Basis of Presentation

The Financial Statements have been prepared on an historical cost basis, except derivative instruments, which are measured at fair value.

 

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2.3 Standards and Interpretations Issued But Not Yet Adopted

The Company has reviewed new and revised accounting pronouncements listed below, that have been issued, but are not yet effective. The Company has not yet evaluated the impact of these changes on its financial statements.

i. IFRS 9 Financial Instruments (“IFRS 9”)

IFRS 9 was issued in November 2009 and is intended to replace IAS 39, “Financial Instruments: Recognition and Measurement” (“IAS 39”) in phases. IFRS 9 uses a single approach to determine whether a financial asset is measured at amortized cost or fair value, as opposed to the multiple rules in IAS 39. The approach is based on how an entity manages its financial instruments given its business model and the contractual cash flow characteristics of the financial assets. The standard also requires a single impairment method to be used, replacing the multiple impairment methods in IAS 39. IFRS 9 is effective for reporting periods beginning on or after January 1, 2015.

ii. IFRS 10 Consolidated Financial Statements (“IFRS 10”)

IFRS 10 was issued in May 2011 and sets a single basis for consolidation, that being control of an entity. IFRS 10 replaces portions of IAS 27, “Consolidated and Separate Financial Statements” and Standing Interpretations Committee 12, “Special Purpose Entities” that provide a single model on how entities should prepare consolidated financial statements. This standard is effective for reporting periods on or after January 1, 2013, with earlier adoption permitted.

iii. IFRS 11 Joint Arrangements (“IFRS 11”)

IFRS 11, issued in May 2011, establishes principles for financial reporting by entities involved in a joint arrangement and distinguishes between joint operations and joint ventures. IFRS 11 supersedes the current IAS 31, “Interests in Joint Ventures” and Standing Interpretations Committee 13, “Jointly Controlled Entities-Non Monetary Contributions by Venturers” and is effective for reporting periods beginning on or after January 1, 2013, with earlier adoption permitted.

iv. IFRS 12 Disclosure of Interests in Other Entities (“IFRS 12”)

IFRS 12, issued in May 2011, establishes a single set of disclosure objectives, and requires minimum disclosures designed to meet those objectives, regarding interests in subsidiaries, joint arrangements, associates or unconsolidated structured entities. IFRS 12 is intended to combine the disclosure requirements on interests in other entities currently located throughout different standards. This standard is effective for reporting periods on or after January 1, 2013, with earlier adoption permitted.

v. IFRS 13 Fair Value Measurements (“IFRS 13”)

IFRS 13, issued in May 2011, defines fair value, sets out a single IFRS framework for measuring fair value and requires disclosures about fair value measurements. IFRS 13 applies to IFRS that require or permit fair value measurements or related disclosures, except in specified circumstances. IFRS 13 is to be applied for reporting periods beginning on or after January 1, 2013, with earlier adoption permitted.

vi. IAS 28 Investments in Associates and Joint Ventures (“IAS 28”)

IAS 28 was amended in 2011 and prescribes the accounting for investments in associates and sets out the requirements for the application of the equity method when accounting for investments in associates and joint ventures. IAS 28 is effective for reporting periods beginning on or after January 1, 2013, with earlier adoption permitted.

There are no other standards or interpretations issued, but not yet adopted, that are anticipated to have a material effect on the reported loss or net assets of the Company.

3. CASH AND CASH EQUIVALENTS

 

     June 30,
2012
     December 31,
2011
 

Cash at banks and on hand

     27,416         16,867   

Restricted cash

     —           23   
  

 

 

    

 

 

 
     27,416         16,890   
  

 

 

    

 

 

 

 

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4. RESTRICTED CASH

 

     June 30,
2012
     December 31,
2011
 

Ecuador performance bond

     500         500   

Zitong performance bond

     20,000         20,000   
  

 

 

    

 

 

 
     20,500         20,500   
  

 

 

    

 

 

 

In December 2011, Ivanhoe was required to post a $20.0 million performance bond as part of the completion and signing of a supplementary agreement to the Contract for Exploration, Development and Production in Zitong Block, Sichaun Basin with China National Petroleum Corporation (“CNPC”) for the Zitong block.

5. ASSETS HELD FOR SALE

Sunwing Zitong Energy (“SZE”), a wholly owned subsidiary of the Company, signed a binding Memorandum of Understanding to assign 100% of its participating interest in the Zitong Production Sharing Contract (“PSC”) to Shell China Exploration and Production Company Limited (“Shell”). The transaction is subject to government approvals and other prescribed conditions. There is no assurance that this transaction will close on the terms presently contemplated or at all.

In exchange for SZE’s interest in the Zitong block, Ivanhoe will receive a cash payment of up to $85.0 million as reimbursement for past qualified and recoverable costs incurred. In addition, Ivanhoe will receive a further cash payment contingent on the timing of the receipt of full government approvals and third-party consents and waivers for the transaction. If the transaction closes after June 30, 2012, but on or before September 30, 2012, the Company will receive an additional $50.0 million. If the transaction closes after September 30, 2012, but on or before December 31, 2012, the Company will receive an additional $20.0 million. Failure to reach completion of the transaction prior to December 31, 2012 will give either party the right to terminate the transaction.

Should SZE receive government approval for the transaction, Shell will become liable for the performance bond posted in 2011, resulting in a release of restricted cash back to the Company.

The carrying value of the Zitong asset, which is comprised of exploration and evaluation (“E&E”) expenditures, was $52.7 million at June 30, 2012 (December 31, 2011 – $41.9 million); the property was previously reported in the Asia segment.

6. INTANGIBLE ASSETS

 

     Exploration and Evaluation Assets               
     Asia     Canada     Latin
America
    Total     HTL™
Technology
     Total Intangible
Assets
 

Cost

             

Balance January 1, 2011

     38,135        123,755        19,525        181,415        92,153         273,568   

Additions

     23,094        9,697        12,303        45,094        —           45,094   

Exploration and evaluation expense

     (2,124     —          (650     (2,774     —           (2,774

Assets reclassified as held for sale

     (41,902     —          —          (41,902     —           (41,902
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

    

 

 

 

Balance December 31, 2011

     17,203        133,452        31,178        181,833        92,153         273,986   

Additions

     229        4,877        16,783        21,889        —           21,889   

Exploration and evaluation expense

     —          (152     —          (152     —           (152
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

    

 

 

 

Balance June 30, 2012

     17,432        138,177        47,961        203,570        92,153         295,723   
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

    

 

 

 

In the six months ended June 30, 2012, $0.9 million (year ended December 31, 2011 – $2.1 million) of employee benefits directly attributable to E&E assets were capitalized. In addition, in the six months ended June 30, 2012, nil (year ended December 31, 2011 – $0.3 million) related to share-based compensation costs were capitalized to E&E assets.

Amortization of the HTL™ technology has not commenced and its carrying value had not been impaired since it was acquired in 2005.

 

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7. PROPERTY, PLANT AND EQUIPMENT

 

     Oil and Gas Property and Equipment      Other
Assets
    Total
PP&E
 
     Asia      Canada      Latin
America
     Total       

Cost

                

Balance January 1, 2011

     35,939         —           —           35,939         13,009        48,948   

Additions

     12,923         —           —           12,923         1,471        14,394   

Disposals

     —           —           —           —           (3 )     (3
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

   

 

 

 

Balance December 31, 2011

     48,862         —           —           48,862         14,477        63,339   

Additions

     6,144         —           —           6,144         116        6,260   
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

   

 

 

 

Balance June 30, 2012

     55,006         —           —           55,006         14,593        69,599   
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

   

 

 

 

Accumulated Depletion and Depreciation

                

Balance January 1, 2011

     6,196         —           —           6,196         2,134        8,330   

Depletion and depreciation

     6,899         —           —           6,899         1,132        8,031   

Disposals

     —           —           —           —           (1     (1
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

   

 

 

 

Balance December 31, 2011

     13,095         —           —           13,095         3,265        16,360   

Depletion and depreciation

     3,676         —           —           3,676         561        4,237   
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

   

 

 

 

Balance June 30, 2012

     16,771         —           —           16,771         3,826        20,597   
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

   

 

 

 

Net Book Value

                

As at December 31, 2011

     35,767         —           —           35,767         11,212        46,979   

As at June 30, 2012

     38,235         —           —           38,235         10,767        49,002   

Oil and Gas Property and Equipment

In the six months ended June 30, 2012, $0.1 million (year ended December 31, 2011 – $0.1 million) of employee benefits directly attributable to property, plant and equipment (“PP&E”) were capitalized.

Other Assets

Other assets include the Company’s Feedstock Test Facility (“FTF”) at the Southwest Research Institute in San Antonio, Texas, and general furniture and fixtures.

Security

Should Ivanhoe receive government and other approvals necessary to develop the northern border of one of the Company’s oil sands leases in the Athabasca region of Canada (“Tamarack”), the Company will make a cash payment to Talisman Energy Canada (“Talisman”) of up to Cdn$15.0 million, as a contingent, final payment for the 2008 acquisition of the oil sands leases (Note 11). The contingent payment is secured by a first fixed charge and security interest in favor of Talisman, including over the oil sands leases, and a general security interest in all of the Company’s present and after acquired property, other than equity interests in the Company’s subsidiaries (through which it holds assets in China, Mongolia and Ecuador and the HTL™ technology). Talisman has agreed to subordinate its security interest in the Tamarack oil sands leases and related assets to UBS Securities LLC and certain of its affiliates (“UBS”) until the loan provided by UBS to the Company through a credit agreement signed in March 2012 (Note 8) is repaid.

8. DEBT

Interest incurred for all outstanding debt was recorded as follows:

 

     Three months ended
June 30,
     Six months ended
June 30,
 
     2012      2011      2012      2011  

Interest expense

     475         352         572         352   

Capitalized to E&E

     2,010         677         3,723         1,374   

Capitalized to PP&E

     463         —           729         —     
  

 

 

    

 

 

    

 

 

    

 

 

 

Total interest incurred

     2,948         1,029         5,024         1,726   
  

 

 

    

 

 

    

 

 

    

 

 

 

 

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8.1 Short Term Debt

In March 2012, the Company signed a credit agreement with UBS providing for a $50.0 million loan from UBS (“UBS Loan”). The UBS Loan includes an initial draw of $30.0 million and Ivanhoe may elect to draw an additional $20.0 million of principal. Subsequent to quarter end, the Company elected to draw an additional $20.0 million of principal in July 2012. Borrowed amounts incur interest at a per annum rate equal to one month Libor plus 10% for the first six months of the UBS Loan which escalates by 1% per month thereafter; interest is payable monthly. The UBS Loan matures on March 23, 2013 and is secured by the Tamarack oil sands leases and related assets, and by a charge over the shares of three of the Company’s subsidiaries: Sunwing Holding Corporation, Sunwing Energy Ltd. and Sunwing Zitong Energy Ltd.

8.2 Convertible Short Term Debt

Ivanhoe entered into an unsecured loan agreement on December 30, 2011 with Ivanhoe Capital Finance Ltd. (“ICFL”), a company wholly owned by Robert Friedland, for a $10.0 million loan (“ICFL Loan”). The funds were advanced to the Company on January 3, 2012. The outstanding balance is subordinate in repayment to all amounts owing under the UBS Loan. Interest on the loan is 10% per annum, calculated monthly and due upon maturity.

On March 14, 2012, the ICFL Loan agreement was amended to provide that, at ICFL’s option, the outstanding principal may be converted into 10,484,375 common shares of the Company, at a price of Cdn$0.96 per common share, and the maturity date was extended to March 31, 2013. The debt component is carried at amortized cost and, on the date of amendment, the equity option was valued at nil using the residual method. The amendment was treated as an extinguishment of the original loan with recognition of the amended loan resulting in the remaining deferred financing costs of $0.3 million being expensed in the first quarter of 2012.

8.3 Convertible Debentures

On June 9, 2011, the Company issued Cdn$73.3 million in 5.75% convertible unsecured subordinated debentures at a price of Cdn$1,000 per debenture (“Convertible Debentures”). Cdn$50.0 million of the Convertible Debentures were issued in a public offering. The remaining Cdn$23.3 million were issued in a private placement on the same terms as the public offering.

The Convertible Debentures mature on June 30, 2016, pay interest semi-annually on June 30 and December 31 and are convertible at a price of Cdn$3.36 per share. They are redeemable after June 30, 2014 at Ivanhoe’s option with the redemption price being settled using either cash or common shares.

The Canadian dollar denominated debt is considered an embedded derivative since the functional currency of the Company is the US dollar and, as such, the option was bifurcated and recognized at fair value as a long term derivative liability (Note 10) with changes in value recorded each period in the statement of loss. The carrying amount of the debt component of the Convertible Debentures at June 30, 2012 was $62.2 million (December 31, 2011 – $61.9 million). The June 30, 2012 carrying value of the unamortized bifurcated derivative and transaction costs was $9.2 million.

9. FINANCIAL INSTRUMENTS

9.1 Fair Value of Financial Instruments Measured at Amortized Cost

Except as detailed below, the fair value of the Company’s financial instruments recognized at amortized cost approximates their carrying value due to the short term maturity of these instruments.

 

     June 30,
2012
     December 31,
2011
 

Short Term Debt

     

Carrying amount

     38,348         —     

Fair value

     39,340         —     

Long Term Debt

     

Carrying amount

     62,235         61,892   

Fair value

     49,323         51,901   

The fair value of the liability component of the Convertible Debentures was estimated using the closing price of the publicly traded debentures at June 30, 2012.

 

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9.2 Financial Instruments Measured at Fair Value Through Profit and Loss

The Company classifies its financial instruments according to the fair value hierarchy outlined in IFRS 7, “Financial Instruments: Disclosures,” as described below:

 

  •    Level 1 –     using quoted prices in active markets for identical assets or liabilities.

 

  •    Level 2 –     using inputs for the asset or liability, other than quoted prices, that are observable either directly (i.e. as prices) or indirectly (i.e. derived from prices).

 

  •    Level 3 –     using inputs for the asset or liability that are not based on observable market data, such as prices based on internal models or other valuation methods.

The following table presents the Company’s derivative instruments measured at fair value through profit or loss (“FVTPL”):

 

     Level 1     Level 2     Level 3        
     2006
Purchase
Warrants
    2009 & 2010
Purchase
Warrants
    2008
Convertible
Component
of Debt
    2011
Convertible
Component
of Debentures
    Subsidiary
Option
    Total
Fair
Value
 

Balance January 1, 2011

     5,615        1,616        1,216        —          —          8,447   

Issuance of convertible debentures

     —          —          —          9,852        —          9,852   

Exercise of options

     (2     (3,107     —          —          —          (3,109

Derivative (gains) losses through profit and loss

     (3,267     2,968        (1,216     (7,810     183        (9,142

Expiration of purchase warrants through profit and loss

     (2,346     (1,477     —          —          —          (3,823

Foreign exchange gains

     —          —          —          (425     —          (425
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Balance December 31, 2011

     —          —          —          1,617        183        1,800   

Derivative gains through profit and loss

     —          —          —          (1,549            (1,549

Expiration of derivatives through profit or loss

     —          —          —          —          (183     (183

Foreign exchange gains

     —          —          —          (8     —          (8
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Balance June 30, 2012

     —          —          —          60        —          60   
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

The gain on derivative instruments of $1.7 million for the six months ended June 30, 2012 (six months ended June 30, 2011 – $7.2 million, year ended December 31, 2011 – $13.0 million) originated from the expiration and revaluation of derivative instruments measured at FVTPL.

9.3 Risks Arising from Financial Instruments

Ivanhoe is exposed in varying degrees to normal market risks inherent in the oil and gas industry, including commodity price risk, foreign currency exchange rate risk, credit risk, interest rate risk and liquidity risk. The Company recognizes these risks and manages its operations to minimize the exposure to the extent practicable. There have not been any significant changes to the Company’s exposure to risks, or processes to manage these risks as described in the Company’s 2011 Form 10-K, except as noted below:

Interest Rate Risk

As at June 30, 2012, the Company had borrowed $30.0 million under the UBS Loan. Subsequent to quarter end, the Company elected to draw an additional $20.0 million of principal in July 2012. Borrowed amounts incur interest at a rate of one month Libor plus 10% for the first six months and escalate by 1% per month thereafter. Borrowings issued at variable rates expose Ivanhoe to interest rate risk. The Company’s goal is to minimize its interest expense; however, the Company does not anticipate using hedging contracts in 2012 to manage its interest rate risk.

If the interest rate on the UBS Loan were to increase by 1%, the Company’s net loss would increase by approximately $25,000 per month. Similarly, a 1% decrease in the interest rate on the UBS Loan would decrease Ivanhoe’s net loss by approximately $25,000 per month.

 

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Table of Contents

10. DERIVATIVE INSTRUMENTS

The Company issued Cdn$73.3 million in Convertible Debentures in the second quarter of 2011. The outstanding principal amount is convertible into common shares of the Company. The fair value of the convertible component was $0.1 million at June 30, 2012, calculated with the Black-Scholes valuation method using a risk-free interest rate of 1.25%, a dividend yield of 0.0%, a weighted average volatility factor of 40% and an expected life of 4.0 years.

If the volatility used to fair value the convertible component decreased by 10%, the fair value would decrease by $0.1 million. If volatility increased by 10%, the fair value of the convertible option would increase by $0.2 million.

11. COMMITMENTS AND CONTINGENCIES

11.1 Operating Lease Arrangements

In the six months ended June 30, 2012, the Company expended $0.8 million (2011 – $0.9 million) on operating leases relating to the rental of office space, which expire between 2012 and 2017.

At June 30, 2012, future net minimum payments for operating leases were:

 

2012

     967   

2013

     1,432   

2014

     595   

2015

     401   

After 2015

     502   
  

 

 

 
     3,897   
  

 

 

 

11.2 Other

Should Ivanhoe receive government and other approvals necessary to develop the northern border of one of the Tamarack leases, the Company will make a cash payment to Talisman of up to Cdn$15.0 million, as a contingent, final payment for the 2008 purchase of the Tamarack leases.

From time to time, Ivanhoe enters into consulting agreements whereby a success fee may be payable if and when either a definitive agreement is signed or certain other contractual milestones are met. Under the agreements, the consultant may receive cash, common shares, stock options or some combination thereof. Similarly, agreements entered into by the Company may contain cancellation fees or liquidated damages provisions for early termination. These fees are not considered to be material.

The Company may provide indemnities to third parties, in the ordinary course of business, that are customary in certain commercial transactions, such as purchase and sale agreements. The terms of these indemnities will vary based upon the contract, the nature of which prevents Ivanhoe from making a reasonable estimate of the maximum potential amounts that may be required to be paid. The Company’s management is of the opinion that any resulting settlements relating to indemnities are not likely to be material.

In the ordinary course of business, the Company is subject to legal proceedings being brought against it. While the final outcome of these proceedings is uncertain, the Company believes that these proceedings, in the aggregate, are not reasonably likely to have a material effect on its financial position.

 

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12. SHAREHOLDERS’ EQUITY

12.1 Share Capital

 

Authorized  

Unlimited common shares with no par value

Unlimited preferred shares with no par value

  
Issued and Outstanding  

344,139,428 common shares (December 31, 2011 – 344,139,428)

Nil preferred shares (December 31, 2011 – nil)

See the Unaudited Condensed Consolidated Statements of Changes in Equity for the change in common shares issued in the six months ended June 30, 2012 and 2011.

12.2 Contributed Surplus

Contributed surplus at June 30, 2012 consisted solely of share-based compensation expense from equity settled awards.

13. SHARE-BASED PAYMENTS

Share-based transactions were charged to earnings, as general and administrative or operating expenses, or capitalized to E&E assets as follows:

 

    

Three months ended

June 30,

    

Six months ended

June 30,

 
     2012     2011      2012      2011  

Share-based expense related to

          

Equity settled transactions

     1,069        1,459         2,223         3,235   

Cash settled transactions

     (66     12         16         12   
  

 

 

   

 

 

    

 

 

    

 

 

 

Total share-based expense

     1,003        1,471         2,239         3,247   

Share-based payments capitalized as E&E assets

     —          335         —           335   
  

 

 

   

 

 

    

 

 

    

 

 

 

13.1 Stock Option Plan

Details of transactions under the Company’s stock option plan are as follows:

 

     June 30, 2012      December 31, 2011  
     Number of
Stock  Options
(000s)
    Weighted Average
Exercise Price
(Cdn$)
     Number of
Stock  Options
(000s)
    Weighted Average
Exercise Price
(Cdn$)
 

Outstanding, beginning of period

     15,748        2.14         16,927        2.24   

Granted

     2,783        0.96         2,924        2.06   

Exercised

     —          —           (1,687     2.44   

Expired

     (463     2.22         (710     2.90   

Forfeited

     (871     2.20         (1,706     2.46   
  

 

 

   

 

 

    

 

 

   

 

 

 

Outstanding, end of period

     17,197        1.95         15,748        2.14   
  

 

 

   

 

 

    

 

 

   

 

 

 

Exercisable, end of period

     8,949        2.13         8,231        2.13   
  

 

 

   

 

 

    

 

 

   

 

 

 

Shares authorized for issue under the option plan at June 30, 2012 were 24.1 million (December 31, 2011 – 24.1 million).

There were no stock options exercised in the six months ended June 30, 2012. The weighted average share price per option at the date of exercise for stock options exercised in the six months ended June 30, 2011 was Cdn$3.28.

 

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Table of Contents

The weighted average fair value of stock options granted from the stock option plan during the six months ended June 30, 2012 was Cdn$0.69 (2011 – Cdn$1.61) per option at the grant date using the Black-Scholes option pricing model. The weighted average assumptions used for the calculation were:

 

Six months ended June 30,

   2012     2011  

Expected life (in years)

     6.3        6.3   

Volatility (1)

     73.8     74.5

Dividend yield

     —          —     

Risk-free rate

     1.7     2.7

Estimated forfeiture rate

     7.9     6.0

 

(1) Expected volatility factor based on historical volatility of the Company’s publicly traded common shares.

 

The following table summarizes information in respect of stock options outstanding and exercisable at June 30, 2012:

 

Range of Exercise Prices (Cdn$)

   Outstanding
(000s)
     Weighted Average
Remaining
Contractual Life
(years)
     Weighted Average
Exercise Price

(Cdn$)
 

0.86 to 1.29

     3,698         6.7         0.95   

1.30 to 1.89

     3,943         1.3         1.61   

1.90 to 2.79

     8,341         4.1         2.36   

2.80 to 3.44

     1,215         4.5         3.26   
  

 

 

    

 

 

    

 

 

 
     17,197         4.0         1.95   
  

 

 

    

 

 

    

 

 

 

13.2 Restricted Share Unit Plan

The Company adopted a restricted share unit (“RSU”) plan in the second quarter of 2011 under which it may issue restricted share units to eligible employees. RSUs vest in equal increments over three years and are settled in shares or cash on the anniversary date. RSUs do not entitle the holder to exercise voting rights until they have vested and the underlying shares have been delivered to the participant.

Details of transactions under the Company’s RSU plan are as follows:

 

     June 30, 2012      December 31, 2011  
     Number of
RSUs

(000s) (1)
    Weighted
Average  Fair
Value

(Cdn$)
     Number of
RSUs

(000s) (1)
    Weighted
Average  Fair
Value

(Cdn$)
 

Outstanding, beginning of period

     937        1.53         —          —     

Granted

     2,498        0.69         1,115        1.62   

Vested

     (283     1.14         —          —     

Forfeited

     (143     1.10         (178     2.08   
  

 

 

   

 

 

    

 

 

   

 

 

 

Outstanding, end of period

     3,009        0.77         937        1.53   
  

 

 

   

 

 

    

 

 

   

 

 

 

 

(1) Includes RSUs that will be withheld on behalf of employees to satisfy statutory tax withholding requirements.

 

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Table of Contents

The weighted average fair value of RSU’s granted during the six months ended June 30, 2012 was Cdn$0.69 per RSU at the grant date using the Black-Scholes option pricing model. The weighted average assumptions used for the calculation were:

 

Six months ended June 30,

   2012     2011  

Expected life (in years)

     2.0        3.0   

Volatility (1)

     68.9     62.7

Dividend yield

     —          —     

Risk-free rate

     1.2     1.7

Estimated forfeiture rate

     20.0     6.1

 

(1) Expected volatility factor based on historical volatility of the Company’s publicly traded common shares.

The liabilities arising from the RSUs to be settled by way of cash payments and the intrinsic value of those liabilities are:

 

     June 30, 2012  

Current liabilities related to RSUs

     107   

Long term liabilities related to RSUs

     67   

Intrinsic value of vested RSUs

     164   

14. SEGMENT INFORMATION

Ivanhoe’s organizational structure reflects its various operating activities and the geographic areas in which it operates. Oil and gas operations are divided into three geographic segments: Asia, Canada and Latin America. Asian operations capture the Company’s oil production in Dagang and Daqing and exploration at Zitong in China, as well as exploration in Mongolia. The Canadian segment comprises activities from Ivanhoe’s oil sands development project at Tamarack. Latin America consists of exploration and development of Block 20 in Ecuador.

The Technology Development area captures costs incurred to develop, enhance and identify improvements in the application of the Company’s HTL™ technology. The Corporate area consists of costs that are not directly allocable to operating projects, such as executive officers, corporate financings and other general corporate activities.

The accounting policies of the segments are the same as the Company’s consolidated accounting policies. Segment results include transactions between business segments. Corporate activities undertaken on behalf of a segment are allocated at cost. Oil revenue is classified according to the geographic location of the production. Segment liabilities include intercompany balances.

 

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Table of Contents

The following tables present the Company’s segment loss, capital investments and identifiable assets and liabilities.

 

     Asia     Canada     Latin
America
    Technology
Development
    Corporate     Total  

Segment revenue (1)

            

For the three months ended June 30, 2012

     11,292        —          —          —          5        11,297   

For the three months ended June 30, 2011

     9,391        —          —          —          141        9,532   

For the six months ended June 30, 2012

     19,201        —          —          —          10        19,211   

For the six months ended June 30, 2011

     17,511        —          —          —          207        17,718   

Segment income (loss)

            

For the three months ended June 30, 2012

     1,116        (1,028     (1,600     (2,061     (1,130     (4,703

For the three months ended June 30, 2011

     461        (979     (2,160     (2,759     1,326        (4,111

For the six months ended June 30, 2012

     940        (2,456     (2,543     (4,190     (7,116     (15,365

For the six months ended June 30, 2011

     (1,711     (2,286     (3,867     (5,007     (2,366     (15,237

Segment assets (2)

            

As at June 30, 2012

     122,972        138,675        60,022        102,201        33,610        457,480   

As at December 31, 2011

     107,902        133,880        40,216        102,435        29,277        413,710   

Segment liabilities (3)

            

As at June 30, 2012

     154,750        151,779        84,210        91,778        (325,978     156,539   

As at December 31, 2011

     140,621        144,531        64,362        87,822        (337,763     99,573   

Capital investments – Intangible

            

For the three months ended June 30, 2012

     9,488        642        9,379        —          —          19,509   

For the three months ended June 30, 2011

     7,607        1,806        4,493        —          —          13,906   

For the six months ended June 30, 2012

     10,094        2,751        15,205        —          —          28,050   

For the six months ended June 30, 2011

     14,106        3,847        5,819        —          —          23,772   

Capital investments – Property, plant and equipment

            

For the three months ended June 30, 2012

     5,110        —          —          —          —          5,110   

For the three months ended June 30, 2011

     2,755        —          (5     764        —          3,514   

For the six months ended June 30, 2012

     5,419        —          —          34        41        5,494   

For the six months ended June 30, 2011

     6,301        —          58        1,104        —          7,463   

 

(1) All oil revenues in Asia are generated from the sale of oil production in China to one customer.
(2) Segment assets include investments in subsidiaries that are eliminated for consolidation under Corporate and assets classified as held for sale.
(3) Liabilities for Corporate include intercompany receivables of $454.6 million at June 30, 2012 (December 31, 2011—$428.7 million) resulting in a negative balance.

 

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Table of Contents

15. OPERATING EXPENSES

Operating expenses for the Company are comprised of the following:

 

     Three months ended
June 30,
     Six months ended
June 30,
 
     2012      2011      2012      2011  

Asia

           

Field operating

     1,547         1,692         3,283         3,315   

Windfall levy

     2,270         2,182         3,728         3,759   

Engineering support

     108         103         226         213   
  

 

 

    

 

 

    

 

 

    

 

 

 
     3,925         3,977         7,237         7,287   

Technology Development

           

FTF operating costs

     921         1,362         2,257         2,575   
  

 

 

    

 

 

    

 

 

    

 

 

 

Total operating costs

     4,846         5,339         9,494         9,862   
  

 

 

    

 

 

    

 

 

    

 

 

 

The windfall levy is imposed by China’s Ministry of Finance at the progressive rates from 20% to 40% on the portion of the monthly weighted average sales price of the crude oil lifted in China exceeding US$55.00 per barrel.

16. SUPPLEMENTAL CASH FLOW INFORMATION

Changes in Non-Cash Activities

 

     Three months ended
June 30,
    Six months ended
June 30,
 
     2012     2011     2012     2011  

Operating activities

        

Accounts receivable

     1,684        (2,022     2,475        (2,646

Note receivable

     4        2        1        33   

Prepaid and other current assets

     223        (214     167        (148

Accounts payable and accrued liabilities

     (2,445     3,278        (3,629     4,739   
  

 

 

   

 

 

   

 

 

   

 

 

 
     (534     1,044        (986     1,978   
  

 

 

   

 

 

   

 

 

   

 

 

 

Investing activities

        

Accounts receivable

     18        80        5        556   

Prepaid and other current assets

     (4     1,509        (37     2,241   

Accounts payable and accrued liabilities

     17,524        (507     21,705        1,781   
  

 

 

   

 

 

   

 

 

   

 

 

 
     17,538        1,082        21,673        4,578   
  

 

 

   

 

 

   

 

 

   

 

 

 

Financing activities

        

Accounts payable and accrued liabilities

     —          (28     —          (47
  

 

 

   

 

 

   

 

 

   

 

 

 
     17,004        2,098        20,687        6,509   
  

 

 

   

 

 

   

 

 

   

 

 

 

 

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Table of Contents

17. RELATED PARTY TRANSACTIONS

Ivanhoe is party to cost sharing agreements with other companies which are related or controlled through common directors or shareholders. Through these agreements, the Company shares office space, furnishings, equipment, air travel and communications facilities in various international locations. Ivanhoe also shares the costs of employing administrative and non-executive management personnel at these offices. These related party transactions are in the normal course of business and the Company believes them to be valued at fair market value.

The breakdown of the related party expenses for the three and six months ended June 30 is as follows:

 

          Three months ended
June 30,
     Six months ended
June 30,
 

Related Party

  

Nature of Transaction

   2012      2011      2012      2011  

Global Mining Management Corp.

   Administration      25         116         184         329   

Ivanhoe Capital Aviation Ltd.

   Aircraft      300         300         600         600   

I2MS.Net PTE Ltd.

   Information systems      47         50         94         108   

Ivanhoe Capital Services Ltd.

   Administration      104         29         176         121   

SouthGobi Resources Ltd.

   Administration      —           26         38         77   

1092155 Ontario Inc.

   HTL™ technology      12         8         24         20   

Ivanhoe Capital PTE Ltd.

   Administration      —           46         —           115   

Ivanhoe Capital Finance Ltd.

   Financing      168         —           993         —     
     

 

 

    

 

 

    

 

 

    

 

 

 
        656         575         2,109         1,370   
     

 

 

    

 

 

    

 

 

    

 

 

 

The liabilities of the Company include the following amounts due to related parties:

 

Related Party

  

Nature of Transaction

   June 30,
2012
     December 31,
2011
 

Global Mining Management Corp.

   Administration      15         52   

I2MS.Net PTE Ltd.

   Information systems      15         18   

SouthGobi Resources Ltd.

   Administration      —           13   

Ivanhoe Capital Services Ltd.

   Administration      44         93   

Ivanhoe Capital PTE Ltd.

   Administration      —           7   

Ivanhoe Capital Finance Ltd.

   Financing      10,493         —     
     

 

 

    

 

 

 
        10,567         183   
     

 

 

    

 

 

 

 

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Table of Contents

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

Forward-Looking Statements

With the exception of historical information, certain matters discussed in this Quarterly Report on Form 10-Q (“Form 10-Q”), including those within this Item 2 – Management’s Discussion and Analysis of Financial Condition and Results of Operations (“MD&A”), are forward-looking statements that involve risks and uncertainties.

Statements that contain words such as “could”, “should”, “can”, “anticipate”, “estimate”, “propose”, “plan”, “expect”, “believe”, “will”, “may” and similar expressions and statements relating to matters that are not historical facts constitute “forward-looking statements” within the meaning of the “safe harbor” provisions of the United States Private Securities Litigation Reform Act of 1995. In particular, forward-looking statements contained in this Form 10-Q include, but are not limited to statements relating to or associated with individual wells, regions or projects. Forward-looking statements include statements as to possible future crude oil prices; future production levels; future royalty and tax levels; future capital expenditures, their timing and their allocation to exploration and development activities; future earnings; future asset acquisitions or dispositions; future sources of funding for the Company’s capital programs; future debt levels; availability of future credit facilities; possible commerciality of the Company’s projects; development plans or capacity expansions; future ability to execute dispositions of assets or businesses; future business relationships with third parties; future sources of liquidity, cash flows and their uses; future drilling of new wells; ultimate recoverability of current and long-term assets; ultimate recoverability of reserves or resources; expected operating costs; the expectation of negotiating of an extension to certain of the Company’s petroleum agreements; the expectation of the Company’s ability to comply with the newly enacted safety and environmental rules; estimates on a per share basis; future foreign currency exchange rates, future expenditures and future allowances relating to environmental matters and the Company’s ability to comply therewith; dates by which certain areas will be developed, come on-stream or reach expected operating capacity; and changes in any of the foregoing.

Statements relating to “reserves” are forward-looking statements, as they involve the implied assessment, based on estimates and assumptions, that the reserves described exist in the quantities predicted or estimated and can be profitably produced in the future.

The forward-looking statements contained in this Form 10-Q are based on certain assumptions and analyses made by the Company in light of its experience and its perception of historical trends, current conditions and expected future developments as well as other factors it believes are relevant in the circumstances. By their nature, forward-looking statements involve inherent risks and uncertainties including the risk that the outcome that they predict will not be achieved. Undue reliance should not be placed on forward-looking statements as a number of important factors could cause the actual results to differ materially from the beliefs, plans, objectives, expectations and anticipations, estimates and intentions expressed in the forward-looking statements, including those set out below and those detailed in Item 1A, “Risk Factors” and Item 7A, “Quantitative and Qualitative Disclosures About Market Risk” in the Company’s Annual Report on Form 10-K for the fiscal year ended December 31, 2011 (“2011 Form 10-K”). Such factors include, but are not limited to: the Company’s history of limited revenue, losses and negative cash flow from its current exploration and development activities in Canada, Ecuador, China, Mongolia and the United States; the Company’s limited cash resources and consequent need for additional financing; the ability to raise capital as and when required, or to raise capital on acceptable terms; the timing and extent of changes in prices for oil and gas; competition for oil and gas exploration properties from larger, better financed oil and gas companies; environmental risks; title matters; drilling and operating risks; uncertainties about the estimates of reserves and the potential success of the Company’s Heavy-to-light (“HTL™”) technology; the potential success of the Company’s oil and gas properties in Canada, Ecuador, China and Mongolia; the prices of goods and services; the availability of drilling rigs and other support services; legislative and government regulations; political and economic factors in countries in which the Company operates; and unanticipated variances in the implementation of the Company's capital investment plans and strategies.

The forward-looking statements contained in this Form 10-Q are made as of the date hereof and the Company undertakes no obligation to update publicly or revise any forward-looking statements, whether as a result of new information, future events or otherwise, unless required by applicable securities laws. The forward-looking statements contained herein are expressly qualified in their entirety by this cautionary statement.

Special Note to Canadian Investors

The Company is a registrant under the Securities Exchange Act of 1934, as amended (the “Exchange Act”) and voluntarily files reports with the United States Securities and Exchange Commission (“SEC”) on Form 10-K, Form 10-Q and other forms used by registrants that are US domestic issuers. Therefore, the Company’s reserves estimates and securities regulatory disclosures generally follow SEC requirements. National Instrument 51-101 – Standards of Disclosure for Oil and Gas Activities (“NI 51-101”), adopted by the Canadian Securities Administrators (“CSA”), prescribes certain standards for the preparation, and disclosure of reserves and related information by Canadian issuers. The Company has been granted certain exemptions from NI 51-101. Please refer to the Special Note to Canadian Investors in the 2011 Form 10-K.

 

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Table of Contents

Advisories

This Form 10-Q should be read in conjunction with the Company’s June 30, 2012 unaudited condensed consolidated financial statements (the “Financial Statements”) contained herein, and the audited consolidated financial statements and Management’s Discussion and Analysis of Financial Condition and Results of Operations contained in the 2011 Form 10-K. The Financial Statements have been prepared using accounting policies consistent with International Financial Reporting Standards (“IFRS”) and in accordance with International Accounting Standard 34, Interim Financial Reporting (“IAS 34”).

As a foreign private issuer in the US, Ivanhoe is permitted to file with the SEC financial statements prepared under IFRS, as issued by the International Accounting Standards Board, without a reconciliation to US GAAP. It is possible that some of the Company’s accounting policies under IFRS could be different from US GAAP.

Non-IFRS Financial Measures

Oil revenue per barrel is calculated by dividing the Company’s oil revenue by its total production for the respective periods presented. Net operating revenue per barrel is calculated by dividing oil revenue less related operating costs by total production for the respective periods presented. Net revenue (loss) from operations per barrel is calculated by subtracting depletion from net operating revenue and dividing by total production for the respective periods presented. The Company believes oil revenue per barrel, net operating revenue per barrel and net revenue (loss) from operations per barrel are important to investors to evaluate operating results and the Company’s ability to generate cash. Each of the components used in these calculations can be reconciled directly to the unaudited condensed consolidated statements of loss and comprehensive loss. The calculations of oil revenue per barrel, net operating revenue per barrel and net revenue (loss) from operations per barrel may differ from similar calculations of other companies in the oil and gas industry, thereby limiting their usefulness as comparative measures.

THE DISCUSSION AND ANALYSIS OF THE COMPANY’S OIL AND GAS ACTIVITIES, WITH RESPECT TO OIL AND GAS VOLUMES, RESERVES AND RELATED PERFORMANCE MEASURES, PRESENT THE COMPANY’S NET WORKING INTEREST AFTER ROYALTIES. ALL TABULAR AMOUNTS ARE EXPRESSED IN THOUSANDS OF U.S. DOLLARS, EXCEPT PER SHARE AND PRODUCTION DATA INCLUDING REVENUES AND COSTS PER BOE.

As generally used in the oil and gas business and throughout this Form 10-Q, the following terms have the following meanings:

 

bbl

   =    barrel    mboe    =    thousands of barrels of oil equivalent

bbls/d

   =    barrels per day    mboe/d    =    thousands of barrels of oil equivalent per day

boe

   =    barrel of oil equivalent    mcf   

=    thousands of cubic feet

boe/d

   =    barrels of oil equivalent per day    mmbbls    =    million barrels

mbbls

   =    thousand barrels    mmbls/d    =    million barrels per day

mbbls/d

   =    thousand barrels per day      

Oil equivalents compare quantities of oil with quantities of gas or express these different commodities in a common unit. In calculating barrel of oil equivalents (boe), the generally recognized industry standard is one bbl is equal to six mcf. Boes may be misleading, particularly if used in isolation. The conversion ratio is based on an energy equivalent conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead.

Electronic copies of the Company’s filings with the SEC and the CSA are available, free of charge, through the Company’s website (www.ivanhoeenergy.com) or, upon request, by contacting its investor relations department at (403) 261-1700. Alternatively, the SEC and the CSA each maintains a website (www.sec.gov and www.sedar.com) from which the Company’s periodic reports and other public filings with the SEC and the CSA can be obtained. Copies of the charters for each of the committees of the Company's board of directors are available through the Company’s website at www.ivanhoeenergy.com/index.php?page=mandate_of_the_boardcommittee_overview.

 

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HIGHLIGHTS

 

     Three months
ended June 30,
   

Six months

ended June 30,

 

($000, except as stated)

   2012     2011     2012     2011  

Average daily production (bbls/d)

     1,017        940        894        973   

Realized oil prices ($/bbl)

     121.99        109.71        118.01        99.38   

Oil revenue

     11,292        9,389        19,200        17,508   

Capital expenditures

     24,619        17,420        33,544        31,235   

Cash flow used in operating activities

     (4,184     (6,455     (11,076     (13,464

Net loss

     (4,703     (4,111     (15,365     (15,237

Net loss per share, basic and diluted

     (0.01     (0.01     (0.04     (0.04

Ivanhoe’s oil revenue in the three months ended June 30, 2012 increased from the second quarter of 2011 due to a combination of increased net volumes and higher pricing. Oil production from the Dagang field in China was relatively constant. However, the terms of the production sharing contract stipulate that capital expenditures are to be funded 100% by Ivanhoe and CNPC’s portion of the costs will be reimbursed through the receipt of additional oil sales. Due to higher capital activity at Dagang in the current quarter, more oil production was allocated to Ivanhoe in the three months ended June 30, 2012.

The net loss in the three months ended June 30, 2012 was $4.7 million compared to a $4.1 million net loss in the second quarter of 2011. Although the current quarter benefitted from higher revenue and lower general and administrative expenses, unrealized derivative instrument gains were smaller in the second quarter of 2012 compared to the second quarter of 2011.

Capital expenditures for the Company totaled $24.6 million in the second quarter of 2012. In China, Ivanhoe focused on a 160 square kilometer, 3-D seismic acquisition program at Zitong as well as drilling two wells, completing one well and continuing the fracture stimulation program at Dagang.

In Canada, the regulatory approval process for the Tamarack Project continued to advance. The Company has been working with regulators to answer technical questions and with local area stakeholders to address their specific areas of interest. Responses to the regulator’s second round of Supplemental Information Requests were submitted on July 6, 2012. Although the Company anticipates receiving approval of the application by the end of 2012, timing is subject to the pace of the regulatory process.

In Ecuador, the Company commenced drilling the IP-17 exploration well in the first quarter of 2012 to evaluate the potential of the southern part of the Pungarayacu field. Drilling continued throughout the second and third quarters and the Company drilled to a total depth of 13,594 feet, where the well was cased and suspended. The well confirmed the presence of hydrocarbons in the Hollin and Napo formations and evaluated the potential of the deeper, pre-cretaceous structures. While hydrocarbons were found in the Hollin and Napo formations, the reservoir in the immediate vicinity of the well was not suitable for commercial exploitation. Additional work is required to explain the Hollin and Napo reservoir characteristics south of the Napo river. In the pre-cretaceous, the well did not have commercial quantities of hydrocarbons, but the evaluation does show good indications that the formations have the potential of generating and storing hydrocarbons.

RESULTS OF OPERATIONS

 

     Three months
ended June 30,
     Six months ended
June 30,
 
     2012      2011      2012      2011  

Asia (net bbls)

           

Dagang

     88,993         81,664         155,122         168,529   

Daqing

     3,577         3,917         7,585         7,651   
  

 

 

    

 

 

    

 

 

    

 

 

 

Total production

     92,570         85,581         162,707         176,180   
  

 

 

    

 

 

    

 

 

    

 

 

 

Average daily production (bbls/d)

     1,017         940         894         973   

Pricing

           

Average realized oil price ($/bbl)

     121.99         109.71         118.01         99.38   

Average Brent ($/bbl)

     108.33         117.33         113.03         111.14   

 

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Table of Contents

Oil Revenue

Ivanhoe’s oil revenue in the three and six months ended June 30, 2012 increased from the comparable periods in 2011. In the second quarter of 2012, revenue increased in comparison to the second quarter of 2011 due to a combination of higher net production volumes as well as higher realized prices. Oil production from the Dagang field in China was relatively constant. However, the terms of the Company’s production sharing contract at Dagang with China National Petroleum Corporation (“CNPC”) stipulate that capital expenditures are to be funded 100% by Ivanhoe and CNPC’s portion of the costs are reimbursed through the receipt of additional oil sales.

Revenue was higher in the first six months of 2012 than in the first half of 2011 as a result of stronger realized prices, despite lower net production volumes. Less oil production was allocated to Ivanhoe in the first half of 2012 than in 2011 due to lower capital activity at Dagang in comparison to the prior year.

Net Revenue from Operations

 

     Three months
ended June 30,
    Six months ended
June 30,
 

($/bbl)

   2012     2011     2012     2011  

Oil revenue(1)

     121.99        109.71        118.01        99.38   

Less operating costs

        

Field operating

     (16.70     (19.76     (20.17     (18.81

Windfall Levy

     (24.52     (25.51     (22.91     (21.34

Engineering and support costs

     (1.18     (1.20     (1.40     (1.21
  

 

 

   

 

 

   

 

 

   

 

 

 

Net operating revenue(1)

     79.59        63.24        73.53        58.02   

Depletion

     (22.99     (18.74     (22.60     (18.03
  

 

 

   

 

 

   

 

 

   

 

 

 

Net revenue from operations(1)

     56.60        44.50        50.93        39.99   
  

 

 

   

 

 

   

 

 

   

 

 

 

 

(1) Oil revenue per barrel, net operating revenue per barrel and net revenue from operations per barrel do not have standardized meanings prescribed by IFRS and therefore may not be comparable to similar measures used by other companies. Please refer to the Non-IFRS Financial Measures under the Advisories section in this MD&A for more details.

Operating Costs

 

     Three months
ended June 30,
     Six months
ended June 30,
 
     2012      2011      2012      2011  

Asia

           

Field operating

     1,547         1,692         3,283         3,315   

Windfall Levy

     2,270         2,182         3,728         3,759   

Engineering support

     108         103         226         213   
  

 

 

    

 

 

    

 

 

    

 

 

 
     3,925         3,977         7,237         7,287   

Technology Development

           

FTF operating costs

     921         1,362         2,257         2,575   
  

 

 

    

 

 

    

 

 

    

 

 

 

Total operating costs

     4,846         5,339         9,494         9,862   
  

 

 

    

 

 

    

 

 

    

 

 

 

Total operating costs in China in the three months ended June 30, 2012 were consistent with the second quarter of 2011. However, operating costs per barrel were $4.07/bbl lower in the three months ended June 30, 2012 than in the comparable period due to higher production volumes in the current quarter. Field operating costs per barrel were lower in the current quarter as staff activity was concentrated on capital activities in Dagang and, as a result, staff costs were capitalized rather than expensed. The Company completed fewer maintenance workovers in 2012 than in the prior year, which also resulted in lower field costs and the Windfall Levy per barrel was lower in the current quarter as the Windfall Levy threshold increased to $55.00/bbl on November 1, 2011.

Similarly, total operating costs in China were consistent for the first half of 2012 and 2011. However, operating costs were $3.12/bbl higher in the six months ended June 30, 2012 than in the comparable period. Field operating costs per barrel were higher in the first half of 2012 due to less capital activity in the Dagang field while the Windfall Levy per barrel was greater in the first half of 2012 as a result of higher realized prices.

 

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Table of Contents

Operating costs for technology development were incurred at the Company’s Feedstock Test Facility (“FTF”) at the Southwest Research Institute in San Antonio, Texas. FTF operating costs in the three and six months ended June 30, 2012 were lower than in the comparable periods due to more streamlined data collection and analysis during project testing in the second quarter of 2012.

General and Administrative

G&A expenses were $1.3 million lower in the three months ended June 30, 2012 than in the second quarter of 2011. Due to reduced activity in the Company’s Asia segment and streamlining operations in Canada and Latin America, staff and travel costs were $0.3 million lower in the current quarter than in the comparable period. Non-cash stock based compensation was $0.5 million lower in the current quarter than in the second quarter of 2011 and contract engineering costs related to Ivanhoe’s HTLTM technology decreased $0.3 million in the current quarter compared to the second quarter of 2011, both of which were marginally offset by minor cost increases in other areas.

G&A expenses were $4.3 million lower in the six months ended June 30, 2012 than in the first half of 2011. The reduction is primarily attributable to $2.5 million of staff bonuses that were paid, but not accrued for, in the first quarter of 2011. Non-cash stock based compensation was $1.0 million lower to date in 2012 compared to the first half of 2011. Due to reduced activity in the Company’s Asia segment, staff and contractor costs were $1.0 million lower in the six months ended June 30, 2012 than in the comparable period.

Depletion and Depreciation

Depletion and depreciation charges in the three and six months ended June 30, 2012 were $0.5 million higher over comparable periods due to higher depletion costs in Asia. Depletion in Asia in the current quarter was higher than in the second quarter of 2011 due to a combination of higher production volumes and a higher depletion rate. The depletion rate rose as a result of lower reserves assigned to Dagang at December 31, 2011.

Depletion in the first half of 2012 was also higher than in the first half of 2011, but the increase was predominantly a result of the higher depletion rate, which was slightly offset by lower year over year production volumes.

The FTF depreciation expense was consistent with the comparable periods in 2011.

Foreign Exchange

The Company recognized a foreign exchange gain of $1.8 million in the second quarter of 2012 in comparison to a gain of $0.2 million in the three months ended June 30, 2011. In the current quarter, the Canadian dollar weakened in comparison to the US dollar, creating a gain on the translation of the Company’s Cdn$73.3 million convertible debentures (“Convertible Debentures”) into US dollars, which was marginally offset by foreign exchange losses on the Company’s Canadian dollar cash and accounts payable balances. In comparison, the Canadian dollar weakened only slightly against the US dollar in the second quarter of 2011, resulting in a foreign exchange gain of $0.2 million.

In the first half of 2012, the foreign exchange gain was greater than in the first half of 2011. Changes in the exchange rates and holding less Canadian dollar cash resulted in a gain of $0.8 million in the first half of 2012. Ivanhoe held higher amounts of Canadian dollar debt in the first half of 2011, however, gains on the translation of the Company’s Canadian dollar denominated debt were partially offset by losses on the translation of Canadian dollar cash.

Derivative Instruments

In the second quarter of 2012, Ivanhoe recognized an unrealized gain of $1.3 million on the revaluation of the convertible component of the Convertible Debentures. In comparison, the Company recognized an unrealized gain of $6.1 million on its derivative liabilities in the second quarter of 2011. The expiry of the Company’s 2006 purchase warrants resulted in a gain of $2.3 million; a gain of $0.7 million was recognized on the revaluation of the convertible portion of the convertible note, and the revaluation of the convertible portion of the Convertible Debentures created a gain of $2.2 million in the second quarter of 2011. The revaluation of an option granted to a private investor in January 2010 to acquire an equity interest in one of the Company’s subsidiaries (“Subsidiary Option”) also created a gain of $0.9 million in the second quarter of 2011.

In the first half of 2012, the Company recognized an unrealized gain of $1.7 million on its derivative liabilities due to a $1.6 million gain on the revaluation of the convertible component of the Convertible Debentures and the expiration of the Subsidiary Option created a gain of $0.2 million. In comparison, the Company sustained an unrealized gain of $7.2 million in the first half of 2011. A combination of the expiry and revaluation of purchase warrants produced a gain of $4.1 million, while the revaluation of the convertible components of the convertible note and Convertible Debentures created gains of $1.2 million and $2.2 million, respectively, in the first half of 2011. These gains were offset by a $0.3 million loss on the revaluation of the Subsidiary Option.

 

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Table of Contents

Provision for Income Taxes

Ivanhoe incurred a deferred tax expense of $0.3 million to date in 2012 due to an increase in the Chinese deferred tax liability which was partially offset by a reduction in the US deferred tax liability.

LIQUIDITY AND CAPITAL RESOURCES

Contractual Obligations and Commitments

The following information about our contractual obligations and other commitments summarizes certain liquidity and capital resource requirements. The information presented in the table below does not include planned, but not legally committed, capital expenditures or obligations that are discretionary and/or being performed under contracts which are cancelable on 30 days notice or less.

 

     Total      2012      2013      2014      2015      After 2015  

Short term debt and interest

     43,793         1,771         42,022         —           —           —     

Long term debt and interest

     88,613         2,123         4,140         4,140         4,140         74,070   

Zitong appraisal program

     66,510         31,680         31,680         3,150         —           —     

Ecuador drilling program

     5,201         5,110         91         —           —           —     

Decommissioning obligations(1)

     3,520         —           385         —           —           3,135   

Leases

     3,897         967         1,432         595         401         502   
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

Total

     211,534         41,651         79,750         7,885         4,541         77,707   
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

 

(1) Represents undiscounted asset retirement obligations after inflation. The discounted value of these estimated obligations ($2.5 million) is provided for in the consolidated financial statements.

Short Term Debt and Interest

On December 30, 2011, Ivanhoe entered into a loan agreement with ICFL, a company wholly owned by Robert Friedland, for $10.0 million (“ICFL Loan”). The funds were advanced on January 3, 2012 and bear interest at a rate of 10.0% per annum. On March 14, 2012, the loan agreement was amended to provide that, at ICFL’s option, the outstanding principal may be converted into 10,484,375 common shares of the Company at a price of Cdn$0.96 per common share. The principal balance matures on March 31, 2013, or earlier upon the occurrence of certain events.

In March 2012, the Company entered into a one year credit agreement with UBS Securities LLC for a $50.0 million loan (“UBS Loan”). At June 30, 2012, the Company had drawn $30.0 million of principal on the UBS Loan, as reflected in the above table. Subsequent to quarter end, Ivanhoe elected to draw an additional $20.0 million of principal in July 2012. Borrowed amounts bear interest at one month Libor plus 10% for the first six months of the loan and escalate by 1% per month thereafter. Interest is payable monthly.

Long Term Debt and Interest

In June 2011, the Company issued Convertible Debentures, which mature on June 30, 2016. The Convertible Debentures bear interest at an annual rate of 5.75%, payable semi-annually on June 30 and December 31 of each year.

Zitong Appraisal Program

The terms of the Supplementary Agreement to the Contract for Exploration, Development and Production in Zitong Block, Sichuan Basin with CNPC call for the completion of an appraisal program by the end of June 2014. The work program consists of a 160 square kilometer seismic acquisition program, as well as drilling and completing three horizontal wells on the Guan and Wen structures.

Ecuador Drilling Program

At the end of February 2012, the Company began drilling the IP-17 exploration well to test both the Hollin and pre-cretaceous structures in the southern part of Block 20. Commitments associated with the well total $5.2 million.

 

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Decommissioning Provisions

The Company is required to remedy the effect of our activities on the environment at our operating sites by dismantling and removing production facilities and remediating any damage caused. At June 30, 2012, Ivanhoe estimated the total undiscounted, inflated cost to settle its asset retirement obligations in Canada, for the FTF in the US and in Ecuador was $3.5 million. These costs are expected to be incurred in 2013, 2029 and 2038, respectively. Ivanhoe does not make such a provision for decommissioning costs in connection with its oil and gas operations in China as dry holes are abandoned as they occur and productive wells will not be abandoned while the Company has an economic interest in the field.

Leases

The Company has long term leases for office space and vehicles, which expire between 2012 and 2017.

Other

Should Ivanhoe receive government and other approvals necessary to develop the northern border of one of the Tamarack Project leases, the Company will be required to make a cash payment to Talisman of up to Cdn$15.0 million, as a contingent, final payment for the 2008 acquisition of the Tamarack Project leases.

From time to time, Ivanhoe enters into consulting agreements whereby a success fee may be payable if and when either a definitive agreement is signed or certain other contractual milestones are met. Under the agreements, the consultant may receive cash, common shares, stock options or some combination thereof. Similarly, agreements entered into by the Company may contain cancellation fees or liquidated damages provisions for early termination. These fees are not considered to be material.

The Company may provide indemnities to third parties, in the ordinary course of business, that are customary in certain commercial transactions, such as purchase and sale agreements. The terms of these indemnities will vary based upon the contract, the nature of which prevents Ivanhoe from making a reasonable estimate of the maximum potential amounts that may be required to be paid. The Company’s management is of the opinion that any resulting settlements relating to indemnities are not likely to be material.

In the ordinary course of business, the Company is subject to legal proceedings being brought against it. While the final outcome of these proceedings is uncertain, the Company believes that these proceedings, in the aggregate, are not reasonably likely to have a material effect on its financial position or earnings.

Sources and Uses of Cash

The Company’s cash flows from operating, investing and financing activities, as reflected in the unaudited condensed consolidated statements of cash flows, are summarized in the following table:

 

    

Three months

ended June 30,

   

Six months

ended June 30,

 
     2012     2011     2012     2011  

Cash used in operating activities

     (4,184     (6,455     (11,076     (13,464

Cash used in investing activities

     (10,598     (16,639     (15,762     (28,123

Cash provided by financing activities

     —          72,945        37,282        102,740   

Ivanhoe’s cash flow from operating activities is not sufficient to meet its operating and capital obligations over the next twelve months. The Company intends to use its working capital to meet its commitments. However, additional sources of funding will be required to advance the Company’s major projects and fully develop its oil and gas properties. Historically, Ivanhoe has used external sources of funding such as public and private equity, debt markets and joint venture partners. However, there is no assurance that these sources of funding will be available to the Company in the future or available on acceptable terms.

Operating Activities

In the three and six months ended June 30, 2012, cash used in operating activities was less than in 2011 as a result of higher revenue and reduced G&A costs.

 

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Investing Activities

Exploration and Evaluation Expenditures

Exploration and evaluation capital expenditures for the Company in the three months ended June 30, 2012 totaled $19.5 million. In China, Ivanhoe expended $9.5 million on a 160 square kilometer 3-D seismic program at Zitong. In Canada, the regulatory approval process for the Tamarack Project continued to progress and expenditures of $0.6 million were incurred to support the regulatory process. Expenditures of $9.4 million were incurred in connection with drilling of the IP-17 exploration well in the southern part of Block 20 in Ecuador.

In the first half of 2012, exploration and evaluation capital expenditures totaled $28.1 million. In China, Ivanhoe expended $10.1 million on the seismic program at Zitong, expenditures to support the regulatory process at Tamarack were $2.8 million and costs incurred in connection with drilling of the IP-17 exploration well in the southern part of Block 20 in Ecuador totaled $15.2 million.

Property, Plant and Equipment Expenditures

In the three and six months ended June 30, 2012, property, plant and equipment additions totaled $5.1 million and $5.5 million, respectively. The Company drilled two wells, completed one well and continued its fracture stimulation program at Dagang in the second quarter of 2012.

Financing Activities

In the first half of 2012, Ivanhoe received financing of $37.3 million, net of transaction costs, to support liquidity. Pursuant to an unsecured loan agreement signed in late 2011, the Company received $10.0 million from ICFL in January 2012. In March 2012, the Company established a $50.0 million short-term secured credit facility with UBS Securities LLC. The loan consists of an initial tranche of $30.0 million and includes an accordion feature to increase the total amount by up to an additional $20.0 million.

Capital Structure

 

As at

   June 30,
2012
     December 31,
2011
 

Debt

     38,348         —     

Long term debt

     62,235         61,892   

Shareholders’ equity

     300,941         314,137   

At June 30, 2012, Ivanhoe’s market capitalization was less than the carrying value of the Company’s assets. Management does not consider this to be determinative that an impairment exists as there are factors which should be considered when interpreting Ivanhoe’s recent trading price, such as the Company’s low trading volumes, industry influences including commodity price concerns and larger macro-economic factors that have created an overall malaise in the capital and economic markets. Management does not believe the full value of the Company’s oil and gas assets or HTLTM technology is reflected in Ivanhoe’s current stock price. On May 24, 2012, the Company received a notification from the Listing Qualifications Department of the NASDAQ Stock Market ("Nasdaq") notifying the Company that the Company did not meet the minimum bid price requirements set forth in the Nasdaq Listing Rules. For additional information, refer to the Form 8-K filed on May 31, 2012.

Ivanhoe intends to use its cash and cash equivalent balance to fulfill its commitments and partially fund operations in 2012. Cash flow may be insufficient to meet operating requirements in the next twelve months and additional sources of funding, either at a parent company level or at a project level, will be required to grow the Company’s major projects and fully develop its oil and gas properties. Historically, Ivanhoe has used external sources of funding, such as public and private equity, debt markets and joint venture partners. Ivanhoe intends to finance its future funding requirements through a combination of strategic investors, joint venture partnerships, public and private debt and equity markets, either at a parent company level or at the project level, and through the sale of interests in existing oil and gas properties. There is no assurance that the Company will be able to obtain such financing, or obtain it on favorable terms, and any future equity issuances may be dilutive to current investors. If Ivanhoe cannot secure additional financing, the Company may have to delay its capital programs and forfeit or dilute its rights in existing oil and gas property interests.

 

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Outlook

In China, implementation of the previously announced transaction to assign its interest in the Production Sharing Contract for the Zitong block in China’s Sichuan Basin to Shell China Exploration continues to advance. Closing is expected to occur once all the necessary approvals have been obtained. Management anticipates receiving the necessary approvals during the third quarter but can give no assurance as to when such approvals will actually be given.

In Canada, the regulatory approval process for the Tamarack project is continuing to progress. The Company has been working with regulators to answer technical questions and with local area stakeholders to address their specific areas of interest. Responses to the regulator’s second round of Supplemental Information Requests were submitted on July 6, 2012. The Company continues to anticipate receiving regulatory approval by the end of 2012. Project advancement, as currently envisaged, is subject to regulatory approval and financing.

In Ecuador, Management is in discussions with a potential strategic partner to establish a financial participation arrangement for Block 20. The Company’s objective is to finalize and implement these arrangements by the end of 2012. While Management is encouraged by the progress made to date, any potential arrangement remains subject to Ecuadorian Government approval and continued commercial negotiations such that Management can give no assurance that such arrangements will ultimately be established.

Ivanhoe continues to focus its HTLTM commercialization efforts on establishing midstream partnerships and business development activities for several projects in Latin America.

Management’s plans for financing future expenditures include traditional project financing, debt and mezzanine financing, the sale of non-current assets or the sale of equity securities as well as the potential for alliances or other arrangements with strategic partners. However, no assurances can be given that Ivanhoe will be able to enter into one or more strategic business alliances with third parties or that the Company will be able to sell non-core assets on acceptable terms or raise sufficient additional capital. If the Company is unable to enter into such business alliances or obtain adequate additional financing, the Company may be required to curtail its operations, which may include the sale or abandonment of assets.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

There has been no material change in the Company’s assessment of its sensitivity to market risk since its presentation set forth in Item 7A, “Quantitative and Qualitative Disclosures About Market Risk” in the 2011 Form 10-K.

ITEM 4. CONTROLS AND PROCEDURES

The Company’s management, including its Executive Chairman and its Chief Financial Officer, evaluated the effectiveness of the design and operation of the Company’s disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) as of June 30, 2012. Based upon this evaluation, management concluded that these controls and procedures were (1) designed to ensure that material information relating to the Company is made known to the Company’s Executive Chairman and its Chief Financial Officer as appropriate to allow timely decisions regarding disclosure and (2) effective, in that they provide reasonable assurance that information required to be disclosed by the Company in the reports that it files or submits under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms.

It should be noted that while the Company’s Executive Chairman and its Chief Financial Officer believe that the Company’s disclosure controls and procedures provide a reasonable level of assurance that they are effective, they do not expect that the Company’s disclosure controls and procedures or internal control over financial reporting will prevent all errors and fraud. A control system, no matter how well conceived or operated, can provide only reasonable, not absolute, assurance that the objectives of the control system are met.

There were no changes in the Company’s internal control over financial reporting in the quarter ended June 30, 2012, that have materially affected, or are reasonably likely to have a material effect on the Company’s internal control over financial reporting.

 

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PART II OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

On July 12, 2012, the United States Court of Appeals for the Tenth Circuit affirmed the dismissal of a lawsuit against the Company and related parties that had been filed on November 20, 2008 in the United States District Court for the District of Colorado. The plaintiffs in the case are Jack J. Grynberg and three affiliated companies. The recent ruling from the Tenth Circuit affirms the district court’s judgment dismissing the case without prejudice. The Court of Appeals has denied plaintiffs’ request for rehearing, but has not yet issued a mandate, which would finally conclude the current appellate proceeding.

The suit alleged bribery and other misconduct and challenged the propriety of a contract awarded to the Company’s wholly-owned subsidiary Ivanhoe Energy Ecuador Inc. to develop Ecuador’s Pungarayacu heavy oil field. The plaintiffs’ claims were for unspecified damages or ownership of the Company’s interest in the Pungarayacu field. The Company and related defendants filed motions to dismiss the lawsuit for lack of jurisdiction. The district court granted the motion and dismissed the case without prejudice. The district court also granted Mr. Robert Friedland’s request to sanction plaintiffs and plaintiffs’ counsel for their conduct related to bringing the suit by awarding Mr. Friedland fees and costs. The Ivanhoe corporate defendants, including the Company, also have been awarded costs and fees as the prevailing parties in the trial court.

The Court of Appeals’ July 12, 2012 order affirmed the district court’s judgment and related orders. The Court of Appeals also concluded that the Ivanhoe Corporate defendants, including the Company, are entitled to fees and costs they incurred on appeal. The Court of Appeals remanded the case to the district court for the limited purpose of computing a proper award of appellate fees and costs.

On December 30, 2010, the Company received a demand for arbitration from GAR Energy and Associates, Inc. (“GAR Energy”) and Gonzalo A. Ruiz and Janis S. Ruiz as successors in interest to, and assignees of, GAR Energy. GAR Energy subsequently abandoned its demand for arbitration and filed suit against the Company and subsidiaries in the Superior Court for Kern County, California on March 11, 2011. The lawsuit alleges breach of contract, fraud and other misconduct arising from a consulting agreement and various other agreements between GAR Energy and the Company relating to the Pungarayacu heavy oil field. The plaintiffs seek actual damages of $250,000 and a portion of the Company’s interest in the Pungarayacu field. The plaintiffs seek other miscellaneous relief, including requests for a declaration of some of the parties’ rights and legal relations under a consulting agreement, attorneys' fees and certain litigation costs and expenses, disgorgement of the Company's past, current and/or future profits attributable to the Pungarayacu field and certain other fields in Ecuador, tort damages and exemplary and punitive damages, the imposition of constructive trusts over certain amounts and profits requested by the plaintiffs, and pre-judgment and post-judgment interest. The Company removed the case to the United States District Court for the Eastern District of California and all of the defendants have answered and filed counterclaims for attorneys’ fees. Defendants filed a motion to dismiss certain claims and to compel arbitration of others. Plaintiffs’ filed a motion to remand the case to state court. On December 23, 2011, the Magistrate Judge denied plaintiffs’ motion to remand and issued findings and recommendations that would send all of the parties and all of the claims to arbitration should the district court Judge assigned to the case adopt them. On January 19, 2012 the district court Judge adopted the Magistrate Judge’s findings and recommendations in full, ordered the parties to arbitration and stayed the district court proceedings to allow for the completion of the arbitration. The arbitration is in the early stages of proceeding. The likelihood of loss or gain resulting from this dispute, and the estimated amount of ultimate loss or gain, are not determinable or reasonably estimable at this time.

ITEM 1A: RISK FACTORS

Ivanhoe is exposed in varying degrees to normal market risks inherent in the oil and gas industry, including commodity price risk, foreign currency exchange rate risk, credit risk, interest rate risk and liquidity risk. The Company recognizes these risks and manages its operations to minimize the exposure to the extent practicable. There have not been any significant changes to the Company’s exposure to risks, or processes to manage these risks as described in the Company’s 2011 Form 10-K, except as noted below:

Interest Rate Risk

As at June 30, 2012, the Company had borrowed $30.0 million under the UBS Loan. Subsequent to quarter end, the Company elected to draw an additional $20.0 million of principal in July 2012. Borrowed amounts incur interest at a rate of one month Libor plus 10% for the first six months and escalate by 1% per month thereafter. Borrowings issued at variable rates expose Ivanhoe to interest rate risk. If interest rates increase, the Company’s debt service obligations on the variable interest rate indebtedness would increase, even though the amount borrowed remained the same, and the Company’s net loss would increase. The Company’s goal is to minimize its interest expense; however, the Company does not anticipate using hedging contracts in 2012 to manage its interest rate risk.

 

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If the interest rate on the UBS Loan were to increase by 1%, the Company’s net loss would increase by approximately $25,000 per month. Accordingly, an increase in interest rates from current levels could cause the Company’s annual debt service obligations to increase significantly.

ITEM 6. EXHIBITS

 

Exhibit Number

  

Description of Document

31.1    Certification by the Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
31.2    Certification by the Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
32.1    Certification by the Chief Executive Officer Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
32.2    Certification by the Chief Financial Officer Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

SIGNATURE

Pursuant to the requirements of the Securities Exchange Act of 1934, the Company has duly caused this report to be signed on its behalf by the undersigned thereto duly authorized.

 

IVANHOE ENERGY INC.
By:   /s/ Gerald D. Schiefelbein
  Gerald D. Schiefelbein
  Chief Financial Officer

Date: August 9, 2012

 

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