10-K 1 form10k.htm FEEC FORM 10-K form10k.htm
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549

FORM 10-K
(Mark One)
    
R
ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d)
  
 
OF THE SECURITIES EXCHANGE ACT OF 1934
  
 
For the fiscal year ended December 31, 2009
  
 
OR
  
£
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d)
  
 
OF THE SECURITIES EXCHANGE ACT OF 1934
  

For the transition period from ___________________ to ________________________
Commission File Number 0-32455

Far East Energy Corporation
(Exact Name of Registrant as Specified in Its Charter)

Nevada
88-0459590
(State or other jurisdiction of incorporation or organization)
(I.R.S. Employer Identification No.)
   
363 N. Sam Houston Parkway East, Suite 380, Houston, Texas
77060
(Address of principal executive offices)
(Zip Code)
   
Registrant's telephone number, including area code: (832) 598-0470
 
Securities registered pursuant to Section 12(b) of the Exchange Act: None
 
Securities registered under 12(g) of the Exchange Act: Common stock (par value $0.001 per share)

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.   Yes £ No R

Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act.  Yes £ No R

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. Yes R 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 if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will not be contained, to the best of registrant's knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K.    R

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 the definitions of "large accelerated filer," "accelerated filer" and "smaller reporting company" in Rule 12b-2 of the Exchange Act.  (Check one):  Large accelerated filer £         Accelerated filer £         Non-accelerated filer £         Smaller reporting companyR
 
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Act).   Yes £ No R

The aggregate market value of the voting common stock, par value $0.001 per share, held by non-affiliates of the registrant was approximately $49,963,000 as of June 30, 2009 (based on $0.39 per share, the last price of the common stock as reported on the OTC Bulletin Board on such date). For purposes of the foregoing calculation only, all directors, executive officers and 10% beneficial owners have been deemed affiliates.

The number of shares of common stock, par value $0.001 per share, outstanding as of March 12, 2010 was 185,463,128.

DOCUMENTS INCORPORATED BY REFERENCE
Portions of the registrant’s proxy statement for the 2010 annual meeting of stockholders are incorporated by reference into Part III of this Form 10-K.
 
 
 
 

FAR EAST ENERGY CORPORATION
TABLE OF CONTENTS


   
Page
     
PART I
1
16
28
28
29
     
PART II
30
33
34
48
49
75
75
75
     
PART III
76
76
76
76
76
     
PART IV
77
     
 
SIGNATURES
  

 
PART I

ITEM 1. BUSINESS

General

We were incorporated in Nevada on February 4, 2000. In January 2002, we renamed our company Far East Energy Corporation and changed our focus to exploring, developing, producing and selling coalbed methane gas ("CBM"). Throughout this Annual Report on Form 10-K, the terms "Far East Energy," "Far East," "we," "the Company," "us," "our" and "our company" refer to Far East Energy Corporation and its subsidiaries.  References to "China" and "PRC" are references to the People's Republic of China.  Today, the operations of our company and its subsidiaries concentrate on CBM exploration and development in the Shanxi Province in northern China and Yunnan Province in southern China. Our goal is to become a recognized leader in CBM property acquisition, exploration, development and production. Our principal headquarters office is located at 363 North Sam Houston Parkway East, Suite 380, Houston, Texas 77060. Our main office in China is located in Beijing and we also maintain satellite offices in Taiyuan City and Kunming.

Far East Energy believes that good environmental, social, health and safety performance is an integral part of our business success. We conduct our business with respect and care for our employees, contractors, communities, and the environments in which we operate.  Our vision is zero harm to people and the environment while creating value for our shareholders as well as for China, including the regions and communities within which we operate.  Our commitment to these principles is demonstrated by the fact that we have had no lost-time accidents in over 4.5 years and no major environmental incidents.  We have a commitment to being good corporate citizens of China, striving to emphasize and utilize very high levels of Chinese content in personnel, services, and equipment; and we have achieved very high percentages of Chinese content in each category.

We are a development stage company, and our activities include principally drilling, testing, completing and dewatering of exploratory CBM wells, preparing for possible gas sales in the future and organizational activities. We are party to three production sharing contracts ("PSCs") which cover the 485,000-acre Shouyang Block in Shanxi Province (the "Shouyang PSC"), the 573,000-acre Qinnan Block in Shanxi Province (the "Qinnan PSC"), and the Enhong and Laochang areas, which total 265,000 acres, in Yunnan Province (the "Yunnan PSC").  We believe our total net acreage in these PSCs makes us one of the biggest holders of CBM acreage in China.

In March of 2009, we formed a strategic alliance related to our Qinnan Block with Arrow Energy International Pte Ltd ("Arrow"), the Singapore-based subsidiary of Arrow Energy Limited, a large Australian CBM producer.  For additional information on the strategic alliance, see "Strategic Alliance with Arrow" below.  China National Petroleum Company ("CNPC") has replaced China United Coalbed Methane Co. Ltd. ("CUCBM") as our Chinese partner company in the Qinnan PSC.  We are in discussions with CNPC regarding the extension of the exploration period, which expired on June 30, 2009.  For many months CNPC has been awaiting authorization from the Chinese government allowing it to deal with foreign partners on CBM projects. On March 7, 2010, several major news outlets reported that CNPC stated that it has been authorized to jointly develop coalbed methane projects with foreign partners, but we have not yet obtained official confirmation of this.  There can be no assurance that CNPC will approve an extension of the exploration period or approve the Farmout Agreement with Arrow.

Our Website

Our website can be found at www.fareastenergy.com. Our Annual Reports on Form 10-K, Quarterly Reports on Form 10-Q, Current Reports on Form 8-K and amendments to those reports filed with or furnished to the U.S. Securities and Exchange Commission ("SEC"), pursuant to Section 13(a) or 15(d) of the Securities Exchange Act of 1934 ("Exchange Act"), can be accessed free of charge by linking directly from our website under the "Investor Relations - SEC Filings" caption to the SEC's Edgar Database. These filings will be available as soon as reasonably practicable after we electronically file such material with, or furnish it to, the SEC. Information contained on our website is not part of this report.


Coalbed Methane Gas and Attributes of Coalbed Methane Resources

Coalbed methane gas is a type of natural gas found in coal seams of various types of coal. As coal is formed, large quantities of natural gas are generated and adsorbed on the internal surface area of the coal.  CBM exploration and production involves drilling into a known coal deposit and extracting the natural gas that is contained in the coal. A coal seam is often saturated with water, with methane gas being held in the coal by water pressure. To produce CBM from coalbeds, water must first be pumped from the seam in order to reduce the water pressure that holds the gas in the seam. This process is called dewatering. When the water pressure is reduced, the gas adsorbed on the coal is released and diffuses through the fractures, or cleats, contained in the coal seam. Gas flows to the well bore through the cleat system as well as any of the other cracks, crevices and fractures found in the coalbed. Dewatering volumes decrease as peak CBM production is reached.

The productivity potential of a well depends on many reservoir and geological characteristics, including permeability, thickness and depth of the coalbed, the coal ranking of the coalbed, gas content and other factors. We consider these factors, as well as isotherm tests conducted on core samples, the amount of dewatering required of a well and a number of other factors, when choosing where to develop any coalbed methane present in our CBM acreage.

Permeability.  Coalbed methane gas production requires that the coal have sufficient permeability.  Permeability is the ability of a substance to allow another substance to pass through it.  In the case of our CBM properties, permeability is the ability of the coal to allow water and/or gas to pass through it.  Permeability in coal is primarily created by naturally occurring fractures, which are commonly referred to as cleats.  Permeability is largely based upon how many cleats the coal has and how close they are to each other. The more cleats that coal has, the better the coal's permeability and the greater opportunity to retrieve the adsorbed CBM.  Tectonic fracturing can also contribute greatly to permeability. Reservoirs with high permeability have a higher propensity for strong gas production than less permeable reservoirs.  The same permeability that can contribute to strong gas production, also initially allows more water to flow through the coal.  Thus, coal seams with higher permeability often take significantly longer time to dewater than lower permeability coal seams.  Once sufficient water is produced, higher permeability normally allows wells to maintain higher production rates for longer periods and enables higher gas recoveries with fewer wells.

Thickness.  The thickness of the coal seam is crucial to CBM production. A coal seam with otherwise unacceptably low permeability could produce commercial quantities of gas if the coal seam has sufficient thickness. In this case, the gas would flow out slowly, but because the coal seam is thick, more of the gas would be produced since there is a large area from which to collect the CBM.

Depth.  The depth of the coal seam is also a significant factor in the productivity potential of a well. Where the coal, and thus the methane gas, lies at shallow depths, wells are generally easier to drill and less expensive to complete. With greater depth, increased pressure closes cleats in the coal, which reduces permeability and the ability of the CBM to move through and out of the coal. On the other hand, if a coal seam is not buried deep enough, there may not have been sufficient water pressure to hold the gas in place and through geologic time the gas may have escaped from the coal.

Coal Ranking.  Methane gas is contained in all ranks of coal. The most CBM is contained in the highest rank coal, which is called anthracite. Unfortunately, anthracite has very low permeability. Semi-anthracite coal typically has lower quantities of CBM than anthracite coal, but may contain significant cleats as well, making it more permeable. The coalbeds found in our Shanxi Province project are semi-anthracite coal that have a favorable cleat structure, which should have a favorable impact on permeability.

The next lesser coal rank is bituminous coal that contains less CBM per ton than the anthracite and semi-anthracite coal but usually has a good cleat structure, allowing for better permeability. The coalbeds found in our Enhong–Laochang project, which are located in the Yunnan Province, have bituminous and semi-anthracite coal.

Dewatering.  Water must be removed from the coal seams to decrease reservoir pressure and release the gas to produce methane gas from coalbeds. After the detachment of gas molecules from the coal surface, or desorption, occurs, the gas diffuses through the coalbed's cleats and fractures toward the well bore. Substantial dewatering of the

 
coalbed is required initially. Water production declines as methane gas production increases. Dewatering of a well may generally range in length from a few weeks to as many as three years or more depending on the attributes of the coal seam.  Depending on the quantity and quality of the water, disposal of large quantities of produced water may present major economic and environmental challenges for operators. These costs can affect the feasibility of CBM projects.

Coalbed Methane in the People's Republic of China

China is the world's largest coal producing country and has substantial CBM resources located within its coalfields. Because most of China's CBM is found at shallow depths, it is easier to drill and complete CBM wells than the deeper wells that are generally required for other forms of natural resource exploration. China's mining operations release approximately 6 billion cubic feet of methane gas into the environment each year because much of the country's CBM resources remain undeveloped. This results in serious pollution and wastes CBM, which could be recovered prior to mining.

Our business strategy is to explore, develop, produce and sell CBM in China. China is currently the world's second largest user of petroleum and one of the largest importers of oil and, to a lesser extent, gas, in the world. China's energy needs have grown rapidly in the past 20 years, fueled in part by the tremendous economic growth during that period. The growth in demand for energy in China is projected to outpace the rest of the world over the next decade. As a result of China's increasing energy needs, the Chinese government has, in recent years, focused great attention on the development of energy sources, including CBM.  The Eleventh Five-Year Plan addressed CBM development and these elements were adopted by the National Development and Reform Commission (the "NDRC") in July 2006. The NDRC is a Chinese commission responsible for the development and strategic upgrade of key industries in China, including the CBM industry. The plan outlines the goal to more than double CBM extraction by 2010, from 0.4 billion cubic feet per day ("Bcfd") in 2006 to 1.0 Bcfd in 2010.  A separate directive specifies safety and extraction regulations alongside favorable incentive policies for CBM development. The overall goal of this plan is to foster a surge in CBM industrialization.  As part of its plan to increase CBM production, the State Council of the PRC, the chief administrative body of the PRC, created CUCBM in 1996. The State Council granted CUCBM rights to contract with foreign corporations for the exploration, development and production of CBM in China.  In mid 2008, one of the major stakeholders of CUCBM, China National Petroleum Company ("CNPC"), expressed a desire to contract directly with foreign corporations to work on CBM projects instead of working through CUCBM, allowing these foreign entities to tap into CNPC’s operational expertise, financial strength, and several existing pipelines and reserve blocks. In addition, the Chinese government has provided incentives to stimulate the development of CBM, including exempting CBM development from import duties and import-related duties (Encouraged and Restricted B of the Guidance Catalog of Industries for Foreign Investments, specific measures executed in accordance with No. 1602 Document issued by the State Administration of Customs in 1997) and reducing value-added tax ("VAT") for CBM projects with foreign companies to 5% compared to 13% to 17% VAT for conventional gas companies (The Notice of the Interim Regulations Concerning the Value-Added Tax, Consumption Tax and Sales Tax Applied to Foreign Investment Enterprise and Foreign Enterprise (February 22, 1994, Item 3)).  For more information on the laws, regulations and regulatory bodies that affect our business, see "Regulations Impacting Our Business" below.

Drilling and Hydraulic Fracturing Technologies

Vertical, deviated and horizontal drilling technologies have yielded successful results in CBM applications. We are currently leveraging all three technologies in our CBM production in China. Which of these drilling technologies or combination thereof will yield optimal results as we explore and develop our blocks is not yet clear. Vertical wells are the cheapest and most straightforward wells to drill and complete, but each well requires a dedicated surface location. A horizontal well potentially allows a well bore to be in contact with hundreds or thousands of feet of coal because the drill bit, when it hits the coal seam, is redirected from a downward angle to a horizontal plane and tracks along the same plane as the coalbed, thereby exposing more coal to the wellbore.  This greater exposure of the coalface achieved by horizontal drilling generally allows for greater CBM production on a daily basis than can be achieved with conventional vertical drilling and completion techniques. Although horizontal wells are more costly and technically challenging than vertical and deviated wells because of wellbore stability and pumping difficulties, they offer greater potential in reduced surface facilities and increased production rates.  Deviated wells are used to access downhole locations that are not accessible with a vertical wellbore.  Deviated wells are slightly

 
more expensive and complicated to drill and complete than vertical wells.  However they are drilled from an existing well pad and location.  Utilizing an existing well location allows more than one well to be drilled from the same pad, consequently reducing land and pad construction costs, as well as reducing environmental impact.  Beginning the second half of 2008, we have applied the deviated drilling technology and drilled with success in our Shouyang Block.

Hydraulic fracturing technology has been utilized in CBM exploration and development for many years.  The technique fractures a formation by pumping fluid, usually water in CBM stimulation, into the formation at a high enough pressure to open the formation to allow a proppant, such as sand, to be pumped into the formation.  This act of opening the formation and pumping in a propping agent allows better communication between the wellbore and the formation.  This is often necessary in formations where permeability around the wellbore is found to be reduced after drilling and thus preventing formation fluids from effectively entering into the wellbore and being produced.  Even though our current hydraulic fracturing operations have generally improved our water production, Far East is continually seeking the best combination of fracturing fluids and propping agents to provide the best completions for our wells.

Acreage in the People's Republic of China

The following table summarizes the acreage subject to our PSCs covering the following undeveloped lease acreage in China as of December 31, 2009:

         
Net Acres
  
   
Gross Acres
    
Maximum (1)
    
Minimum (2)
  
China:
                  
Shouyang Block, Shanxi Province
     485,000       485,000       340,000  
Qinnan Block, Shanxi Province
     573,000 (3)     573,000       401,000  
Enhong and Laochang Areas, Yunnan Province
     265,000       265,000       159,000  

(1) Assuming the Chinese partner company chooses not to participate.
(2) Assuming the Chinese partner company chooses to maximize its participation.
(3) Under a farmout agreement entered into in connection with our strategic alliance related to our Qinnan Block with Arrow, subject to certain conditions precedent including most notably approval by appropriate Chinese governmental authorities, we will assign 75.25% of our participating interest in the Qinnan PSC to Arrow.  For additional information on the strategic alliance, see "Strategic Alliance with Arrow" below.  CNPC has replaced CUCBM as our Chinese partner company in the Qinnan PSC.  We are in discussions with CNPC regarding the extension of the exploration period, which expired on June 30, 2009. For many months CNPC has been awaiting authorization from the Chinese government allowing it to deal with foreign partners on CBM projects. On March 7, 2010, several major news outlets reported that CNPC stated that it has been authorized to jointly develop coalbed methane projects with foreign partners, but we have not yet obtained official confirmation of this.  There can be no assurance that CNPC will approve an extension of the exploration period or approve the Farmout Agreement with A rrow.

As with any energy exploration and production company, we continuously review our acreage holdings in order to optimize those holdings.  We may, from time to time and as circumstances dictate, decide to relinquish all or part of any of our blocks that we deem non-prospective or sub-optimal in order to optimize our acreage holdings and/or preserve cash resources.

Our Holdings in the Shanxi Province of the People's Republic of China

Overview.  In June 2003, we entered into two amendments to certain farmout agreements and assignment agreements with Phillips China, Inc., a subsidiary of ConocoPhillips ("Phillips"), pursuant to which we acquired a 40% net undivided interest from Phillips in the Shouyang and Qinnan PSCs between Phillips and CUCBM for Shanxi Province ("Shanxi Agreements"). The assignment agreements and related amendments to the farmout agreements substituted us for Phillips as the principal party and operator for the projects under the PSCs. These agreements were approved by CUCBM on March 15, 2004, and ratified by the PRC Ministry of Commerce ("MOC") on March 22, 2004.  The term of each of the Shanxi Agreements consists of an exploration period, a development period and a production period.  The exploration period is divided into three phases called Phase I, Phase II and Phase III. We have completed our Phase I and Phase II obligations under the Shanxi Agreements, and

 
elected to enter into Phase III.  We are the operator and are responsible for all exploration costs related to the Shanxi Agreements, including all exploration costs for discovering and evaluating CBM-bearing areas.

After the exploration period we may elect to proceed to develop a given area (a "CBM Field") in accordance with the PSCs. After the approval and implementation of a pilot test program in the CBM Field, the parties to the PSC will jointly determine whether the field can be commercially developed. The development period as to any CBM Field in the Shanxi Province will begin after the approval of an overall development program ("ODP") for any such CBM Field. If any CBM Field is discovered within the area subject to the Shanxi Agreements, our Chinese partner company will be deemed to hold a 30% participating interest in such field and we will be deemed to have a 70% participating interest, unless the Chinese partner company elects to participate at a lower level, in which case we will retain all participating interests not taken by the Chinese partner company and shall be responsible for development costs associated therewith.  Pursuant to the farmout agreements with Phillips, Phillips retained a participation interest of 30% with a right to convert such interest into an overriding royalty interest. Upon our election to enter Phase III of the exploration periods in the Shanxi Agreements, Phillips elected to convey its remaining 30% participating interest to us and to receive an overriding royalty interest of 5% of our participating interest (making our maximum participating interest, subject to the Farmout Agreement, in each discovery 70%) or a maximum net overriding interest of 3.5% overall.  Therefore, depending upon whether and to what extent the Chinese partner company elects to participate in a given discovery, our interest in the Shouyang PSC will range from 66.5% (assuming full participation by the Chinese partner company) to 96.5% (assuming the Chinese partner company chooses not to participate).  The production period as to any CBM Field in the Shanxi Province project will begin after the date of commencement of commercial production of that CBM Field. Provided the Company remains in compliance with the requirements under the PSCs, the Shanxi Agreements allow production to continue on a CBM Field until the earlier of the end of the useful life of the field or July 1, 2032, unless extended or otherwise amended.

We have fulfilled our obligations under the exploration period of the Shanxi Agreements for the three phases.  The two agreements have historically been treated interdependently in certain respects.  In particular, the Phase II and III obligation to complete 12,000 meters of horizontal drilling in coal seam could be achieved by combining Phase II and Phase III drilling in the two separate blocks.  We fully satisfied the horizontal drilling obligation by the first quarter of 2009.  In the future, this interdependence is likely to change pursuant to CUCBM’s conveyance to CNPC of its interest in the Qinnan block.

Our obligations and results for the three phases during the exploration period of our PSC with CUCBM are summarized below:

Phase I. We have completed our Phase I obligations under both PSCs under the Shanxi Agreements. Phase I obligated us, at our expense, to perform a hydraulic fracture of one of three exploration wells previously drilled by Phillips by January 31, 2005. In September 2004, the hydraulic fracture and testing was completed on the QN-002 well drilled previously by Phillips on its acreage in the Qinnan Block located in the Shanxi Province. The testing was performed on the coal seam at a depth of approximately 550 meters (1,880 feet), with an objective of gaining information on the permeability of that coal seam and completing our obligations for Phase I under the Shanxi Agreements.

Phase II.  We completed our Phase II obligations under both PSCs for Shanxi Province by drilling and completing two horizontal wells in the Shouyang Block prior to March 31, 2006.  We also completed a third horizontal well under Phase II.  These wells are currently being dewatered.

Phase III. After completion of Phase II, we elected to commit to Phase III of the Shanxi PSCs.  Our work commitment to complete Phase III consists of furthering the horizontal drilling in the coal seam that we began in Phase II to a total of 12,000 meters. This work obligation could be met by combining the drilling results in the Shouyang and Qinnan Blocks.  We fully satisfied the horizontal drilling obligation by the first quarter of 2009.


Chinese Party to the PSCs. Until recently, CUCBM was our partner in both the Shouyang and Qinnan PSCs.  CUCBM was a joint venture of China National Coal Group Corp and CNPC.  CNPC recently withdrew from the joint venture and has apparently replaced CUCBM as our Chinese partner company for the Qinnan PSC.  However, both CNPC and CUCBM informed us in 2009 that CNPC had not yet been granted authority by the Chinese government to jointly develop CBM projects with foreign partners.  For many months CNPC has been awaiting authorization from the Chinese government allowing it to deal with foreign partners on CBM projects. On March 7, 2010, several major news outlets reported that CNPC stated that it has been authorized to jointly develop coalbed methane projects with foreign partners, but we have not yet obtained official confirmation of this.  We have begun working with CNPC on various matters concerning the Qinnan PSC including the preparation for the next joint management committee (the "JMC") meeting and the extension of the current exploration phase.  CUCBM is the Chinese party to the Shouyang PSC.  Throughout this Annual Report on Form 10-K, we use the term "our Chinese partner company" when referring to either CUCBM or CNPC, as applicable.

Shouyang PSC.  During the third quarter of 2009, the MOC approved a modification agreement (the "2009 Shouyang PSC Modification Agreement"), which among other provisions, extended Phase III of the exploration period to June 30, 2011 from June 30, 2009.

The 1H Pilot Area of the Shouyang Block is being closely monitored and work programs are being carried out there to achieve three primary goals: (i) to enlarge our pilot area and continue to expand the area in our 1H Pilot Area where critical desorption and gas production have begun to occur thereby increasing gas production, (ii) to add step out wells that will help delineate the geographic extent of the high permeability and high gas content area and, (iii) to determine the optimal approach to minimize costs and maximize gas recovery.  To reach these goals, we drilled six horizontal wells, twelve vertical wells, six deviated wells and three parameter wells by the end of fall 2009.

The deviated wells represent another phase in the process of reducing costs.  These are essentially vertical wells drilled at a very high angle from an existing well pad and location. Utilizing an existing well location allows more than one well to be drilled from the same pad, consequently reducing land and pad construction costs, as well as reducing environmental impact.  Once drilled to the coal seam, the wells were fracture stimulated.  We have gained insights over time as to situations where cavitation or hydraulic fracture stimulation may improve our dewatering efficiency in the pilot area.  Hydraulic fracturing is a stimulation method successfully used in other gas shale and coalbed reservoirs to improve wellbore productivity by providing channels that extend beyond any formation damage done to the wellbore during the drilling process.  This allows for water and gas to more easily flow into the wellbore and then be produced.  

In December 2009, we commenced a winter drilling program at the Shouyang Block to drill eight new wells. We plan to complete the winter drilling program and drilling of three additional new wells by early April, thus fully utilizing the five rigs available to us, and bringing the number of completed wells to ten by April.  Of these eleven wells, nine are program wells drilled in the 1H Pilot Area to expand the field to the west and increase the amount of gas being produced to commercial levels in the second half of 2010; while two are parameter wells drilled several kilometers to the west and southwest to obtain further information regarding the geographic extent of the high permeability/high gas content area.
 
Current plans call for those rigs to commence five more wells in April and early May, and three more in early June with the emphasis increasingly shifting to drilling parameter wells at four to six kilometer intervals to the west, south, and east with the goal of demonstrating that there is a very large area of the Shouyang Block that contains high gas content as well as good permeability characteristics. Of the five wells to be spudded in April and early May, four will be parameter wells seeking to show that much of the northern area of the Shouyang Block shares the same rare combination of high permeability and high gas content discovered in the 1H Pilot Area.  The three wells planned to be commenced in June will also be parameter wells.


In summary, our plan is to include the following in our drilling programs in the near future:

 
·
Finish the winter drilling program by April – eleven wells (nine in the 1H Pilot Area and two parameter wells to the west and southwest of the 1H Pilot Area);
 
·
April and early May – five wells, four of which are parameter wells; and
 
·
Early June – three wells, all parameter wells.

It is rare to find high permeability and high gas content together in the same coal.  The San Juan Basin, generally accorded the title of the most prolifically producing CBM basin in the world, is perhaps the classic example of what can happen when high permeability and high gas content are found in combination along with synergistic geologic and hydrologic controls.  While we believe that our Shouyang Block demonstrates permeability and gas content characteristics similar to previously successful CBM fields, there can be no assurance that the Shouyang  Block will experience similar results.

To date, the 1H Pilot wells, as well as the parameter wells drilled at intervals of four to six kilometers to the south and to the west of the 1H Pilot Area have revealed permeability ranging from 10 to 80 millidarcies.  Permeability in the 2H area, about seven kilometers south of the 1H Pilot Area, appears to be around 60 millidarcies.  In the area surrounding the P2 well, about six kilometers west of the 1H Pilot Area, the permeability appears to be between 10 and 20 millidarcies; while in the area surrounding the P3 well, about six kilometers southwest of the 1H Pilot Area, the permeability appears to be about 10 to 15 millidarcies.  This range of permeability compares favorably with a number of successful CBM fields.  With permeabilities ranging from areas of 10 to 80 millidarcies, the Shouyang Block seems to have  an area of high permeability coupled with high gas.

The Company also plans to conduct four fracture stimulation programs over the next five months:

 
·
Beginning mid-March - twelve wells;
 
·
April - seven wells, including three in the 1H Pilot area;
 
·
June - three wells; and
 
·
July - probably four wells.

All of these wells will be fractured using the improved methods learned by FEEC during its 2009 Work Program, which included using resin-coated sand as a propping agent to improve the stability and durability of the fractured area.  The Company also announced that the remaining wells should be spudded during the winter program shortly after the Chinese New Year holiday and the final fracture process is scheduled to be completed to finish the work on the winter drilling and testing program by the end of April.  The Company plans for each of the wells being drilled and fractured to  be completed and for the dewatering to begin immediately thereafter.

Far East has obtained the initial results of the production capacity tests on the Number 9 coal seam for four wells. It is too early to be able to predict the total gas production capacity of these wells in the Number 9 coal seam but it does appear that compared with the Number 15 coal seam in the 1H Pilot Area, the Number  9 coal seam has a higher gas saturation level, which could allow the Company to produce CBM from that coal seam  with a shorter dewatering period than has been necessary in the Number 15 coal seam.

Instead of continuing to flare the current gas production, Far East believes it could initiate gas sales as early as the third quarter of 2010.  We are in discussions with three separate parties (two pipelines and one CNG company) regarding the potential off-take and sale of gas produced from the 1H Pilot Area.   The two pipeline companies are planning to lay lines approximately 18 inches in diameter near the Shouyang Area.  One of the pipeline companies recently stated that it would consider slightly re-routing its line to come to within approximately two kilometers of Far East’s 1H Pilot Area, with  that company's pipeline expected to be completed by July or August.   That pipeline is being built to take gas off of the Shanjing II pipeline that runs from Western China to Beijing and to move that gas towards the provincial capital of Shanxi Province. Its route was already planned to pass within five to seven kilometers of the 1H Pilot Area.  Additionally, the pipeline company has stated that it does not intend to require that Far East guarantee volumes of gas.  Normally, in order to induce a pipeline to build to a producing area, the producer must guarantee that a certain volume of gas will be available to the pipeline.

 
Qinnan PSC.  Phase III of the exploration period under the Qinnan PSC expired on June 30, 2009.  We have had discussions with CNPC regarding the extension of the exploration period.  At CNPC's request, we have provided certain operational and financial information about our Company to assist them in the decision making process.  Recently, CNPC has completed an accounting audit pursuant to the Qinnan PSC of our expenditures for 2007 and 2008.  We have also provided to CNPC at their request our work plan for 2010 for Qinnan. There can be no assurance that we will be successful in extending the Qinnan PSC.  For many months CNPC has been awaiting authorization from the Chinese government allowing it to deal with foreign partners on CBM projects. On March 7, 2010, several major news outlets reported that CNPC stated that it has been authorized to jointly develop coalbed methane projects with foreign partners, but we have not yet obtained official confirmation of this.  There can be no assurance that CNPC will approve an extension of the exploration period or approve the Farmout Agreement with Arrow.  Future work program at the Qinnan Block depends largely on whether the exploration period of the Qinnan PSC will be extended as well as whether the necessary Chinese government approvals will be obtained for the Farmout Agreement (defined below) with Arrow.

In 2006, we acquired and processed 26 kilometers of 2D seismic data in the Qinnan Block.  We also obtained test data from a vertical well we drilled in December 2006.  We have utilized the well data and the 2D seismic data in the planning for future wells.  During 2008, we completed the drilling of our first horizontal well in the area, with 3,000 meters drilled in the Number 3 coal seam.   The Number 3 coal seam is the object of development by other parties in the area near the southern end of Shanxi Province.  Our testing of the well to-date has demonstrated that the coal seam has low permeability of approximately one to two millidarcies, which we expected, and that the wellbore formation has been damaged during the drilling process.  Subject to the extension of the PSC and approval of the Farmout Agreement, we intend to continue to test the well through measured water and gas production.

To expand our exploration effort and understanding of the potential of the Qinnan Block, in the third quarter of 2008, we successfully drilled three of four planned parameter wells on the southern end of the Qinnan Block to test the coal seams for permeability, reservoir pressure, coal thickness and gas content.  Although it is still early in the core analyses for gas content, based on preliminary results, we believe that three of the four wells have demonstrated high gas content of 300 to 500 standard cubic feet of natural gas per ton of coal.  These measurements are similar to those obtained from previous testing of wells on the Qinnan Block.  The tests of the three parameter wells have provided valuable information on the continuity of the coal seam on the southern end of the Qinnan Block.  We plan to use the information gathered in discussions with our Chinese partner company when determining the size of any potential ODP for the area.  The fourth well failed to find coal seams sufficiently thick to be prospective and was plugged and abandoned.  We also completed drilling operations in early 2009 on an additional horizontal well in the Qinnan area.  This well is designed to begin appraising the area around one of the parameter wells drilled in 2008.

On March 13, 2009, we formed a strategic alliance related to our Qinnan Block with Arrow and entered into a farmout agreement (the "Farmout Agreement") under which, subject to certain conditions including securing approval from our Chinese partners and the MOC, our wholly-owned subsidiary, Far East Energy (Bermuda), Ltd. ("FEEB") will assign to Arrow 75.25% of its rights in the Qinnan PSC in the Shanxi Province.  For additional information on the strategic alliance, see "Strategic Alliance with Arrow" below.

    If the farmout of a portion of our interest in the Qinnan PSC is approved by our Chinese partners and the MOC and other conditions precedent are met, Arrow will become the operator under our Qinnan PSC and costs under the PSC will be allocated as discussed under "Strategic Alliance with Arrow."  Assuming that we successfully assign the 75.25% interest in the Qinnan PSC to Arrow, depending upon whether and to what extent the Chinese partner company elects to participate in a given discovery, our interest in the Qinnan PSC will range from 16.5% (assuming full participation by the Chinese partner company) to 23.9% (assuming the Chinese partner company chooses not to participate).  We note that, under the Farmout Agreement, Arrow will fund all exploration costs associated with the Qinnan PSC up to a maximum of $30 million.  After Arrow reaches such $30 million cap, FEEB and Arrow will share further Qinnan area exploration costs in proportion to their participating interests in the Qinnan PSC, provided that FEEB may, in its discretion, instead elect to assign all of its interest in the Qinnan PSC to Arrow subject to retaining a 2% overriding royalty interest.


Any ODP will be developed and filed jointly by us, our Chinese partner company and, if the farmout to Arrow is successful, with respect to the Qinnan PSC, Arrow, and will be submitted to Chinese governmental authorities for approval.  Under the Farmout Agreement, if we obtain Chinese governmental approval of an ODP for the Qinnan area, Arrow will pay FEEB an additional $8 million in cash as a bonus, and FEEB will have the option to assign all of its interest in the Qinnan PSC to Arrow, while retaining a 5% overriding royalty interest.

Minimum Exploration Expenditure.  Under the PSCs, we have committed to satisfy certain annual minimum exploration expenditure requirements for each PSC.  Our minimum exploration expenditure requirement for each block is based on the minimum exploration expenditure requirements of CUCBM established by the Ministry of Land and Resources ("MLR").  The MLR sets its requirements by applying a minimum expenditure per acre to the total acreage encompassed by each PSC.  The annual minimum exploration expenditure requirement is approximately $2.9 million and $3.4 million, respectively, for the Shouyang PSC and the Qinnan PSC, based on the currency exchange rate between the U.S. Dollar and the Chinese Renminbi ("RMB") as of December 31, 2009.  For 2009, our exploration expenditure at the Shouyang Block exceeded minimum requirement. Pursuant to the 2009 Shouyang PSC Modification Agreement, the portion of the exploration expenditures which exceeds the current year's minimum exploration expenditure requirement can no longer be carried forward toward the satisfaction of the subsequent year's minimum requirement.  These expenditure requirements are denominated in RMB and therefore, are subject to fluctuations in the currency exchange rate between the U.S. Dollar and the Chinese RMB. Assuming that we obtain approval from our Chinese partner company and the MOC, and satisfy the other conditions under the Farmout Agreement with Arrow, then the additional payment due upon the occurrence of these events from Arrow together with funds currently available should provide sufficient working capital to meet our currently planned work programs through 2010.  Our current work programs would satisfy the minimum exploration expenditures for all three of our PSCs for 2010.  The MLR minimum expenditure requirements are a significant factor that influences our exploration work program.

Related Payments. Under the PSCs, we are required to make the following yearly payments to our Chinese partner companies.  As indicated below, certain amounts may change from year to year.

   
Shouyang PSC
    
Qinnan PSC
  
Exploration Period
            
Salary and Benefit
            
2009
   $ 162,200     $ 143,100  
2010
     195,900 (1)     143,100 (2)
Exploration Permit Fee
                
2009
     140,136       165,529  
2010
     143,622       169,693 (2)
Training Fee
     60,000       60,000  
Assistance Fee
     50,000       50,000  
                 
Development & Production Period
                
Signature Fee (3)
     150,000       150,000  
Training Fee
     150,000       150,000  
Assistance Fee
     120,000       120,000  
 
(1) The increase from 2009 to 2010 is due to the increase of standard amount of the CUCBM's professionals’ salary and benefit under the amended Shouyang PSC. The salary and benefits for CUCBM professionals during the development and production periods is to be determined by negotiation with CUCBM.
(2) The increase from 2009 to 2010 is due to the phaseout of a discount on exploration permit fee pursuant to MLR’s regulations.
(3) Due within 30 days after first approval of the ODP following the exploration period.


Our Holdings in the Yunnan Province of the People's Republic of China

Overview.  On January 25, 2002, we entered into a PSC (the "Yunnan PSC") with CUCBM to develop two areas in Yunnan Province: (1) the Enhong area, which covers approximately 145,198 acres and (2) the Laochang area, which covers approximately 119,772 acres). We are the operator under the PSC. The term of the Yunnan PSC consists of an exploration period, a development period and a production period. The exploration period is divided into two phases, Phase I and Phase II.  We have completed Phase I and have elected to enter into Phase II.  During the third quarter of 2009, the MOC approved a modification agreement (the "2009 Yunnan PSC Modification Agreement"), which among other provisions, extended Phase II of the exploration period to June 30, 2011 from June 30, 2009. Following completion of Phase II of the exploration period, we may elect to continue the PSC and conduct development and production operations on any CBM discoveries. After the exploration period, the development period as to any CBM Field in the Enhong-Laochang project will begin after the approval of an ODP for any such CBM Field.  An ODP would be developed and filed jointly by us and CUCBM, seeking approval from Chinese governmental authorities, for any CBM Field the Company and CUCBM elect to develop. The production period as to any CBM Field in the Enhong-Laochang project will begin after the date of commencement of commercial production of that CBM Field. Provided that the Company remains in compliance with the requirements under the Yunnan PSC, production will be allowed to continue on a CBM Field until the earlier of the end of the useful life of the field or January 1, 2033, unless extended or otherwise amended.

We are the operator and are responsible for all exploration costs related to the Yunnan PSC, including all exploration costs for discovering and evaluating CBM-bearing areas.  If any CBM Field is discovered within the contract area, CUCBM will be deemed to hold a 40% participating interest in such field and we will be deemed to have a 60% participating interest, unless CUCBM elects to participate at a lower level, in which case we will retain all participating interests not taken by CUCBM and shall be responsible for development costs associated therewith.

Because there are no pipelines currently in the vicinity of our Yunnan Province projects, our ability to sell CBM produced on these projects to communities outside the general area will be contingent upon a gas pipeline, CNG facility or other off-take vehicle being built close to our project area.  We estimate the initial cost to construct a connecting pipeline and compression facilities from our project area to the nearest large cities, Qujing and Kunming, may be in the range of $20 million to $50 million or more.  Recently, it was reported that CNPC will undertake a pipeline construction project with supports from the Yunnan provincial government to extend the Myanmar-China natural gas pipeline to pass through the city of Kunming, then go northward through the city of Zhaotong, and finally connect with major interprovincial pipelines in Sichuan Province. Further, the pipeline plans are expected to include a branch to connect Kunming to Qujing.  We believe that the construction, which would lay pipelines closer to our projects, would  help reduce the cost for CBM off-take from our projects and increase our ability to eventually deliver gas to consumers.  If CUCBM elects a 40% participating interest in Yunnan Province project, our costs would be reduced accordingly.

Currently, we are conducting a strategic review of our Yunnan holdings to determine whether they fit within our risk profile given the tight capital markets and general economic downturn.  We take into consideration, among other factors, our overall corporate strategy, the prospective costs and benefits of the acreage, our relationship with our Chinese partner companies and our current cash position in order to formulate an optimal strategy for the Company.  The strategy may include, but not be limited to: (i) minimal capital spending to continue holding the acreage, (ii) sale, farm-out or partial farm-out of the acreage, (iii) full or partial relinquishment of the acreage, or (iv) continued staged exploration of the acreage. We have not yet concluded this review and cannot make any projection as to the likely outcome of this review.  Moreover, CUCBM will have its own view and certain outcomes will be subject to CUCBM and MOC approval.

Our Phase I and Phase II obligations and results during the exploration period of our PSC with CUCBM are summarized below.

Phase I.  We completed our Phase I obligations under the Yunnan PSC. We drilled and completed three wells on the project, performed a hydraulic fracture and tested one of these three wells.  We believe the three wells have yielded favorable gas content results.  We also conducted geological data gathering, shot 2D seismic data for 10 kilometers in the Enhong area, drilled one slim hole vertical well in the Enhong area and one slim hole vertical well in the Laochang area with desorption and standard CBM laboratory analysis.

 
Phase II.  On February 23, 2005, we elected to enter into Phase II under our Yunnan PSC, which required us to drill at least one horizontal well with a minimum of two laterals.   To continue our preparation for the drilling of the horizontal well and future development of this field, we continued our geological and geophysical activities and drilled four slim hole vertical wells to gain more data and to enhance our understanding of structure complexity, coal lateral continuity, coal properties and reservoir characteristics.  Based on the data gathered from these wells and other wells drilled by the Chinese coal industry, we drilled a cluster of four deviated wells to stimulate and test-produce the Number 7, 8, 13 and 19 coal seams in 2008. These wells were drilled diagonally from the same surface location as an existing vertical well to provide a close pattern of five wells to test the coal seams.  This pattern allows us to optimize well spacing and reduce the cost of road/pad construction and land use.  We believe this will prove to be an optimal method of developing a CBM Field in mountainous terrain.  As a result of our testing, we anticipate that these coal seams will have low permeability and that we will need to fracture multiple zones to fully test these wells.  The outcome of our strategic review discussed above will determine the future plan for these wells and the acreage.

Minimum Exploration Expenditure.  Under the Yunnan PSC, we have committed to satisfy certain annual minimum exploration expenditure requirements.  Our minimum exploration expenditure requirements for the blocks subject to the PSC are based on the minimum exploration expenditure requirements of CUCBM established by the MLR.  The MLR sets its requirements by applying a minimum expenditure per acre to the total acreage encompassed by the PSC.  The annual minimum exploration expenditure requirement is approximately $1.6 million, based on the currency exchange rate between the U.S. Dollar and the Chinese RMB as of December 31, 2009.  Pursuant to the 2009 Yunnan PSC Modification Agreement, the portion of the exploration expenditures which exceeds the current year's minimum exploration expenditure requirement can no longer be carried forward toward the satisfaction of the subsequent year's minimum requirement.  Our 2009 exploration expenditure and the cumulative amount carried forward from 2008 amounted to approximately $1.5 million. Therefore we were approximately $0.1 million short of the requirement.  The shortage will be discussed in the next Joint Management Committee meeting currently scheduled in late March.  Based on previous experience and the shortage being immaterial, we are hopeful that permission will be granted from CUCBM to add the underage to the 2010 requirement.  These requirements are denominated in the RMB, and therefore, are subject to fluctuations in the currency exchange rate between the U.S. Dollar and the Chinese RMB.  The MLR minimum expenditure requirements are a significant factor that influences the Company's exploration work program.

Related Payments.  Pursuant to the terms of the Yunnan PSC, we have paid CUCBM signature fees totaling $350,000.  Under the PSC, we are required to make certain payments to CUCBM, including: (1) CUCBM assistance fees for Chinese personnel totaling $45,000 per year during the exploration phase and $80,000 per year during the development and production periods; (2) training fees for Chinese personnel working on the projects of $45,000 per year during the exploration period and $80,000 per year during the development and production periods; (3) reimbursement to CUCBM for government-imposed fees for CBM exploration rights during the exploration period, which were $74,000 in 2009 and are estimated to be approximately $79,000 in 2010, and in proportion to our participating interest in the development and production periods; and (4) salary and benefits paid to CUCBM professionals during the exploration period, which was approximately $210,000 in 2009 and are estimated to be approximately $257,000 in 2010.  This increase is due to the increase of standard amount of CUCBM’s professionals salary and benefit under the extended Yunnan PSC.  The allocation of salary and benefits for CUCBM professionals during the development and production periods are to be determined by negotiation with CUCBM.

Strategic Alliance with Arrow

On March 13, 2009, the Company and FEEB formed a strategic alliance related to our Qinnan Block with Arrow, the Singapore-based subsidiary of Arrow Energy Limited.  Specifically, on that date, (i) FEEB and Arrow entered into the Farmout Agreement  under which, subject to certain conditions, FEEB will assign to Arrow 75.25% of its rights (the "Assignment") in the Qinnan PSC, (ii) the Company, FEEB and Arrow entered into a Securities Purchase Agreement (the "Purchase Agreement"), (iii) FEEB issued an Exchangeable Note, $10 million principal amount (the "Exchangeable Note"), to Arrow for $10 million in cash, (iv) the Company issued a Warrant (the "Warrant") to Arrow for 7,420,000 shares of the Company's common stock, par value $0.001 per share (the "Common Stock"), at an exercise price of $1.00 per share, and (v) the Company and Arrow entered into a

 
Registration Rights Agreement (the "Registration Rights Agreement" and, collectively with the other agreements described in the preceding clauses (i) through (iv), the "Agreements").

Farmout Agreement.  The Farmout Agreement conditions the Assignment on, among other things, the receipt of required approvals from the government of the PRC (collectively, the "Farm-In Conditions") on or prior to October 15, 2009 or such later date as the parties may agree upon (the "Farm-In Deadline").  The terms of the Farmout Agreement were subsequently amended in October 2009 and then again in November 2009.  The October 2009 amendment changed the Farm-In Deadline to November 20, 2009.  The November 2009 amendment provided, among other things, further changed the Farm-In Deadline to December 19, 2009.  In conjunction with the November 2009 amendment, FEEB and Arrow also agreed that interest on the Exchangeable Note would begin to accrue as originally scheduled on October 16, 2009.  Since December 19, 2009, each of the Company and Arrow have had the right to terminate the Farmout Agreement at any time, though neither party has elected to exercise that right and the parties are continuing to use efforts to satisfy the conditions contemplated by the Farmout Agreement.  There can be no assurance that our Chinese partners or the MOC will approve the Farmout Agreement.  The parties are required to exercise their respective commercially reasonable efforts in good faith to satisfy the Farm-In Conditions.  Under the current Farmout Agreement, upon satisfaction of the Farm-In Conditions, Arrow will make an initial payment to the Company of $8 million, and, subject to certain conditions, including government approval for the extension of the current exploration period, Arrow will fund all exploration costs associated with the Qinnan PSC up to a maximum of $30 million.  After Arrow reaches such $30 million cap, FEEB and Arrow will share further Qinnan area exploration costs in proportion to their participating interests in the Qinnan PSC, provided that FEEB may, in its discretion, instead elect to assign all of its interest in the Qinnan PSC to Arrow subject to retaining a 2% overriding royalty interest.  In addition, under the Farmout Agreement, if the parties obtain Chinese governmental approval of an ODP for the Qinnan area, Arrow will pay FEEB an additional $8 million in cash as a bonus, and FEEB will have the option to assign all of its interest in the Qinnan PSC to Arrow, while retaining a 5% overriding royalty interest.  If an overall development program is approved, then FEEB and Arrow will share related development costs and any future revenues for such area on a pro-rata basis in accordance with their participating interests in the Qinnan PSC.  If our Chinese partner or the MOC does not approve the agreement in an expedient manner, the parties may seek to modify certain terms of the Farmout Agreement.

As discussed above, if the Farm-In Conditions are not satisfied prior to the Farm-In Deadline, then either party has the right to terminate the Farmout Agreement by delivering notice of such termination to the other party.  In addition to the foregoing, the Farmout Agreement contains certain customary representations, warranties and covenants of the parties.  Further, if certain events of default occur, then FEEB will be entitled to exercise rights to revoke the Assignment and the Farmout Agreement will automatically terminate.

Purchase Agreement.  Under the Purchase Agreement, FEEB issued Arrow the Exchangeable Note, the Company issued Arrow the Warrant and Arrow paid FEEB $10 million in cash.

Exchangeable Note.  The Exchangeable Note has an initial principal amount of $10 million and bears interest at a rate of 8% per annum, which began to accrue on October 16, 2009 and matures  on March 13, 2011 (the "Maturity Date"), unless repaid earlier.  Principal and interest are due and payable on the Maturity Date or earlier if payment is accelerated upon the occurrence and continuance of an event of default (addressed below).

Arrow has the right at any time to exchange the Exchangeable Note in whole or in part for shares of Common Stock at an exchange rate of 21,052.63 shares per $10,000 (or $0.475 per share) of principal and interest (the "Exchange Rate"), subject to certain equitable adjustment mechanisms in the event of a sale of the Company, stock split or similar occurrence.  However, if certain conditions to the effectiveness of the Assignment are satisfied on or before the Farm-In Deadline, the entire principal amount of the Exchangeable Note will automatically be exchanged for shares of Common Stock at the Exchange Rate, subject to the same adjustment mechanisms.

The Exchangeable Note contains certain restrictive covenants applicable to the Company and FEEB, including, among others, restrictions on the incurrence of indebtedness that ranks senior to or pari passu with the Exchangeable Note and restrictions on FEEB's ability to sell all of its rights under Shouyang PSC.  The Company has guaranteed FEEB's payment obligations under the Exchangeable Note.

 
An event of default will occur under the Exchangeable Note if at any time (i) the Company fails to issue the required shares of Common Stock upon exchange of the Note, (ii) FEEB sells all of its rights under the Shouyang PSC, (iii) any of the Company and its subsidiaries incurs indebtedness that is not subordinated to FEEB's obligations under the Exchangeable Note, (iv) FEEB declares bankruptcy, (v) the Company and its subsidiaries, taken as a whole, cease to carry on all or substantially all of their business or (vi) it becomes unlawful for the Company and FEEB to carry out their material obligations under the Exchangeable Note.  In addition, after the Farm-In Deadline, additional circumstances may trigger an event of default under the Exchangeable Note, including, subject to specified qualifications and limitations, if (i) either the Company or FEEB does not comply with its obligations under the Exchangeable Note or the Securities Purchase Agreement, (ii) any judgment in excess of $1 million is rendered against the Company or any of its subsidiaries and remains undischarged or unvacated for 30 days, (iii) any of the Company and its subsidiaries fails to make any payments on indebtedness, or any of their indebtedness is accelerated, where the amount unpaid or accelerated, as applicable, exceeds $500,000, or (iv) any required governmental or other approvals necessary to maintain the validity of the Exchangeable Note, or allow the Company or FEEB to perform its obligations thereunder, ceases to be in effect.  Under the Exchangeable Note, in certain cases, the Company or FEEB, as applicable, is entitled to notice of a circumstance that may become an event of default and an opportunity to cure the default before it becomes an event of default.  Upon the occurrence of an event of default, Arrow may declare all amounts outstanding under the Exchangeable Note immediately due and payable.

Warrant.  The Warrant entitles Arrow to purchase 7,420,000 shares of Common Stock at an exercise price of $1.00 per share, subject to certain equitable adjustment mechanisms in the event of a sale of the Company, stock split or similar occurrence.  The Warrant expired in December 2009.

Registration Rights Agreement.  The Registration Rights Agreement required the Company to file a registration statement on or prior to June 11, 2009 on Form S-1 or, if available to the Company, Form S-3 to register the shares issuable upon exercise of the Warrant and upon exchange of the Exchangeable Note (the "Registrable Securities").  The Company filed a Registration Statement on Form S-1 covering the Registrable Securities on June 11, 2009 and the registration statement was declared effective on June 22, 2009.  The Company also agreed to keep the registration statement effective with respect to the Registrable Securities for up to two years.

Marketing and Transportation of Our CBM in China

The marketability of any gas production will depend, in part, upon the availability, proximity and capacity of pipelines, gas gathering systems and processing facilities and upon reaching an agreement with an authorized entity which may include our Chinese partner company. Our preliminary marketing feasibility studies indicate that we should be able to transport our CBM through pipelines or by compressing the CBM for transportation. CBM projects traditionally require multiple wells to properly dewater the coal and generate predictable volumes of gas.

Pipelines in Shanxi Province.  Currently, two national trunklines, one to Beijing and one to Shanghai, traverse China in proximity to our Shanxi Province projects.  However, we are in discussions with three separate third parties (two pipelines and one CNG company) regarding the potential off-take and sale of any commercial quantities of gas that may be produced from the 1H Pilot Area.  Far East believes that, subject to reaching an agreement regarding off-take and commercial quantities of gas being produced, it could initiate gas sales as early as the third quarter of 2010. The two pipeline companies are planning to lay lines approximately 18 inches in diameter near the Shouyang Area.  One of the pipeline companies recently stated that it would consider slightly re-routing its line to come to within approximately two kilometers of Far East’s 1H Pilot Area, with that company's pipeline expected to be completed by July or August.   That pipeline is being built to take gas off of the Shanjing II pipeline that runs from Western China to Beijing and to move that gas towards the provincial capital of Shanxi Province. Its route was already planned to pass within five to seven kilometers of the 1H Pilot Area.  Additionally, the pipeline company has stated that it does not intend to require that Far East guarantee volumes of gas.  Normally, in order to induce a pipeline to build to a producing area, the producer must guarantee that a certain volume of gas will be available to the pipeline.  If our discussions with the three separate third parties do not result in any commercially viable arrangement and in the absence of any similar arrangement with other companies, pipelines may need to be built on those projects to connect to larger pipelines to transport any CBM that may be produced from those projects.  We estimate the initial cost for these connecting pipelines and compression facilities may be in the range of $10 million to $20 million or more.  If CUCBM elects a 30% participating interest in our Shanxi Province project, our net costs

 
would be reduced accordingly.  Additionally, if we are successful in assigning 75.25% of our current participating interest in the Qinnan PSC to Arrow, our net cost with respect to any project for that PSC would be reduced accordingly.  There is no assurance that any of the existing pipelines we might desire to connect to in the future will have sufficient capacity available to meet our requirements or the costs of using such pipelines would be economical.  Additionally, there is no assurance that we will be able to use the existing pipeline on terms acceptable to us or at all, as the PRC does not require that open access to pipeline infrastructure be allowed.

Pipelines in Yunnan Province.  Because there are no pipelines currently in the vicinity of our Yunnan Province projects, our ability to sell CBM produced on these projects to communities outside the general area will be contingent upon a gas pipeline, CNG facility or other off-take vehicle to be built close by our project area.  We estimate the initial cost to construct a connecting pipeline and compression facilities from our project area to the nearest large cities, Qujing and Kunming, may be in the range of $20 million to $50 million or more.

Recently, it is reported that CNPC will undertake a pipeline construction project with  supports from the Yunnan provincial government to extend the Myanmar-China natural gas pipeline to pass through the city of Kunming, then go northward through the city of Zhaotong, and finally connect with major interprovincial pipelines in Sichuan Province. Further, the pipeline plans are expected to include a branch to connect the city of Kunming to the city Qujing.  We believe that the construction, which would lay pipelines closer to our projects, would help reduce the cost for CBM  off-take from our projects and increase our ability to eventually deliver gas  to  consumers.  If CUCBM elects a 40% participating interest in Yunnan Province project, our costs would be reduced accordingly.  However, there can be no assurances that this project will be undertaken or be completed or, if it is undertaken, that it will be completed on a timely basis.  Additionally, there is no assurance that we will be able to use the pipeline on terms acceptable to us or at all, as the PRC does not require that open access to pipeline infrastructure be allowed.

Compressed Natural Gas.  If we have initial commercial production of CBM from our Shanxi Province projects, then, prior to the point at which production reaches pipeline quantities, we could potentially begin to market the CBM produced to local markets as CNG.  CNG is an alternative to the construction of a pipeline and is especially appropriate for early stage gas production where gas volumes are lower.  Thus we may determine to pursue CNG facilities in order to earn revenues from any early production of CBM. Production of CNG would require the installation of a CNG facility, which would likely be constructed and paid for by the purchaser of our gas production.

CBM Natural Gas Pricing.  Unlike traditional natural gas produced in China, the market price of CBM natural gas is not regulated by the Chinese government.  Based on our research on the prevailing gas market conditions in China, we expect to receive market-driven, competitive pricing for our future gas production, regardless of whether we deliver our gas through a pipeline or in the form of CNG.  In addition to the fees described herein, upon commencing commercial sales of CBM, the PRC government will be entitled to certain royalties and taxes described in the PSCs.

Our Competition

The energy industry is highly competitive in all of its phases. Competition is particularly intense with respect to the acquisition of desirable producing properties, the acquisition of CBM prospects suitable for enhanced production efforts, the hiring of experienced personnel and the marketing of resources. Our competitors in CBM acquisition, development, and production include major integrated oil and gas companies and substantial independent energy companies, many of which possess greater financial and other resources.

Safety and Health Matters

We employ numerous safety precautions and emergency response plans designed specifically for our exploration activities in China to ensure the safety of our employees and independent contractors.  We have maintained a strong safety record which includes no lost-time accidents in the past 4.5 years-plus and no major environmental incidents.  We also conduct our operations in accordance with various laws and regulations concerning occupational safety and health.  As protection against operating hazards and environmental risks, we maintain insurance coverage against some, but not all, potential injuries and losses.  In addition, we require service providers we engage to maintain similar insurance coverage.

 
Regulations Impacting Our Business

Our operations will be subject to numerous laws and regulations governing the discharge of materials into the environment or otherwise relating to environmental protection. These laws and regulations require the acquisition of a permit before drilling commences; restrict the types, quantities and concentration of various substances that can be released into the environment in connection with drilling and production activities; limit or prohibit drilling activities on certain lands lying within wilderness, wetlands and other protected areas impose substantial liabilities for any pollution resulting from our operation and limit our discretion in marketing any production.

The exploration and production of CBM in China is regulated by and affected by the policies of multiple administrative bodies including the NDRC, the MOC, the MLR, CNPC and CUCBM.  The Mineral Resources Law and the related regulations are the primary source of law governing the exploration and production of coalbed methane in China.

The NDRC is responsible for the development and strategic upgrade of key industries in China, including the CBM industry.  Policy making decisions of the NDRC could, therefore, affect our company.  Additionally, the MOC has many policy setting functions and, through its Foreign Investment Administration (the "FIA"), the MOC is directly responsible for foreign investment in China.  Our PSCs and the subsequent amendments to those contracts were, and continue to be, subject to approval of the MOC.   Within the FIA, the Service Trade Division also regulates the public utilities in urban areas, various pipeline networks, transportation and CBM exploration and production and, therefore, the division's policies, rules and regulations could affect our future strategy and operations for transportation and distribution of any CBM production.

The rules and regulations of the MLR and, in particular, CUCBM more directly affect the CBM industry in China as well as our operations.  The MLR is the principal authority regulating the CBM industry in China.  It has authority over the designation of land for exploration, the approval of geological reserve reports, the review and granting of licenses for exploration and production and the administration of the registration and assignment of exploration and production licenses.  Presently, CUCBM has the right to partner with foreign investors in CBM activities.   As previously discussed, CNPC is in the process of trying to obtain the right to partner with foreign investors, and if successful, CNPC will become our partner on the Qinnan Block.  This partnership relationship is administered and delineated in whole or part through the PSC vehicle.  In the PSCs, CUCBM represents that they have full authority to contract with foreign investors for the purpose of exploring and producing CBM.  Because only a Chinese party can hold an exploration license for CBM, CUCBM applies to MLR for the exploration licenses on behalf of foreign investors.  In operating under the PSCs, our primary interaction with Chinese administration is with CUCBM and the JMC that administers our PSC.  The JMC consists of members of our management team and representatives of CUCBM and it meets on a periodic basis to, among other things, discuss and make decisions concerning our exploration and development progress and plans, including budgets and capital expenditure commitments.  Under the terms of the PSCs, we must obtain CUCBM's consent to certain actions, including the transfer of any rights under the PSCs.  Additionally, the PSCs authorize us to sell CBM directly into the market but our marketing efforts may be limited by certain Chinese regulations that require companies to have a permit not generally available to foreign companies to sell gas in certain Chinese localities.

Our Employees

As of March 12, 2010, we had 20 employees in China and 9 employees in the United States for a total of 29 employees, all of whom were employed by us on a full-time basis.


ITEM 1A. RISK FACTORS

Forward-Looking Statements

This report includes forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended (the "Securities Act"), and Section 21B of the Securities Exchange Act of 1934, as amended ("Exchange Act"). All statements other than statements of historical facts contained in this report, including statements regarding our future financial position, business strategy and plans and objectives of management for future operations, are forward-looking statements. The words "believe," "may," "will," "estimate," "continue," "anticipate," "intend," "project," "expect," "consider" and similar expressions, as they relate to us, are intended to identify forward-looking statements.

We have based these forward-looking statements largely on our current expectations and projections about future events and financial trends that we believe may affect our financial condition, results of operations, business strategy and financial needs. Although we believe that the expectations reflected in these forward-looking statements are reasonable, there can be no assurance that the actual results or developments we anticipate will be realized or, even if substantially realized, that they will have the expected effects on our business or operations. Actual results could differ materially from those projected in such forward-looking statements. Factors that could cause actual results to differ materially from those projected in such forward-looking statements include: the gas produced at our wells may not increase or may decrease; certain of the proposed transactions with Arrow may not close on a timely basis or at all, including due to a failure to satisfy closing conditions or otherwise; the anticipated benefits to us of the transactions with Arrow may not be realized; the final amounts received by us from Arrow may be different than anticipated; the MOC may not approve the extension of the Qinnan PSC on a timely basis or at all; our Chinese partner companies or the MOC may require certain changes to the terms and conditions of our PSC in conjunction with their approval of any extension of the Qinnan PSC; our lack of operating history; limited and potentially inadequate management of our cash resources; risk and uncertainties associated with exploration, development and production of CBM; expropriation and other risks associated with foreign operations; disruptions in capital markets effecting fundraising; matters affecting the energy industry generally; lack of availability of oil and gas field goods and services; environmental risks; drilling and production risks; changes in laws or regulations affecting our operations, as well as other risks described in our filings with the SEC.

When you consider these forward-looking statements, you should keep in mind these risk factors and the other cautionary statements in this report. Our forward-looking statements speak only as of the date made. All subsequent oral and written forward-looking statements attributable to us or persons acting on our behalf are expressly qualified in their entirety by these factors. We assume no obligation to update any of these statements.

Additional risks include among others, the following:

Risks Relating to Our Business

We must obtain additional financing in order to continue our operations.

We are not able to accurately predict when we will recognize meaningful revenues. We expect to experience operating losses and negative cash flow for the foreseeable future. On March 13, 2009, we entered into a series of related transactions associated with our Qinnan Block with Arrow. Assuming that we obtain approval from our Chinese partner company and the Chinese Ministry of Commerce (“MOC”), and satisfy the other conditions under the Farmout Agreement with Arrow (the “Farmout Agreement”), then the additional payment due upon the occurrence of these events from Arrow together with funds currently available should provide sufficient working capital to meet our currently planned work programs through 2010.  Our current work programs would satisfy the minimum exploration expenditures for all three of our PSCs for 2010.  However, there can be no assurance that the approvals for the Farmout Agreement will be received. Moreover, since December 19, 2009, each of Arrow and the Company has had the right to terminate the Farmout Agreement at any time, though neither party has elected to exercise that right, and the parties are continuing use efforts to satisfy the conditions to the transactions contemplated by the Farmout Agreement.


Management will continue to seek to raise additional capital to continue operations and to meet future expenditure requirements necessary to retain our rights under the PSCs. Management intends to seek to obtain funds to continue operations by entering into a strategic relationship or transaction, such as a joint venture, farmout, merger or acquisition, and/or obtaining debt or equity financing. The global financial crisis has created liquidity problems for many companies and financial institutions and international capital markets have stagnated, especially in the United States and Europe. A continuing downturn in these markets could impair our ability to obtain, or may increase our costs associated with obtaining, additional funds through the sale of our securities. The ongoing crisis has created a difficult environment in which to negotiate and consummate a transaction. While we will continue to seek to raise funds, there can be no assurance that we will be able to enter any strategic relationship or transaction or that we will be successful in obtaining funds through debt or equity financing. Under certain circumstances, the structure of a strategic transaction may require the approval of the Chinese authorities, which could delay closing or make the consummation of a transaction more difficult or impossible. In particular, any transfer of our rights under any PSC will require the approval of our Chinese partner company. There can be no assurance that the Chinese authorities will provide the approvals necessary for a transaction or transfer. In addition, the terms and conditions of any potential strategic relationship or transaction or of any debt or equity financing are uncertain and we cannot predict the timing, structure or other terms and conditions of any such arrangements or the consideration that may be paid with respect to any offering of securities.

Our ability to continue as a going concern depends upon our ability to obtain substantial funds for use in our development activities and upon the success of our planned exploration and development activities. There can be no guarantee of future fundraising or exploration success or that we will realize the value of our unevaluated exploratory well costs. The accompanying consolidated financial statements do not include any adjustments that might result from the outcome of this uncertainty. Management believes that we will continue to be successful in obtaining the funds necessary to continue as a going concern.

If our operating requirements or drilling obligations materially change from those currently planned, we may require more capital than currently anticipated or may be required to raise capital earlier than anticipated. For example, it is possible that the Ministry of Land and Resources or our Chinese partner company could seek to, among other things, increase our capital expenditures or accelerate our drilling program. If we are unable to commit to the expenditures or accelerate our drilling and dewatering efforts it may adversely affect our ability to extend the terms of our PSCs. Raising additional funds by issuing Shares or other types of equity securities would further dilute our existing stockholders. If we fail to obtain the necessary funds to complete our exploration activities under our PSCs, and we cannot obtain extensions to the requirements under our PSCs, we would not be able to successfully complete our exploration activities and we may lose rights under our PSCs.

We must obtain extensions for our PSCs to continue our operations in China.

We have commenced the extension application process for each of our PSCs. The Ministry of Commerce (the "MOC") has approved modification agreements to extend the exploration periods for the Shouyang area of Shanxi Province and the Enhong and Laochang areas of Yunnan Province to June 30, 2011. The exploration period of the Qinnan PSC in Shanxi Province expired on June 30, 2009. With regard to the Qinnan PSC, CNPC has recently replaced CUCBM as our Chinese partner company for the PSC. We are continuing to pursue an extension of the exploration period of the Qinnan PSC. It is possible that our Chinese partner company might elect to issue a new PSC, which could be on less favorable terms than those in the current PSC. At CNPC's request, we have provided certain operational and financial information about our Company to assist them in the decision making process. Recently, CNPC has completed an accounting audit pursuant to the Qinnan PSC of our expenditures for 2007 and 2008.  We have also provided to CNPC at their request our work plan for 2010 for Qinnan.  For many months CNPC has been awaiting authorization from the Chinese government allowing it to deal with foreign partners on CBM projects. On March 7, 2010, several major news outlets reported that CNPC stated that it has been authorized to jointly develop coalbed methane projects with foreign partners, but we have not yet obtained official confirmation of this.  There can be no assurance that we will be successful in extending the exploration period of the Qinnan PSC or that a new PSC will be granted. Additionally, in connection with obtaining this extension or a new PSC, we may be required to commit to certain expenditures or to modify the terms or respective ownership interests and/or acreage in the applicable PSC. However, if we are unable to raise sufficient funds to commit to these expenditures, it may adversely affect our ability to extend any or all of our PSCs.


We are in the initial exploration phase and have substantial capital requirements that, if not met, will hinder our ability to continue as a going concern.

We face significant challenges, expenses and difficulties as a development stage company seeking to explore, develop and produce coalbed methane gas. The development of our projects in China will require that we obtain funding to satisfy very significant expenditures for exploration and development of these projects, if they are successful. We will also require resources to fund significant capital expenditures for exploration and development activities in future periods. In this regard, CUCBM or CNPC could seek to renegotiate our PSCs to, among other things, increase our expenditures or accelerate our drilling program beyond the minimum contractual requirements under our PSCs. As discussed above, assuming that we obtain approval from our Chinese partner company and the MOC, and satisfy the other conditions under the Farmout Agreement with Arrow, then the additional payment due upon the occurrence of these events from Arrow together with funds currently available should provide sufficient working capital to meet our currently planned work programs through 2010.  Our current work programs would satisfy the minimum exploration expenditures for all three of our PSCs for 2010.  Our success will depend on our ability to obtain additional financing to fund our capital expenditures. If we cannot obtain adequate capital, and we cannot obtain extensions to the requirements under our production sharing contracts, we will not be able to successfully complete our exploration and development activities, and we may lose rights under our production sharing contracts. This would materially and adversely affect our business, financial condition and results of operations.

Continued disruption in national and international investment and credit markets or fraud or embezzlement of funds at the financial institutions which hold our assets may adversely affect our business, financial condition and results of operation.

The recent meltdown of and disruptions in the global financial system have led to a significant slowdown in capital market activities, a scarcity of credit, tighter lending standards and higher interest rates and costs of capital. Current market conditions may continue or worsen. We can make no assurances that we will be able to obtain additional equity or debt financing to fund our anticipated drilling, exploration and operation costs on terms that are acceptable to us or at all. In the absence of capital obtained through a strategic relationship or transaction with one or more interested companies, or through an equity or debt financing, our ability to operate and to meet our obligations under our production sharing contracts would be impaired, which would have a material adverse effect on our business, financial condition and results of operation and may affect our ability to continue as a going concern.

Our cash and cash equivalents are liquid investments with original maturities of three months or less at the time of purchase. We maintain the cash and cash equivalents with reputable major financial institutions in deposit accounts and U.S. government securities money market accounts. Deposits with these institutions exceed the Federal Deposit Insurance Corporation's insurance limits or similar limits in foreign jurisdictions. If one or more of these institutions are unable to honor our withdrawal requests or redeem our shares in our deposit or money market accounts as a result of the institution's financial condition, fraud, embezzlement or otherwise, it could have an adverse affect on our business, financial condition and results of operations.
 
The development of CBM properties involves substantial risks and we cannot assure that our exploration and drilling efforts will be successful.

The business of exploring for and, to a lesser extent, developing and operating CBM properties involves a high degree of business and financial risk that even a combination of experience, knowledge and careful evaluation may not be able to overcome. The selection of prospects for CBM gas drilling, the drilling, ownership and operation of CBM wells and the ownership of interests in CBM properties are highly speculative. Our well data, including information relating to permeability and coal thickness, is preliminary in nature. We cannot predict whether any prospect will produce CBM or whether, even if producing, such prospect will produce commercial quantities of CBM.

Drilling for CBM gas may involve unprofitable efforts, not only from dry wells, but also from wells that are productive but do not produce coalbed methane in sufficient quantities or quality to realize enough net revenues to return a profit after drilling, operating and other costs. The cost of drilling, completing and operating wells is often uncertain and cost overruns are common. Our drilling operations may be curtailed, delayed or canceled as a result of

 
numerous factors, many of which are beyond our control, including but not limited to uncooperative inhabitants, title problems, weather conditions, compliance with governmental requirements and shortages or delays in the delivery of equipment and services. In addition, other factors such as permeability, structural characteristics of the coal, or the quality or quantity of water that must be produced, may hinder, restrict or even make production impractical or impossible.

Drilling and completion decisions generally are based on subjective judgments and assumptions that are speculative. We may drill wells that, although productive, do not produce CBM in economic quantities. It is impossible to predict with certainty the production potential of a particular property or well. Furthermore, the successful completion of a well does not ensure a profitable return on the investment. A variety of geological, operational, or market-related factors, including, but not limited to, unusual or unexpected geological formations, pressures, equipment failures or accidents, fires, explosions, blowouts, cratering, pollution and other environmental risks, shortages or delays in the availability of drilling rigs and the delivery of equipment, loss of circulation of drilling fluids or other conditions may substantially delay or prevent completion of any well, or otherwise prevent a property or well from being profitable. We contract with drilling companies to drill certain of our wells in China and we face the risk that the other party may not perform, which may delay our drilling program. A productive well may also become uneconomic in the event of excessive water or other deleterious substances are encountered, which impair or prevent the production of natural gas from the well. In addition, production from any well may be unmarketable if it is contaminated with water or other deleterious substances. We cannot assure that wells drilled by us will be productive or, even if productive, will produce CBM in economic quantities so that we will recover all or any portion of our investment. In the event we are not successful, we may be required to write off some or all of the capitalized well costs on our financial statements.

We have no current source of revenue.

We will not generate material revenues from our existing properties until we have successfully completed exploration and development, and started production of CBM. We are not able to accurately predict when we will recognize meaningful revenues. Additionally, pipelines must be built to connect to larger pipelines or compressed must be constructed on our Shanxi Province projects to process and transport our CBM, and no facilities exist to transport or process CBM near our Yunnan Province projects. Our ability to realize revenues from any producing wells may be impaired until these facilities are built out or arrangements are made to deliver our production to market.

We are a development stage company and, thus, we have no relevant operating history for the purpose of evaluation of our performance and prospects.

We have been engaged principally in developing and implementing strategic operating and exploration plans, raising capital, hiring personnel, entering into contracts, acquiring rights to explore, develop, produce and sell CBM, and drilling, testing and completing of exploratory wells. We do not have operating experience in the distribution and marketing of CBM gas in China. We are considered a development stage company for accounting purposes because we have generated no revenues to date. Accordingly, we have no relevant operating history upon which you can evaluate our performance and prospects. In addition, we cannot forecast operating expenses based on our historical results and our ability to accurately forecast future revenues is limited. As a result of our limited operating history, we are more susceptible to business risks including risks of unforeseen capital requirements, failure to establish business relationships, and competitive disadvantages against larger and more established companies.

We have a history of losses, and expect to incur losses in the foreseeable future. If we do not achieve profitability, our financial condition and the value of our common stock will suffer.

To date, we have no revenues from the sale of CBM. We incurred yearly net losses applicable to common stockholders since inception. We expect to experience operating losses and negative cash flow for the foreseeable future. We must obtain additional financing and generate sufficient revenues to fund anticipated drilling, exploration and operation costs and to achieve and maintain profitability. We cannot guarantee that we will ever generate sufficient revenues to achieve profitability, which will negatively impact the price of our common stock. If we do achieve profitability, we cannot assure you that we will be able to sustain or increase profitability in the future.

 
We must complete multiple CBM wells on our Shanxi Province and Yunnan Province projects before we can commence production.

To date, we have drilled 8 horizontal wells, 24 vertical wells and 7 deviated wells in the Shanxi Province projects and 10 vertical wells and 4 deviated wells in Yunnan Province. While subject to periodic maintenance, we have achieved continuous gas production in some of these wells. At this early stage, the volumes being produced while dewatering are still small and the data obtained is not yet sufficient to be able to project the peak gas production volume or to be able to conclude whether the wells will produce gas in commercial volumes. None of the other wells we have drilled to date are currently producing CBM gas as they are undergoing or will undergo dewatering and production testing. However, even if all our current wells reach production status, they may not produce enough CBM gas to achieve commercial viability. For each project, we are analyzing and evaluating drilling data obtained in an effort to determine how many additional wells we have to drill in order to begin production of commercial volumes. We cannot make any assurances that we will have the resources to drill enough additional wells in the Shanxi and Yunnan Provinces to commence production in the areas. As a result, even though we may have producing properties in the region, we may not be in a position to derive any revenues from such wells. Actual production may vary materially from preliminary test results, including the results to date for our first horizontal well. Actual production from the wells may be at recovery rates and gas quality materially different than our first indications.

We are a holding company and we rely on our subsidiaries for dividends and other payments for funds to meet our obligations.

We are principally a holding company with substantially all of our assets relating to operations in China being owned by our subsidiary, FEEB. Consequently, we have no direct operations and are not expected to own a significant amount of assets other than the outstanding capital stock of our subsidiaries, including FEEB, and cash and cash equivalents. Because we conduct our operations through our subsidiaries, if and when we commence commercial production of CBM, we will depend on those entities for dividends and other payments to generate the funds necessary to meet our financial obligations and to pay dividends, if any, with respect to our common stock. The jurisdictions of our subsidiaries may impose restrictions on or require government approval of dividends or certain payments by the subsidiaries. All of our subsidiaries will be separate and independent legal entities and will have no legal obligation whatsoever to pay, and may be contractually restricted from paying any dividends, distributions or other payments to us.

We are dependent on our key executives and may not be able to hire and retain key employees to fully implement our business strategy.

Our success will depend largely on our senior management, which includes our executive officers. As we grow our business, we must attract, retain and integrate additional experienced managers, geoscientists and engineers in order to successfully operate and grow our businesses. The number of available, qualified personnel in the oil and gas industry to fill these positions may be limited. Our inability to attract, retain and integrate these additional personnel or the loss of the services of any of our senior executives or key employees could delay or prevent us from fully implementing our business strategy and could significantly and negatively affect our business.

We are not diversified and we concentrate on one industry.

Our business strategy concentrates on exploration and development of CBM gas in China. There is an inherent risk in not having a diverse base of properties in exploration and development, because we will not have alternate sources of revenue if we are not successful with our current exploration and development activities. As we will invest substantially all of our assets in this market, we may be more affected by any single adverse economic, political or regulatory event than a more diversified entity. Our failure in the exploration and development of our CBM property rights in China would have a material adverse affect on our business.


We may not be able to develop a proven reserve base.

Our future success will depend upon our ability to find and develop CBM reserves. Any CBM reserves that we develop will decline as CBM production occurs. To develop reserves and production, we must implement our exploration, development and production programs and identify and produce from previously overlooked or by-passed zones and shut-in wells. Our current strategy is to develop a reserve base, production and cash flow through the development of CBM fields in our Shanxi Province and Yunnan Province projects. We can give no assurance that our planned exploration and development activities will result in any reserves or that we will have any success in discovering and producing reserves at economical exploration and development costs.

We may have difficulty managing growth in our business.

Because of our small size and the relatively large scale of operations required for our business to yield revenue, growth in accordance with our business plan, if achieved, will place a significant strain on our financial, technical, operational and management resources. As we expand our activities and increase the number of projects we are evaluating or in which we participate, there will be substantially more demands on these resources. Further, we may be required to respond to any expansion of our activities in a relatively short period of time in order to meet the demands created by the expansion of these activities, the growth of our business and our drilling objectives. The failure to timely upgrade our technical, administrative, operating and financial control systems or the occurrence of unexpected expansion difficulties, including the recruitment and retention of experienced managers, geoscientists and engineers, could have a material adverse effect on our business, financial condition and results of operations and our ability to timely execute our business plan. If we are unable to implement these actions in a timely manner, our results and the growth of our business may be adversely affected.

Risks Relating to Our Operations in China

No facilities presently exist to transport or process CBM near our Yunnan Province projects, and, although larger pipelines exist in proximity to our Shanxi Province projects, pipelines must be built to connect to larger pipelines and facilities must be added to compress or liquefy and perhaps to transport any CBM that may be produced from those projects.

The marketability of any production will depend, in part, upon the availability, proximity and capacity of pipelines, gas gathering systems and processing facilities. We may transport our CBM through pipelines or by compressing or liquefying the CBM for transportation. We have begun discussions with CUCBM regarding a gas marketing agreement. It is anticipated that the marketing facility would allow us to jointly market our gas with CUCBM through a gas sales facility.

Currently, two national trunklines, one to Beijing and one to Shanghai, traverse China in proximity to our Shanxi Province projects.  However, we are in discussions with three separate third parties (two pipelines and one CNG company) regarding the potential off-take and sale of gas any commercial quantities of gas that may be produced from the 1H Pilot Area.  Far East believes that, subject to reaching an agreement regarding off-take and commercial quantities of gas being produced, it could initiate gas sales as early as the third quarter of 2010. The two pipeline companies are planning to lay lines approximately 18 inches in diameter near the Shouyang Area.  One of the pipeline companies recently stated that it would consider slightly re-routing its line to come to within approximately two kilometers of Far East’s 1H Pilot Area, with that company's pipeline expected to be completed by July or August.   That pipeline is being built to take gas off of the Shanjing II pipeline that runs from Western China to Beijing and to move that gas towards the provincial capital of Shanxi Province. Its route was already planned to pass within five to seven kilometers of the 1H Pilot Area.  Additionally, the pipeline company has stated that it does not intend to require that Far East guarantee volumes of gas.  Normally, in order to induce a pipeline to build to a producing area, the producer must guarantee that a certain volume of gas will be available to the pipeline.  If our discussions with the three separate third parties do not result in any commercially viable arrangement and in the absence of any similar arrangement with other companies, pipelines may need to be built on those projects to connect to larger pipelines to transport any CBM that may be produced from those projects.  We estimate the initial cost for these connecting pipelines and compression facilities may be in the range of $10 million to $20 million or more.  If CUCBM elects a 30% participating interest in our Shanxi Province project, our net costs would be reduced accordingly.  Additionally, if we are successful in assigning 75.25% of our current participating interest in the

 
Qinnan PSC to Arrow, our net cost with respect to any project for that PSC would be reduced accordingly.  There is no assurance that any of the existing pipelines we might desire to connect to in the future will have sufficient capacity available to meet our requirements or the costs of using such pipelines would be economical.  Additionally, there is no assurance that we will be able to use the existing pipeline on terms acceptable to us or at all, as the PRC does not require that open access to pipeline infrastructure be allowed.

Pipelines in Yunnan Province. There are no pipelines in the vicinity of our Yunnan Province projects, and we estimate the initial cost to construct a connecting pipeline and compression facilities from our project to the nearest large city, Kunming, may be in the range of $20 million to $50 million or more. If CUCBM elects a 40% participating interest in our Yunnan Province project our costs would be reduced accordingly. Because there is no gas pipeline, CNG facility, LNG plant or other off-take vehicle in near proximity to these wells, our ability to sell CBM produced on these projects to communities outside the general area will be contingent upon a pipeline, CNG or LNG plant being built near the Enhong-Laochang project.

Recently, it was reported that CNPC will undertake a pipeline construction project with support from the Yunnan provincial government to extend the Myanmar-China natural gas pipeline to pass through the city of Kunming, then go northward through the city of Zhaotong, and finally connect with major interprovincial pipelines in Sichuan Province.  Further, the pipelines are expected to include a branch to connect the city of Kunming to the city of Qujing.  We believe that the construction, which would lay pipelines closer to our projects, would help reduce the cost for CBM off-take from our projects and increase our ability to eventually deliver gas to consumers.  If CUCBM elects a 40% participating interest in Yunnan Province project, our costs would be reduced accordingly.  However, there can be no assurances that this project will be undertaken or be completed or, if it is undertaken, that it will be completed on a timely basis.  Additionally, there is no assurance that we will be able to use the pipeline on terms acceptable to us or at all, as the PRC does not require that open access to pipeline infrastructure be allowed.

Compressed Natural Gas. If we have initial commercial production of CBM from our Shanxi Province projects, then, prior to the point at which production reaches pipeline quantities, we could potentially begin to market the CBM produced to local markets as CNG. CNG is an alternative to the construction of a pipeline or LNG facility and is especially appropriate for early stage gas production where gas volumes are lower. We may determine to pursue CNG facilities in order to earn revenues from any early production of CBM.  Production of CNG would require the installation of a CNG facility,  which would likely be constructed and paid for by the purchaser of our gas production.

Substantially all of our assets and operations are located in China.

Substantially all of our assets and operations are located in China. Accordingly, our business is subject to a significant extent, to the economic, political, and legal developments in China. China is a developing country, has only recently begun participating in global trade with its accession to the World Trade Organization, and has only a limited history of trade practices as a nation. We are subject to the laws, rules, regulations, and political authority of the government of China. We may encounter material problems while doing business in China, such as interactions with the Chinese government and uncertain foreign legal precedent pertaining to developing CBM gas in China. Risks inherent in international operations also include, but are not limited to, the following:

 
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Global economic conditions;

 
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Local currency instability;

 
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Inflation;

 
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The risk of realizing economic currency exchange losses when transactions are completed in currencies other than U.S. dollars;

 
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The ability to repatriate earnings under existing exchange control laws; and

 
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Political unrest.
 
 
Changes in domestic and foreign import and export laws and tariffs can also materially impact international operations. In addition, foreign operations involve political, as well as economic risks, including:

 
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Nationalization;

 
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Expropriation;

 
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Contract renegotiations;

 
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Trade protection;

 
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Changes in diplomatic and trade relations between United States and China;

 
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Government intervention and price fixing in certain markets; and

 
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Changes in laws resulting from governmental changes.

Additionally, CUCBM and CNPC are subject to rules and regulations of China and the jurisdiction or influence of other governmental agencies in China that may adversely affect their ability to perform under, or our rights in our PSCs with them. These rules and regulations may affect our rights under or PSCs by potentially limiting, renegotiating or precluding us from exploring and developing the full acreage provided for and may also affect the opportunities and obligations under our PSCs. CUCBM and CNPC could seek to, among other things, increase our expenditures or accelerate our drilling program beyond the minimum contractual requirements under our PSCs. We must comply with certain procedural requirements under our PSCs and with CUCBM in order to obtain the reimbursement of costs incurred under the PSCs. We cannot assure you that we will recover or that CUCBM will approve reimbursement of all costs incurred under the PSC, which could adversely impact our business, financial conditions and results of operations. In the event of a dispute, we may be subject to the exclusive jurisdiction of foreign courts or may not be successful in subjecting foreign persons to the jurisdiction of courts in the United States. We may also be hindered or prevented from enforcing our rights with respect to a governmental instrumentality because of the doctrine of sovereign immunity.

We are exposed to foreign currency risk.

In July 2005, the Chinese government began to permit the Chinese RMB to float against the U.S. Dollar. All of our costs to operate our Chinese offices are paid in Chinese RMB. Our exploration costs in China may be incurred under contracts denominated in Chinese RMB or U.S. Dollars. If the value of the U.S. Dollar falls in relation to the Chinese RMB, the cost to us of funding our Chinese operations would rise because more U.S. Dollars would be required to fund the same expenditures in RMB. Conversely, if the value of the U.S. Dollar rises in relation to the Chinese RMB, the change in exchange rates would decrease our dollar cost to fund operations in China.

To date, we have not engaged in hedging activities to hedge our foreign currency exposure. In the future, we may enter into hedging instruments to manage our foreign currency exchange risk or continue to be subject to exchange rate risk. However, we may not be successful in reducing foreign currency exchange risks, and as a result, we may from time to time experience losses resulting from fluctuations in the value of the Chinese RMB.


Inflation may adversely affect our financial condition and results of operations.

Although inflation has not materially impacted our operations in the recent past, increased inflation in China or the U.S. could have a negative impact on our operating and general and administrative expenses, as these costs could increase. In recent months, the Company has increased its use of Chinese suppliers, including drilling contractors, that are paid in RMB. In the future, inflation in China may results in higher minimum expenditure requirements under our PSCs if CUCBM adjusts these requirements for inflation. A material increase in these costs as a result of inflation could adversely affect our operations and, if there are material changes in our costs, we may seek to raise more funds earlier than anticipated.

We risk the effects of general economic conditions in China.

Any future CBM sales could be adversely affected by a sustained economic recession in China. As our operations and end user markets are primarily in China, a sustained economic recession in that country could result in lower demand or lower prices for the natural gas to be produced by us. The recent meltdown of and disruptions in the global financial system may adversely impact China's growth rates.

We may depend on a few customers when we begin selling our gas production.

At present, we have no CBM gas sales contracts pending and we are not able to accurately predict when we will recognize meaningful revenues from our gas production. However, when we begin selling our gas production, there may be only a small number of entities we can contract with which will purchase any gas we may produce. Losing any such potential contract or client would have a material negative impact on our business.

Risks Related to the Oil & Gas Industry

The volatility of natural gas and oil prices could harm our business.

Our future revenues, profitability and growth as well as the carrying value of our oil and gas properties depend to a large degree on prevailing oil and gas prices. Commercial lending sources are not currently available to us because of our lack of operating history and income. Our ability to borrow and to obtain additional equity funding on attractive terms also substantially depends upon oil and gas prices. Prices for oil and gas are subject to large fluctuations in response to relatively minor changes in the supply and demand for oil and gas, uncertainties within the market and a variety of other factors beyond our control. These factors include weather conditions in China, the condition of the Chinese economy, the activities of the Organization of Petroleum Exporting Countries, governmental regulation, political stability in the Middle East and elsewhere, the foreign supply of oil and gas, the price of foreign imports and the availability of alternative fuel sources. Prices for oil and natural gas have been and are likely to remain extremely unstable.

We may not be able to successfully compete with rival companies.

The energy industry is highly competitive in all its phases. Competition is particularly intense with respect to the acquisition of CBM prospects suitable for enhanced production efforts, and the hiring of experienced personnel. Our competitors in CBM acquisition, development, and production include major integrated oil and gas companies in addition to substantial independent energy companies. Many of these competitors possess and employ financial and personnel resources substantially greater than those that are available to us and may be able to pay more for desirable producing properties and prospects and to define, evaluate, bid for, and purchase a greater number of producing properties and prospects than we can. Our financial or personnel resources to generate revenues in the future will depend on our ability to select and acquire suitable producing properties and prospects in competition with these companies.


The production and producing life of wells is uncertain and production will decline.

If any well becomes commercially productive, it will not be possible to predict the life and production of that well. The actual producing lives could differ from those anticipated. Sufficient CBM may not be produced for us to receive a profit or even to recover our initial investment. In addition, production from our CBM gas wells, if any, will decline over time, and does not indicate any consistent level of future production.

We may suffer losses or incur liability for events for which the operator of a property or we have chosen not to obtain insurance.

Our operations are subject to hazards and risks inherent in producing and transporting oil and natural gas, such as fires, natural disasters, explosions, pipeline ruptures, spills, and acts of terrorism, all of which can result in the loss of hydrocarbons, environmental pollution, personal injury claims and other damage to our properties and others. The occurrence of any of these events could result in the following:

 
Ÿ
Substantial losses due to injury and loss of life;

 
Ÿ
Severe damage to and destruction of property, natural resources and equipment;

 
Ÿ
Pollution and other environmental damage;

 
Ÿ
Clean-up responsibilities; and

 
Ÿ
Regulatory investigation and penalties and suspension of operations.

As protection against operating hazards, we maintain insurance coverage against some, but not all, potential losses. The occurrence of an event that is not covered, or not fully covered, by insurance could have a material adverse effect on our business, financial condition and results of operations.

Environmental hazards and liabilities may adversely affect us and result in liability.

There are numerous natural hazards involved in the drilling of CBM wells, including unexpected or unusual formations, pressures, and blowouts and involving possible damages to property and third parties, surface damages, bodily injuries, damage to and loss of equipment, reservoir damage and loss of reserves. We could also be liable for environmental damages caused by previous property owners. As a result, substantial liabilities to third parties or governmental entities may be incurred which could have a material adverse effect on our financial condition and results of operations.

We maintain insurance coverage for our operations in amounts we deem appropriate, but we do not believe that insurance coverage for environmental damages that occur over time, or complete coverage for sudden and accidental environmental damages, is available at a reasonable cost. Accordingly, we may be subject to liability or may lose the privilege to continue exploration or production activities upon substantial portions of our properties if certain environmental damages occur. The insurance coverage we do maintain may also be insufficient. In that event, our assets would be utilized to pay personal injury and property damage claims and the costs of controlling blowouts or replacing destroyed equipment rather than for additional drilling activities.

We face substantial governmental regulation and environmental risks.

Our business is subject to various laws and regulations that may be changed from time to time in response to economic or political conditions. Matters subject to regulation include the following:

 
Ÿ
Discharge permits for drilling operations;

 
Ÿ
Drilling bonds;

 
Ÿ
Reports concerning operations;

 
 
Ÿ
The spacing of wells;

 
Ÿ
Unitization and pooling of properties;

 
Ÿ
Taxation; and

 
Ÿ
Environmental protection.

Regulatory agencies may also impose price controls and limitations on production by restricting the rate of flow of oil and gas wells below actual production capacity in order to conserve oil and gas.

We are subject to environmental regulation that can materially and adversely affect the timing and cost of our operations.

Our exploration and proposed production activities are subject to certain laws and regulations relating to environmental quality and pollution control. Our operations in China are governed by PSCs and the Shanxi farmout agreements. We are subject to the laws, decrees, regulations and standards on environmental protection and safety promulgated by the Chinese government. Various government laws and regulations concerning the discharge of incidental materials into the environment, the generation, storage, transportation and disposal of waste or otherwise relating to the protection of public health, natural resources, wildlife and the environment, affect our current exploration efforts and future development, processing and production operations and the costs related to them. These regulations require us to obtain environmental permits to conduct seismic acquisition, drilling or construction activities. Such regulations also typically include requirements to develop emergency response plans, waste management plans, environmental plans and spill contingency plans.

Existing environmental laws and regulations may be revised or new laws and regulations may be adopted or become applicable to us. Revised or additional laws and regulations that result in increased compliance costs or additional operating restrictions, particularly if those costs are not fully recoverable from insurance or our customers, could have a material adverse effect on our business, financial condition or results of operations.

The unavailability or high cost of drilling rigs, equipment, supplies, personnel and oil field services could adversely affect our ability to execute our exploration and exploitation plans on a timely basis and within our budget.

Shortages or the high costs of drilling rigs, equipment, supplies or personnel could delay or adversely affect our exploration and exploitation operations, which could have a material adverse effect on our business, financial condition or results of operations. If the unavailability or high cost of rigs, equipment, supplies or personnel were particularly severe in China, we could be materially and adversely affected.

Risks Relating to our Securities

We have registered for resale a substantial amount of our outstanding shares of common stock and shares of common stock underlying warrants and options and shares of our common stock that cannot currently be traded without restriction that may become eligible for trading in the future. We cannot predict the effect future sales of our common stock will have on the market price of our common stock.

On March 12, 2010, we had 500 million shares of common stock authorized, of which approximately 185.5 million shares of common stock were issued and outstanding. As of March 12, 2010, we had 31.7 million shares of common stock subject to options and warrants. As of March 12, 2010, of the issued and outstanding shares, 5.5 million, or 3%, were "restricted stock" subject to resale restrictions. Our shares of restricted stock will be available for trading in the future, so long as all the requirements of Rule 144, promulgated under the Securities Act, are met or if such shares are registered for resale. Additionally, as of March 12, 2010, 12.4 million shares underlying warrants may be considered to be restricted stock upon issuance. Therefore, the total number of shares of common stock potentially subject to restriction upon issuance was 17.9 million.

 
We cannot predict the effect, if any, that future sales of our common stock will have on the market price of our common stock prevailing from time to time. Sales of substantial amounts of common stock, such as the outstanding securities registered or to be registered on registration statements, or the perception that such sales could occur, may adversely affect prevailing market prices for our common stock.

We do not currently intend to pay dividends on our common stock.

We currently intend to retain any profits to fund the development and growth of our business. As a result, we have not paid dividends on our common stock and our board of directors currently does not intend to declare dividends or make any other distributions on our common stock in the foreseeable future. Consequently, it is uncertain when, if ever, we will declare dividends to our common stockholders. Investors in our common stock may not derive any profits from their investment in us for the foreseeable future, other than through any price appreciation of our common stock that may occur.

The price of our common stock could be volatile.

The market price of our common stock will likely fluctuate significantly in response to the following factors, some of which are beyond our control:

 
Ÿ
Variations in our quarterly operating results;

 
Ÿ
Changes in market valuations of oil and gas companies;

 
Ÿ
Announcements by us of significant contracts, acquisitions, strategic partnerships, joint ventures or capital commitments;

 
Ÿ
Failure to extend the terms of our production sharing contracts;

 
Ÿ
Additions or departures of key personnel;

 
Ÿ
Future sales of our common stock;

 
Ÿ
Stock market price and volume fluctuations attributable to inconsistent trading volume levels of our common stock; and

 
Ÿ
Commencement of or involvement in litigation.

In addition, the trading volume of our common stock is relatively small, and the market for our common stock may not be able to efficiently accommodate significant trades on any given day. As a result, sizable trades of our common stock may cause volatility in the market price of our common stock to a greater extent than in more actively traded securities. These broad fluctuations may adversely affect the market price of our common stock.

Trading in our common stock is limited and sporadic, and a significant market for our common stock may not develop.

Our common stock is currently eligible for trading only on the OTC Bulletin Board. While there currently exists a limited and sporadic public trading market for our common stock, the price paid for our common stock and the amount of common stock traded are volatile. We cannot assure or guarantee you that the trading market for our common stock will improve or develop further, and as a result, the liquidity of our common stock may be reduced and you may not recover any of your investment.


We may issue our capital stock without the consent of stockholders. The issuance of any additional equity securities would further dilute our stockholders.
 
Our board of directors has the authority, without further action by the stockholders, to issue up to 500 million shares of preferred stock in one or more series and to designate the rights, preferences, privileges and restrictions of each series. We also have 500 million shares of common stock authorized under our charter documents, of which approximately 185.5 million shares are issued and outstanding as of March 12, 2010. The issuance of preferred stock could have the effect of restricting dividends on the common stock or delaying or preventing our change in control without further action by the stockholders. While we have no present plans to issue any shares of preferred stock, we may need to do so in the future in connection with capital raising transactions. In addition, we may issue additional shares of common stock or other equity securities, including securities convertible into shares of common stock, in connection with capital raising activities. The issuance of additional common stock would also have a dilutive impact on our stockholders' ownership interest in our company.


ITEM 1B.  UNRESOLVED STAFF COMMENTS

None.


ITEM 2. PROPERTIES

Undeveloped Acreage

The following table summarizes the acreage subject to our production sharing contracts covering the following undeveloped acreage in China as of December 31, 2009:

         
Net Acres
  
   
Gross Acres
    
Maximum (1)
    
Minimum (2)
  
China:
                  
Shouyang Block, Shanxi Province
     485,000       485,000       340,000  
Qinnan Block, Shanxi Province
     573,000 (3)     573,000       401,000  
Enhong and Laochang Areas, Yunnan Province
     265,000       265,000       159,000  

(1) Assuming the Chinese partner company chooses not to participate.
(2) Assuming the Chinese partner company chooses to maximize its participation.
(3) Under the Farmout Agreement entered into in connection with our strategic alliance related to our Qinnan Block with Arrow, subject to certain conditions precedent including most notably approval by appropriate Chinese governmental authorities, we will assign 75.25% of our participating interest in the Qinnan PSC to Arrow.  For additional information on the strategic alliance, see Item 1. "Business - Strategic Alliance with Arrow." CNPC has replaced CUCBM as our Chinese partner company in the Qinnan PSC.  We are in discussions with CNPC regarding the extension of the exploration period, which expired on June 30, 2009 For many months CNPC has been awaiting authorization from the Chinese government allowing it to deal with foreign partners on CBM projects. On March 7, 2010, several major news outlets reported that CNPC stated that it has been authorized to jointly develop coalbed methane projects with foreign partners, but we have not yet obtained official confirmation of this.  There can be no assurance that CNPC will approve an extension of the exploration period or approve the Farmout Agreement with Arrow.

For further discussion of our interests in these properties, see the discussion of our production sharing contracts and farmout agreements under "Our Holdings in the Shanxi Province of the People's Republic of China" and "Our Holdings in the Yunnan Province of the People's Republic of China" contained in Item 1, Business.


Other Properties

Our principal office is located at 363 N. Sam Houston Parkway East, Suite 380, Houston, Texas 77060. The principal office consists of approximately 5,770 square feet under lease at December 31, 2008.  We also maintain offices under lease in the following cities of the People's Republic of China:  Beijing, Taiyuan, and Kunming.


ITEM 3. LEGAL PROCEEDINGS

We have no knowledge of any pending or threatened material litigation, settlement of litigation, or other material claim involving us.


PART II

ITEM 5. MARKET FOR THE REGISTRANT'S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES


Common Stock

Our common stock is not listed for trading on a registered exchange. Shares of our common stock are traded over the counter and quoted on the OTC Bulletin Board under the symbol "FEEC." The OTC Bulletin Board provides information to professional market makers who match sellers with buyers. The high and low bid quotations of our common stock presented below includes intra-day trading prices. These quotations represent inter-dealer prices, without retail mark-up, mark-down, or commissions, and may not represent actual transactions.


   
High
    
Low
  
2009
            
First Quarter
   $ 0.30     $ 0.16  
Second Quarter
   $ 0.45     $ 0.20  
Third Quarter
   $ 0.70     $ 0.30  
Fourth Quarter
   $ 0.60     $ 0.35  
                 
2008
                
First Quarter
   $ 1.00     $ 0.38  
Second Quarter
   $ 0.99     $ 0.45  
Third Quarter
   $ 0.70     $ 0.22  
Fourth Quarter
   $ 0.32     $ 0.09  
 
On March 12, 2010, we had 185.5 million shares of common stock outstanding and approximately 85 stockholders of record.

We currently intend to retain all future earnings to fund the development and growth of our business. We have not paid dividends on our common stock and do not anticipate paying cash dividends in the immediate future. We did not repurchase any of our equity securities in 2009 and have not adopted a stock repurchase program.

Stock Performance Graph

The following graph compares the performance of the Company's common stock with that of the S&P 500 Index and the Dow Jones Oil & Gas Index. The graph sets forth the cumulative total stockholder return, which assumes reinvestment of dividends, of a $100 investment on December 31, 2004 in the Company's common stock, the S&P 500 Index and the Dow Jones Oil & Gas Index.

 

   
Cumulative Total Return
  
   
12/31/04
    
12/31/05
    
12/31/06
    
12/31/07
    
12/31/08
    
12/31/09
  
Far East Energy Corporation
   $ 100.00     $ 111.48     $ 74.59     $ 78.69     $ 14.34     $ 37.70  
Dow Jones Oil & Gas Index
     100.00       134.09       164.62       221.98       142.57       167.19  
S&P 500 Index
     100.00       104.91       121.48       128.16       80.74       102.11  
 
The information included under this section entitled "Stock Performance Graph" is deemed not to be "soliciting material" or "filed" with the SEC, is not subject to the liabilities of Section 18 of the Exchange Act, and shall not be deemed incorporated by reference into any of the filings previously made or made in the future by our company under the Exchange Act or the Securities Act, except to the extent the Company specifically incorporates any such information into a document that is filed.


Issuer Withholdings and Subsequent Cancellations of Equity Securities

Column (a) in the tabulation below indicates shares which were withheld by us to satisfy tax withholding obligations that arose upon the vesting of shares of nonvested stock (also commonly referred to as restricted stock) during 2009.  Once withheld, these shares were cancelled and removed from the number of outstanding shares.  Currently, the Company does not have a share repurchase plan.

Period
  
(a)
Total Number of Shares Purchased
    
(b)
Average Price Paid Per Share
    
(c)
Total Number of Shares Purchased as Part of Publicly Announced Plan or Programs
    
(d)
Maximum Number of Shares that May Yet Be Purchased Under The Plans or Programs
  
February 2009
     13,107     $ 0.69       -       -  
October 2009
     3,968       0.30       -       -  
Total
     17,075     $ 0.60       -       -  
 

ITEM 6. SELECTED FINANCIAL DATA
(In Thousands, Except Per Share Data)

   
As of and for the Years Ended December 31,
  
   
2009
    
2008
    
2007
    
2006 (1)
    
2005
  
Operating Results Data
                              
Operating revenues
   $ -     $ -     $ -     $ -     $ -  
Operating expenses:
                                        
Exploration costs (2)
     4,503       15,283       3,345       1,914       3,510  
Leasehold operating expense
     1,892       2,904       1,945       958       -  
General and administrative
     6,479       4,515       7,230       7,903       5,052  
Impairment loss
     -       -       -       -       -  
Amortization of contract rights
     -       -       -       -       -  
Total operating expenses
     12,874       22,702       12,520       10,775       8,562  
Operating loss
     (12,874 )     (22,702 )     (12,520 )     (10,775 )     (8,562 )
Other income (expense):
                                        
Interest expense
     (863 )     -       -       -       -  
Interest income
     5       260       721       560       293  
Gain on sale of assets
     (5 )     -       -       -       8  
Foreign currency exchange loss
     (18 )     (149 )     (50 )     (128 )     (31 )
Total other income (expense)
     (881 )     111       671       432       270  
Loss before income taxes
     (13,755 )     (22,591 )     (11,849 )     (10,343 )     (8,292 )
Income taxes
     -       -       -       -       -  
Net loss
   $ (13,755 )   $ (22,591 )   $ (11,849 )   $ (10,343 )   $ (8,292 )
                                         
Earnings per share: Basic and diluted
   $ (0.08 )   $ (0.15 )   $ (0.09 )   $ (0.10 )   $ (0.10 )
                                         
Financial Position Data
                                        
Total assets
   $ 42,404     $ 39,883     $ 49,793     $ 45,654     $ 27,011  
Total liabilities
     14,734       4,572       3,298       3,943       2,830  
Stockholders' equity
     27,670       35,311       46,495       41,711       24,181  
 
 
(1)
During the fourth quarter of 2006, we determined that the functional currency for our Chinese operations for 2006 and prior reporting periods included in this Annual Report on Form 10-K was U.S. Dollars, instead of the Chinese RMB as previously reported and utilized.  For additional information, see "Foreign Currency Transactions" in Note 1 to the consolidated financial statements.
 
(2)
For additional information on our Exploration costs, see Item 7, "Managements Discussion and Analysis of Financial Condition and Results of Operations – Critical Accounting Policies" and Note 5 to the consolidated financial statements.


ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

The following discussion and analysis of our financial condition and results of operations should be read in conjunction with our audited consolidated financial statements and related notes and all of the other information contained elsewhere in this report.  The terms "we," "us," "our" and "our company" refer to Far East Energy Corporation and its consolidated subsidiaries.

Overview.  We are a development stage company, and our activities include principally drilling, testing, completing and dewatering of exploratory coalbed methane ("CBM") wells, preparing for possible gas sales in the future and organizational activities. We believe that good environmental, social, health and safety performance is an integral part of our business success. We conduct our business with respect and care for our employees, contractors, communities, and the environments in which we operate.  Our vision is zero harm to people and the environment while creating value for our shareholders as well as for China, including the regions and communities within which we operate.  Our commitment to these principles is demonstrated by the fact that we have had no lost-time accidents in the past 4.5 years-plus and no major environmental incidents.  We have a commitment to being good corporate citizens of China, striving to emphasize and utilize very high levels of Chinese content in personnel, services, and equipment; and we have achieved very high percentages of Chinese content in each category.

During 2009, we continued our efforts to explore and develop CBM in Shanxi Province in northern People's Republic of China ("PRC" or "China") and in Yunnan Province in southern PRC.  We continued to employ numerous safety precautions to ensure the safety of our employees and independent contractors.  We also conducted our operations in accordance with various laws and regulations concerning the environment, occupational safety and health.

On March 13, 2009, we formed a strategic alliance related to our Qinnan Block with Arrow Energy International Pte Ltd ("Arrow"), the Singapore-based subsidiary of Arrow Energy Limited, a large Australian CBM producer.  For additional information on the strategic alliance, see "Capital Resources and Liquidity" and Item 1. "Business – Strategic Alliance with Arrow."  Assuming that we obtain approval from our Chinese partner company and the MOC, and satisfy the other conditions under the Farmout Agreement with Arrow, then the additional payment due upon the occurrence of these events from Arrow together with funds currently available should provide sufficient working capital to meet our currently planned work programs through 2010.  Our current work programs would satisfy the minimum exploration expenditures for all three of our PSCs for 2010.      

Although we believe the results of our exploration activities in Shanxi and Yunnan Provinces to date have been favorable, we will need to complete more wells to achieve commercial viability in these provinces, which will require additional capital expenditures.  Management intends to continue to seek to obtain funds by entering into a strategic relationship or transaction, such as a joint venture or farmout and/or obtaining debt or equity financing.  The global financial crisis has created liquidity problems for many companies and financial institutions and international capital markets have stagnated, especially in the United States and Europe.  A continuing downturn in these markets could impair our ability to obtain, or may increase our costs associated with obtaining, additional funds through the sale of our securities.  The ongoing crisis has created a difficult environment in which to negotiate and consummate a transaction.  While we will continue to seek to raise funds, there can be no assurance that we will be able to enter any strategic relationship or transaction or that we will be successful in obtaining funds through debt or equity financing.  Under certain circumstances, the structure of a strategic transaction may require the approval of the Chinese authorities, which could delay closing or make the consummation of a transaction more difficult.  In particular, any transfer of our rights under the PSCs will require the approval of our Chinese partner company and the MOC.  There can be no assurance that the Chinese authorities will provide the approvals necessary for a transaction or transfer.  In addition, the terms and conditions of any potential strategic relationship or transaction or of any debt or equity financing are uncertain and we cannot predict the timing, structure or other terms and conditions of any such arrangements.  There can be no guarantee of future fundraising or exploration success or that we will realize the value of our unevaluated exploratory well costs.  Management believes that we will continue to be successful in obtaining the funds necessary to continue as a going concern.

 
Shouyang Block, Shanxi Province.  During the third quarter of 2009, the MOC approved a modification agreement (the "2009 Shouyang PSC Modification Agreement"), which among other provisions, extended Phase III of the exploration period to June 30, 2011 from June 30, 2009.

The 1H Pilot Area of the Shouyang Block is being closely monitored and work programs are being carried out there to achieve three primary goals: (i) to enlarge our pilot area and continue to expand the area in our 1H Pilot where critical desorption and gas production have begun to occur thereby increasing gas production, (ii) to add step out wells that will help delineate the geographic extent of the high permeability and high gas content area and, (iii) to determine the optimal approach to minimize costs and maximize gas recovery.  To reach these goals, we drilled six horizontal wells, twelve vertical wells, six deviated wells and three parameter wells by the end of fall 2009.

The deviated wells represent another phase in the process of reducing costs.  These are essentially vertical wells drilled at a very high angle from an existing well pad and location. Utilizing an existing well location allows more than one well to be drilled from the same pad, consequently reducing land and pad construction costs, as well as reducing environmental impact.  Once drilled to the coal seam, the wells were fracture stimulated.  We have gained insights over time as to situations where cavitation or hydraulic fracture stimulation may improve our dewatering efficiency in the pilot area.  Hydraulic fracturing is a stimulation method successfully used in other gas shale and coalbed reservoirs to improve wellbore productivity by providing channels that extend beyond any formation damage done to the wellbore during the drilling process.  This allows for water and gas to more easily flow into the wellbore and then be produced.  

In December 2009, we commenced a winter drilling program at the Shouyang Block to drill eight new wells. We plan to complete the winter drilling program and drilling of three additional new wells by early April, thus fully utilizing the five rigs available to us, and bringing the number of completed wells to ten by April.  Of these eleven wells, nine are program wells drilled in the 1H Pilot Area to expand the field to the west and increase the amount of gas being produced to commercial levels in the second half of 2010; while two are parameter wells drilled several kilometers to the west and southwest to obtain further information regarding the geographic extent of the high permeability/high gas content area.
 
Current plans call for those rigs to commence five more wells in April and early May, and three more in early June with the emphasis increasingly shifting to drilling parameter wells at four to six kilometer intervals to the west, south, and east with the goal of demonstrating that there is a very large area of the Shouyang Block that contains high gas content as well as good permeability characteristics. Of the five wells to be spudded in April and early May, four will be parameter wells seeking to show that much of the northern area of the Shouyang Block shares the same rare combination of high permeability and high gas content discovered in the 1H Pilot Area.  The three wells planned to be commenced in June will also be parameter wells.

In summary, our plan is to include the following in our drilling programs in the near future:

 
·
Finish the winter drilling program by April – eleven wells (nine in the 1H Pilot Area and two parameter wells to the west and southwest of the 1H Pilot Area);
 
·
April and early May – five wells, four of which are parameter wells; and
 
·
Early June – three wells, all parameter wells.

To date, the 1H Pilot wells, as well as  the parameter wells drilled at intervals of four to six kilometers to the south and to the west of the 1H Pilot Area have revealed permeability ranging from 10 to 80 millidarcies.  Permeability in the 2H area, about seven kilometers south of the 1H Pilot Area, appears to be around 60 millidarcies.  In the area surrounding the  P2, about six kilometers west of the 1H Pilot area, the permeability appears to be between 10 and 20 millidarcies; while in the  area surrounding the P3 well, about six kilometers southwest of the 1H Pilot Area, the permeability appears to be about 10 to 15 millidarcies.  This range of permeability compares favorably with a number of successful CBM fields.  With permeabilities ranging from areas of 10 millidarcies to 80 millidarcies, the Shouyang Block seems to have  an area of high permeability coupled with high gas.


The Company also plans to conduct four fracture stimulation programs over the next five months:

 
·
Beginning mid-March - twelve wells;
 
·
April - seven wells, including three in the 1H Pilot area;
 
·
June - three wells; and
 
·
July - probably four wells.

All of these wells will be fractured using the improved methods discovered by FEEC during its 2009 Work Program, which included using resin-coated sand to improve the stability and durability of the fracs.  The Company also announced that the remaining wells should be spudded  during the winter program  shortly after the Chinese New Year holiday and the final fracture process is scheduled to be completed to finish the  work on the winter drilling and testing program by the end of April.  The Company explained that each of the wells being drilled and fractured will be completed and dewatering will begin immediately thereafter in the Number 15 coal seam for each of these newly drilled wells.

Far East also announced the initial results of the production capacity tests on the Number 9 coal seam for four wells. It is too early to be able to predict the total gas production capacity of these wells in the Number 9 coal seam but it does appear that compared with the Number 15 coal seam in the 1H Pilot Area, the Number 9 coal seam has a higher gas saturation level which could allow the Company to produce CBM from that coal seam with a shorter dewatering period than has been necessary in the Number 15 coal seam.

Instead of continuing to flare the current gas production, Far East believes it could initiate gas sales as early as the third quarter of 2010.  We are in discussions with three separate parties (two pipelines and one CNG company) regarding the potential off-take and sale of gas produced from the 1H Pilot Area.  The two pipeline companies are planning to lay lines approximately 18 inches in diameter near the Shouyang Area.  One of the pipeline companies recently stated that it would consider slightly re-routing its line to come to within approximately two kilometers of Far East’s 1H Pilot Area, with that company’s pipeline expected to be completed by July or August.  That pipeline is being built to take gas off the Shanjing II pipeline that runs from Western China to Beijing and to move that gas towards the provincial capital of Shanxi Province.  Its route was already planned to pass within five to seven kilometers of the 1H Pilot Area.  Additionally, the pipeline company has stated that it does not intend to require that Far East guarantee volumes of gas.  Normally, in order to induce a pipeline to build to a producing area, the producer must guarantee that a certain volume of gas will be available to the pipeline.

Qinnan Block, Shanxi Province.  Phase III of the exploration period under the Qinnan PSC expired on June 30, 2009.  We have had discussions with CNPC regarding the extension of the exploration period.  At CNPC's request, we have provided certain operational and financial information about our Company to assist them in the decision making process.  Recently, CNPC has completed an accounting audit pursuant to the Qinnan PSC of our expenditures for 2007 and 2008.  There can be no assurance that we will be successful in extending the Qinnan PSC.  For many months CNPC has been awaiting authorization from the Chinese government allowing it to deal with foreign partners on CBM projects. On March 7, 2010, several major news outlets reported that CNPC stated that it has been authorized to jointly develop coalbed methane projects with foreign partners, but we have not yet obtained official confirmation of this.  There can be no assurance that CNPC will approve an extension of the exploration period or approve the Farmout Agreement with Arrow.  Future work program at the Qinnan Block depends largely on whether the exploration period of the Qinnan PSC will be extended as well as whether the necessary Chinese government approvals will be obtained for the Farmout Agreement with Arrow.

Enhong-Laochang Area, Yunnan Province.  Currently, we are conducting a strategic review of our Yunnan holdings to determine whether they fit within our risk profile given the tight capital markets and general economic downturn.  We take into consideration, among other factors, our overall corporate strategy, the prospective costs and benefits of the acreage, our relationship with our Chinese partner companies and our current cash position in order to formulate an optimal strategy for the Company.  The strategy may include, but not be limited to: (i) minimal capital spending to continue holding the acreage, (ii) sale, farm-out or partial farm-out of the acreage, (iii) full or partial relinquishment of the acreage, or (iv) continued staged exploration of the acreage.  We have not yet concluded this review and cannot make any projection as to the likely outcome of this review.  Moreover, CUCBM will have its own view and certain outcomes will be subject to CUCBM and MOC approval.

 
Because there are no pipelines currently in the vicinity of our Yunnan Province projects, our ability to sell CBM produced on these projects to communities outside the general area will be contingent upon a gas pipeline, CNG facility or other off-take vehicle being built close to our project area.  We estimate the initial cost to construct a connecting pipeline and compression facilities from our project area to the nearest large cities, Qujing and Kunming, may be in the range of $20 million to $50 million or more.  Recently, it is reported that CNPC will undertake a pipeline construction project with support from the Yunnan provincial government to extend the Myanmar-China natural gas pipeline to pass through the city of Kunming, then go northward through the city of Zhaotong, and finally connect with major interprovincial pipelines in Sichuan Province. Further, the pipeline plans are expected to include a branch that is expected to connect Kunming to Qujing.  We believe that the construction, which would lay pipelines closer to our projects, would help reduce the cost for CBM off-take from our projects and increase our ability to eventually deliver gas to consumers.  If CUCBM elects a 40% participating interest in Yunnan Province project, our costs would be reduced accordingly.

Production Sharing Contracts.  Our operations in the Shouyang and Qinnan Blocks in Shanxi Province and the Enhong-Laochang area of Yunnan Province are conducted under three separate production sharing contracts ("PSCs").  The two Shanxi PSCs and the Yunnan PSC will expire on July 1, 2032 and January 1, 2033, respectively, subject to the existence of commercially productive reserves and unless extended or otherwise amended.

The three PSCs are divided into three periods: exploration, development and production. All three PSCs are in the exploration period, although the exploration period of the Qinnan PSC expired on June 30, 2009, and is the subject of the extension request discussed elsewhere herein.  Currently, we bear all exploration costs for discovering and evaluating CBM-bearing areas during the exploration period.  During the third quarter of 2009, the MOC approved modification agreements to extend the exploration periods for the Shouyang PSC and the Yunnan PSC to June 30, 2011. CUCBM is our Chinese partner company in these PSCs and has the right to participate in up to 30% of the interest in the Shouyang PSC and up to 40% of the interest in the Yunnan PSC.  CNPC has recently replaced CUCBM as our Chinese partner company for the Qinnan PSC. We are continuing to pursue an extension of the exploration period of the Qinnan PSC. It is possible that CNPC might elect to issue a new PSC, which could be on less favorable terms than those in the current PSC. At CNPC's request, we have provided certain operational and financial information about our Company to assist them in the decision making process. Recently, CNPC has completed an accounting audit pursuant to the Qinnan PSC of our expenditures for 2007 and 2008.  There can be no assurance that we will be successful in extending the exploration period of the Qinnan PSC or that a new PSC will be granted. Additionally, in connection with obtaining this extension or a new PSC, we may be required to commit to certain expenditures or to modify the terms or respective ownership interests and/or acreage in the PSC.  If we are unable to raise sufficient funds to commit to these expenditures, it may adversely affect our ability to extend the PSC.

During the exploration period, all expenditures are funded by us.  Expenditures in the development and production periods are funded in proportion to the respective participating share of the participants in the PSC.  If we satisfy the conditions to the Farmout Agreement, including obtaining approval from our Chinese partners and the MOC, and successfully assign 75.25% of our participating interest in the Qinnan PSC to Arrow, Arrow will make an initial payment of $8 million to us, become the operator under the Qinnan PSC, and, subject to certain conditions, will fund all exploration costs associated with the Qinnan PSC up to a maximum of $30 million.  If the conditions to the Farmout Agreement are not satisfied prior to October 15, 2009 (the "Farm-In Deadline"), then either party has the right to terminate the Farmout Agreement by delivering notice of such termination to the other party. The terms of the Farmout Agreement were subsequently amended in October 2009 and then again in November 2009.  The October 2009 amendment changed the Farm-In Deadline to November 20, 2009.  The November 2009 amendment provided, among other things, further changed the Farm-In Deadline to December 19, 2009.  In conjunction with the November 2009 amendment, FEEB and Arrow also agreed that interest on the Exchangeable Note would begin to accrue as originally scheduled on October 16, 2009.  Since December 19, 2009, each of the Company and Arrow have had the right to terminate the Farmout Agreement at any time, though neither party has elected to exercise that right and the parties are continuing to use efforts to satisfy the conditions contemplated by the Farmout Agreement.  Assuming that the Farmout Agreement conditions are met, after Arrow reaches such $30 million cap, FEEB and Arrow will share further Qinnan development costs and any future revenues in proportion to the participating interests in the Qinnan PSC, provided that FEEB may, in its discretion, instead elect to assign all of its interest in the Qinnan PSC to Arrow subject to retaining a 2% overriding royalty interest.  In addition, under the Farmout

 
Agreement, if we obtain Chinese governmental approval of an ODP for the Qinnan area, Arrow will pay FEEB an additional $8 million in cash as a bonus, and FEEB will have the option to assign all of its interest in the Qinnan PSC to Arrow, while retaining a 5% overriding royalty interest.  Qualified project costs incurred under the PSCs by us can be recovered from the value of the first 75% of gross production of CBM for the two Shanxi Province PSCs and 70% of gross production of CBM for the Yunnan PSC.  Participants will pay their proportionate share of the value added tax and State royalty according to the relevant government regulations  In addition, with respect to the Shouyang and Qinnan PSCs, our company must pay ConocoPhillips, Inc. a 3.5% royalty on production.

Results of Operations

Year Ended 2009 compared to Year Ended 2008

The table below sets out major components of our expenditures (in thousands):

   
2009
    
2008
  
Additions to Unevaluated
            
Oil and Gas Properties (capitalized)
            
- Shouyang Block, Shanxi Province (1)
   $ 3,584     $ 6,930  
Exploration Expenditures (expensed)
                
- Shouyang Block, Shanxi Province
     2,093       1,540  
- Qinnan Block, Shanxi Province
     1,558       3,880  
- Yunnan Province
     852       1,956  
- Total
     4,503       7,376 (2)
Lease Operating Expenditures (expensed)
                
- Shouyang Block, Shanxi Province
     1,710       2,860  
- Qinnan Block, Shanxi Province
     182       44  
- Total
     1,892       2,904  
                 
Total Exploration and Operating Expenditures
   $ 9,979     $ 17,210  
                 
General and Administrative Expenses
   $ 6,479     $ 4,515  

 
(1)
Capitalized in the Consolidated Balance Sheets.
 
(2)
Exploration Expenditures shown are different from Exploration costs in the Consolidated Statements of Operations as these expenditures do not include prior year unevaluated exploratory well costs charged to expense of $7.9 million for 2008.

The costs of drilling exploratory wells are capitalized on the Consolidated Balance Sheets as Additions to Unevaluated Oil & Gas Properties pending determination of whether they have discovered proved commercial reserves. If it is determined that no proved commercial reserves are discovered, the related capitalized costs will be expensed on the Consolidated Statements of Operations. Other exploration and lease operating expenditures are charged to expense as incurred.

The table below sets out the operating expenses in the Consolidated Statements of Operations (in thousands):

   
2009
    
2008
    
Increase
(Decrease)
    
%
Change
  
Exploration costs
   $ 4,503     $ 15,283     $ (10,780 )     -71 %
Lease operating expense
     1,892       2,904       (1,012 )     -35 %
General and administrative
     6,479       4,515       1,964       43 %
Total
   $ 12,874     $ 22,702     $ (9,828 )     -43 %
 
 
Exploration costs consist primarily of the write-off of drilling and exploration costs previously capitalized. Accounting for such write-offs is determined by Financial Accounting Standards Board "("FASB") Accounting Standards Codification ("ASC") Topic 932, Extractive Activities – Oil and Gas, which requires that wells be expensed unless a sufficient quantity of reserves has been located to justify completing the well, and the enterprise is making sufficient progress assessing the reserves.  Oil and gas exploration costs, other than the costs of drilling exploratory wells, are charged to expense as incurred. The costs of drilling exploratory wells are capitalized pending determination of whether they have discovered proved commercial reserves.  For further discussion of our accounting policies, see "Critical Accounting Policies—Accounting for Oil and Gas Properties" below.
 
The table below sets out components of exploration costs for the years ended December 31, 2009 and December 31, 2008 (in thousands):

   
Year ended December 31,
  
   
2009
    
2008
  
Capitalized well costs charged to expense
   $ -     $ 7,907  
Seismic data acquisition
     -       84  
Technical personnel compensation
     698       641  
PSC related payments
     1,218       1,044  
Contract drilling & related expenses
     2,587       5,607  
Total
   $ 4,503     $ 15,283  

During 2008, we determined that $7.9 million of capitalized costs incurred previously no longer met the requirements for continued capitalization.  The amount includes $7.0 million related to the FCC-HZ02 well in the Shouyang project.  Accordingly, we charged this amount to exploration costs. There were no comparable charges in 2009. Exploration costs also decreased due primarily to a higher contract drilling and related expenses for 2008 related to the Yunnan PSC of $1.1 million and the Qinnan PSC of $2.2 million.

The table below sets out components of Lease Operating Expense ("LOE") expense for the years ended December 31, 2009 and December 31, 2008 (in thousands):

   
Year ended December 31,
  
   
2009
    
2008
  
Workovers
   $ 292     $ 1,266  
Pumping Related Costs
     1,379       1,265  
Supervision
     221       373  
Total
   $ 1,892     $ 2,904  

LOE for 2009 was comprised of costs pertaining to the dewatering efforts in the Shouyang and Qinnan Blocks in Shanxi Province, which presently have sustained low rates of small gas production. To date, the production is not at commercial levels and the data obtained is not sufficient to project when or if the wells will achieve commercial gas production rates and what those rates may be.  LOE for the year ended December 31, 2009 decreased primarily due to a decrease in workovers of $1.0 million partially offset by an increase in pumping related costs of $0.1 million. As of December 31, 2009, 29 wells were being dewatered: 7 horizontal wells, 6 deviated wells and 16 vertical wells. As of December 31, 2008, 20 wells were being dewatered: 5 horizontal wells, 3 deviated wells and 12 vertical wells.

General and administrative (“G&A”) expenses included non-cash items, primarily share-based compensation and depreciation, totaled $1.1 million and a negative $0.5 million for 2009 and 2008, respectively.  In 2008, a $2.1 million downward adjustment was made to previously recognized share-based compensation costs to reflect higher estimated forfeiture rates. Excluding the downward adjustment in 2008, G&A expenses for 2009 and 2008 were comparable.


Year Ended 2008 compared to Year Ended 2007

The table below sets out major components of our expenditures (in thousands):

   
2008
    
2007
  
Additions to Unevaluated
            
Oil and Gas Properties (capitalized)
            
- Shouyang Block, Shanxi Province (1)
   $ 6,930     $ 7,326  
- Yunnan Province
     -       331  
- Total
     6,930       7,657  
Exploration Expenditures (2)
                
- Shouyang Block, Shanxi Province
     1,540       1,128  
- Qinnan Block, Shanxi Province
     3,880       1,167  
- Yunnan Province
     1,956       893  
- Total
     7,376       3,188  
Lease Operating Expenditures (expensed)
                
- Shouyang Block, Shanxi Province
     2,860       1,945  
- Qinnan Block, Shanxi Province
     44       -  
- Total
     2,904       1,945  
Total Exploration and Operating Expenditures
   $ 17,210     $ 12,790  
                 
General and Administrative Expenses
   $ 4,515     $ 7,230  
 
 
(1)
Capitalized on the Consolidated Balance Sheets.
 
(2)
Exploration Expenditures shown are different from Exploration costs in the Consolidated Statements of Operations as these expenditures do not include prior year unevaluated exploratory well costs charged to expense of $7.9 million for December 31, 2008 and $0.2 million for December 31, 2007.

The table below sets out the operating expenses in the Consolidated Statements of Operations (in thousands):

   
2008
    
2007
    
Increase
(Decrease)
    
%
Change
  
Exploration costs
   $ 15,283     $ 3,345     $ 11,938       357 %
Lease operating expense
     2,904       1,945       959       49 %
General and administrative
     4,515       7,230       (2,715 )     -38 %
Total
   $ 22,702     $ 12,520     $ 10,182       81 %

The table below sets out components of exploration costs for the years ended December 31, 2008 and December 31, 2007 (in thousands):

   
Year ended December 31,
  
   
2008
    
2007
  
Capitalized well costs charged to expense
   $ 7,907     $ 157  
Seismic data acquisition
     84       320  
Technical personnel compensation
     641       430  
PSC related payments
     1,044       1,007  
Contract drilling & related expenses
     5,607       1,431  
Total
   $ 15,283     $ 3,345  
 
 
During 2008, we determined that $7.9 million of capitalized costs incurred previously no longer met the requirements for continued capitalization.  The amount includes $7.0 million related to the FCC-HZ02 well in the Shouyang project.  Accordingly, we charged this amount to exploration costs. Comparable charges in 2007 were $0.2 million.  Exploration costs also increased due to higher contract drilling and related expenses of $4.2 million as a result of increased drilling activities and higher employee compensation of technical personnel of $0.2 million, which consisted primarily of non-cash share-based compensation. The increases were partially offset by a decrease in the cost of the acquisition of seismic data in the Qinnan Block of $0.2 million.

The table below sets out components of LOE expense for the years ended December 31, 2008 and December 31, 2007 (in thousands):

   
Year ended December 31,
  
   
2008
    
2007
  
Workovers
   $ 1,266     $ 840  
Pumping Related Costs
     1,265       792  
Supervision
     373       313  
Total
   $ 2,904     $ 1,945  
 
LOE for 2008 was comprised of costs pertaining to the dewatering efforts in the Shouyang and Qinnan Blocks in Shanxi Province, which presently have sustained low rates of small gas production. To date, the production is not at commercial levels and the data obtained is not sufficient to project when or if the wells will achieve commercial gas production rates and what those rates may be.  LOE for the year ended December 31, 2008 increased primarily due to an increase in workovers of $0.4 million and an increase in pumping related costs of $0.4 million.  As of December 31, 2008, 20 wells were being dewatered: 5 horizontal wells, 3 deviated wells and 12 vertical wells. As of December 31, 2007, 5 wells were being dewatered: 4 horizontal wells and 1 vertical well.

G&A expenses included non-cash items, primarily share-based compensation and depreciation, totaled a negative $0.5 million and $1.4 million for 2008 and 2007, respectively.  G&A expenses for 2008 decreased primarily due to a $2.1 million adjustment made to previously recognized share-based compensation costs to reflect higher estimated forfeiture rates. Other decreases in general and administrative expenses for 2008 are due to actions taken to reduce expenses of $0.2 million in light of the change in the global economic conditions, reduction in travel expense of $0.1 million, and a reduction in third party investor relations and web-site hosting of $0.2 million. Additionally, insurance expense in 2008 was lower by $0.1 million.
 
Capital Resources and Liquidity

We have no source of revenue or cash flow from operations, and our primary source of cash flow has been cash proceeds from public offerings and private placements of our common stock and warrants to purchase our common stock, and the exercise of warrants and options to purchase our common stock.

On March 13, 2009, the Company and FEEB formed a strategic alliance related to our Qinnan Block with Arrow, the Singapore-based subsidiary of Arrow Energy Limited.  Specifically, on that date, (i) FEEB and Arrow entered into the Farmout Agreement  under which, subject to certain conditions, FEEB will assign to Arrow 75.25% of its rights (the "Assignment") in the Qinnan PSC, (ii) the Company, FEEB and Arrow entered into a Securities Purchase Agreement (the "Purchase Agreement"), (iii) FEEB issued an Exchangeable Note, $10 million principal amount (the "Exchangeable Note"), to Arrow for $10 million in cash, (iv) the Company issued a Warrant (the "Warrant") to Arrow for 7,420,000 shares of the Company's common stock, par value $0.001 per share (the "Common Stock"), at an exercise price of $1.00 per share, and (v) the Company and Arrow entered into a Registration Rights Agreement (the "Registration Rights Agreement" and, collectively with the other agreements described in the preceding clauses (i) through (iv), the "Agreements").

Farmout Agreement.  The Farmout Agreement conditions the Assignment on, among other things, the receipt of required approvals from the government of the PRC (collectively, the "Farm-In Conditions") on or prior to December 19, 2009 or such later date as the parties may agree upon (the "Farm-In Deadline").  The terms of the

 
Farmout Agreement were subsequently amended in October 2009 and then again in November 2009.  The October 2009 amendment changed the Farm-In Deadline to November 20, 2009.  The November 2009 amendment provided, among other things, further changed the Farm-In Deadline to December 19, 2009.  In conjunction with the November 2009 amendment, FEEB and Arrow also agreed that interest on the Exchangeable Note would begin to accrue as originally scheduled on October 16, 2009.  Since December 19, 2009, each of the Company and Arrow have had the right to terminate the Farmout Agreement at any time, though neither party has elected to exercise that right and the parties are continuing to use efforts to satisfy the conditions contemplated by the Farmout Agreement.  There can be no assurance that our Chinese partners or the MOC will approve the Farmout Agreement.  The parties are required to exercise their respective commercially reasonable efforts in good faith to satisfy the Farm-In Conditions under the current Farmout Agreement, upon satisfaction of the Farm-In Conditions, Arrow will make an initial payment to the Company of $8 million, and, subject to certain conditions, including government approval for the extension of the current exploration period, Arrow will fund all exploration costs associated with the Qinnan PSC up to a maximum of $30 million.  After Arrow reaches such $30 million cap, FEEB and Arrow will share further Qinnan area exploration costs in proportion to their participating interests in the Qinnan PSC, provided that FEEB may, in its discretion, instead elect to assign all of its interest in the Qinnan PSC to Arrow subject to retaining a 2% overriding royalty interest.  In addition, under the Farmout Agreement, if the parties obtain Chinese governmental approval of an ODP for the Qinnan area, Arrow will pay FEEB an additional $8,000,000 in cash as a bonus, and FEEB will have the option to assign all of its interest in the Qinnan PSC to Arrow, while retaining a 5% overriding royalty interest.  If an overall development program is approved, then FEEB and Arrow will share related development costs and any future revenues for such area on a pro-rata basis in accordance with their participating interests in the Qinnan PSC.

As discussed above, if the Farm-In Conditions are not satisfied prior to the Farm-In Deadline, then either party has the right to terminate the Farmout Agreement by delivering notice of such termination to the other party.  In addition to the foregoing, the Farmout Agreement contains certain customary representations, warranties and covenants of the parties.  Further, if certain events of default occur, then FEEB will be entitled to exercise rights to revoke the Assignment and the Farmout Agreement will automatically terminate.

Purchase Agreement.  Under the Purchase Agreement, FEEB issued Arrow the Exchangeable Note, the Company issued Arrow the Warrant and Arrow paid FEEB $10 million in cash.

Exchangeable Note.  The Exchangeable Note has an initial principal amount of $10 million and bears interest at a rate of 8% per annum, which began to accrue on October 16, 2009 and matures on March 13, 2011 (the "Maturity Date"), unless repaid earlier.  Principal and interest is due and payable on the Maturity Date or earlier if payment is accelerated upon the occurrence and continuance of an event of default (addressed below).

Arrow has the right at any time to exchange the Exchangeable Note in whole or in part for shares of Common Stock at an exchange rate of 21,052.63 shares per $10,000 (or $0.475 per share) of principal and interest (the "Exchange Rate"), subject to certain equitable adjustment mechanisms in the event of a sale of the Company, stock split or similar occurrence.  However, if certain conditions to the effectiveness of the Assignment are satisfied on or before the Farm-In Deadline, the entire principal amount of the Exchangeable Note will automatically be exchanged for shares of Common Stock at the Exchange Rate, subject to the same adjustment mechanisms.

The Exchangeable Note contains certain restrictive covenants applicable to the Company and FEEB, including, among others, restrictions on the incurrence of indebtedness that ranks senior to or pari passu with the Exchangeable Note and restrictions on FEEB's ability to sell all of its rights under Shouyang PSC.  The Company has guaranteed FEEB's payment obligations under the Exchangeable Note.  For additional information on the restrictive covenants and events of default under the Exchangeable Note, see Item 1. "Business – Strategic Alliance with Arrow."

Warrant.  The Warrant entitles Arrow to purchase 7,420,000 shares of Common Stock at an exercise price of $1.00 per share, subject to certain equitable adjustment mechanisms in the event of a sale of the Company, stock split or similar occurrence.  The Warrant expired in December 2009.

 
Assuming that we obtain approval from our Chinese partner company and the MOC, and satisfy the other conditions under the Farmout Agreement with Arrow, then the additional payment due upon the occurrence of these events from Arrow together with funds currently available should provide sufficient working capital to meet our currently planned work programs through 2010.  Our current work programs would satisfy the minimum exploration expenditures for all three of our PSCs for 2010.  Our ability to continue as a going concern depends upon our ability to obtain substantial funds for use in our development activities and upon the success of our planned exploration and development activities. There can be no guarantee of future fundraising or exploration success or that we will realize the value of our unevaluated exploratory well costs. The consolidated financial statements included in this Annual Report on Form 10-K do not include any adjustments that might result from the outcome of this uncertainty.  Management believes that we will continue to be successful in obtaining the funds necessary to continue as a going concern.


Cash flow

As of December 31, 2009, 2008 and 2007, cash and cash equivalents were $5.6 million, $7.9 million and $16.9 million, respectively.  The decrease of $2.3 million in cash and cash equivalents from beginning to end of the fiscal year 2009 was primarily due to cash outflows related to field operations of approximately $8.8 million,  G&A expenditures of approximately $5.4 million, restricted cash of $2.0 million set aside for the exploration expenditures in the Qinnan Block from the proceeds of the Exchangeable Note and costs associated with the strategic alliance with Arrow of approximately $0.5 million, partially offset by the net proceeds from the issuance of the Exchangeable Note of $10 million related to the strategic alliance with Arrow and $4.4 million related to the sale of shares of common stock in December 2009.  During the period from the formation of the strategic alliance with Arrow to the end of the fourth quarter, we used approximately $1.3 million of the $2 million restricted cash for exploration expenditures related to the Qinnan Block.  As of December 31, 2009, our balance in restricted cash was $0.7 million.

Cash used in operating activities for 2009 was $12.7 million as compared to $13.3 million for 2008 and $10.8 million for 2007.  We generated no revenue in any of those years. The decrease in cash used in operating activities in 2009 of $0.6 million as compared to 2008 was due primarily to decreased exploratory contract drilling and related expenses of $3.0 million, decreased in LOE workover costs of $1.0 million, partially offset by an unfavorable change in working capital of $2.6 million, an increase in cash G&A of $0.4 million and an increase in PSC related payments of $0.2 million.    The increase in cash used in operating activities in 2008 as compared to 2007 was due primarily to increased exploration costs and operating expense, partially offset by an increase in total accounts payable and accrued liabilities.  Operating expense for 2008 increased as a result of our expanded dewatering efforts.  Dewatering efforts in 2008 related to a total of 20 wells: 5 horizontal wells, 3 deviated wells and 12 vertical wells. Dewatering efforts in 2007 related to a total of 5 wells: 4 horizontal wells and 1 vertical well.

Cash used in investing activities for 2009 was $3.5 million, as compared to $7.6 million for 2008 and $8.1 million for 2007.  The decrease of $4.1 million was primarily due to a decrease in additions to unevaluated oil and gas properties of $3.9 million.  In 2008, cash used in investing activities was lower than in 2007 due primarily to a decrease in capitalized drilling costs of $0.3 million.  

Cash provided by financing activities for 2009 was $13.9 million, as compared to $11.8 million for 2008 and $15.2 million for 2007.  Cash provided by financing activities for 2009 of $13.9 million was a result of the $10 million in proceeds from the issuance of the Exchangeable Note in the first quarter of 2009 and the sale of 11.6 million shares of our common stock and warrants to purchase up to 4.6 million shares of our common stock in the fourth quarter of 2009 for $4.4 million.  The increase was partially offset by the total financing costs of $0.5 million.  Cash provided by financing activities for 2008 of $11.8 million was a result of the sale of 24 million shares of our common stock and warrants to purchase up to 8.4 million shares of our common stock in the second quarter of 2008.   Cash provided by financing activities for 2007 of $15.2 million was a result of the sale of approximately 11.5 million shares of common stock and warrants to purchase up to approximately 4 million shares of common stock for $14.8 million as well as proceeds of $0.4 million from the exercise of options to purchase our common stock.


Capital Resources and Requirements

Our board of directors has the authority, without further action by the stockholders, to issue up to 500 million shares of preferred stock in one or more series and to designate the rights, preferences, privileges and restrictions of each series. We also have 500 million shares of common stock authorized under our charter documents, of which approximately 173.8 million shares were issued and outstanding as of December 31, 2009. In September 2009, we filed with the SEC a shelf registration statement on Form S-3 for the offer and sale from time to time up to $75 million of our debt and equity securities.  The amount available under the registration statement at March 12, 2010 was approximately $65.1 million.

The issuance of preferred stock could have the effect of restricting dividends on the common stock or delaying or preventing our change in control without further action by the stockholders. While we have no present plans to issue any shares of preferred stock, we may need to do so in the future in connection with capital raising transactions. In addition, we may issue additional shares of common stock in connection with capital raising activities. The issuance of additional common stock would also have a dilutive impact on our stockholders' ownership interest in our company.

The exploration and development of CBM reserves requires substantial capital expenditures. In order to reduce our required investment in a particular project, we may form joint ventures and seek joint venture partners to share the costs. We incurred approximately $10.0 million of costs related to exploratory activities during 2009.  Assuming that we obtain approval from our Chinese partner company and the MOC, and satisfy the other conditions under the Farmout Agreement with Arrow, then the additional payment due upon the occurrence of these events from Arrow together with funds currently available should provide sufficient working capital to meet our currently planned work programs through 2010.  Our current work programs would satisfy the minimum exploration expenditures for all three of our PSCs for 2010.  We may expand our capital and related expenditures, depending on the timing of our receipt of any funds from our fundraising efforts and on whether results from our current exploratory activities indicate that it is beneficial for us to incur the additional expenditures.

We will also require resources to fund significant capital expenditures for exploration and development activities and to fund operating expenses in future periods. We are not able to accurately predict when we will recognize meaningful revenues.  CBM projects traditionally require multiple wells to properly dewater the coal and generate predictable volumes of gas. To generate revenue prior to the point at which production reaches pipeline quantities, we may elect to install compressors and produce compressed natural gas ("CNG"), which could be sold to local communities. Production of CNG would require the installation of a CNG facility, which would likely be constructed and paid for by the purchaser of our gas production. Currently, two national trunklines, one to Beijing and one to Shanghai, traverse China in proximity to our Shanxi Province projects.  However, we are in discussions with three separate parties (two pipelines and one CNG company) regarding the potential off-take and sale of gas produced from the 1H Pilot Area.  Far East believes it could initiate gas sales as early as the third quarter of 2010. The two pipeline companies are planning to lay lines approximately 18 inches in diameter near the Shouyang Area.  One of the pipeline companies recently stated that it would slightly re-route its line to come to within approximately two kilometers of Far East’s 1H Pilot Area, with that company's pipeline expected to be completed by July or August.   That pipeline is being built to take gas off of the Shanjing II pipeline that runs from Western China to Beijing and to move that gas towards the provincial capital of Shanxi Province. Its route was already planned to pass within five to seven kilometers of the 1H Pilot Area.  Therefore, the pipeline company has stated that it does not intend to require that Far East guarantee volumes of gas.  Normally, in order to induce a pipeline to build to a producing area, the producer must guarantee that a certain volume of gas will be available to the pipeline.  If our discussions with the three separate third parties do not result in any commercially viable arrangement and in the absence of any similar arrangement with other companies, pipelines may need to be built on those projects to connect to larger pipelines to transport any CBM that may be produced from those projects.  We estimate the initial cost for these connecting pipelines and compression facilities may be in the range of $10 million to $20 million or more.  If CUCBM elects a 30% participating interest in our Shanxi Province project, our net costs would be reduced accordingly.  Additionally, if we are successful in assigning 75.25% of our current participating interest in the Qinnan PSC to Arrow, our net cost with respect to any project for that PSC would be reduced accordingly.  There is no assurance that any of the existing pipelines we might desire to connect to in the future will have sufficient capacity available to meet our requirements or the costs of using such pipelines would be economical.  Additionally,

 
there is no assurance that we will be able to use the existing pipeline on terms acceptable to us or at all, as the PRC does not require that open access to pipeline infrastructure be allowed.

Assuming that we obtain approval from our Chinese partner company and the MOC, and satisfy the other conditions under the Farmout Agreement with Arrow, then the additional payment due upon the occurrence of these events from Arrow together with funds currently available should provide sufficient working capital to meet our currently planned work programs through 2010.  Our current work programs would satisfy the minimum exploration expenditures for all three of our PSCs for 2010.  However, to develop our projects in China over the long term, we need to obtain project funding to satisfy significant expenditures for exploration and development of those projects, if they are successful. We intend to obtain the funds for our planned exploration and development activities by various methods, which might include issuing equity securities, issuing debt instruments, the exercise of warrants issued to investors in conjunction with the recently completed private offerings, obtaining farmout partners, selling certain property interests, and entering into a strategic transaction, among other alternatives. No assurance can be given that we will be able to obtain any additional financing on favorable terms, if at all. Under certain circumstances, the structure of a strategic transaction may require the approval of the Chinese authorities, which could delay closing or make the consummation of a transaction more difficult.  In particular, any transfer of our rights under the PSCs will require the approval of CUCBM.  There can be no assurance that the Chinese authorities will provide the approvals necessary for a transaction or transfer.  If our operating requirements vary materially from those currently planned, we may require more financing than currently anticipated. Borrowing money may involve pledging some or all or our assets.  Raising additional funds by issuing common stock or other types of equity securities would further dilute our existing stockholders.  If we fail to raise the necessary funds to complete our exploration activities and we cannot obtain any required extensions to the requirements under our PSCs, we would not be able to successfully complete our exploration activities and we may lose rights under our PSCs.

Contractual Obligations

Obligations under non-cancelable agreements at December 31, 2009 were as follows (in thousands):

         
Payments Due by Period
  
   
Total
    
2010
       2011-2012       2013-2014    
2015 and
Beyond
  
Long-Term Debt Obligations
   $ 11,142 (1)   $ -     $ 11,142     $ -     $ -  
Capital Lease Obligations
     -       -       -       -       -  
Operating Lease Obligations (2)
     570       387       183       -       -  
Purchase Obligations (3)
     12,902       8,983       3,919       -       -  
Other Long-Term Liabilities Reflected on the
                                        
   Registrant's Balance Sheet Under GAAP (4)
     339       -       -       -       339  
      Totals
   $ 24,953     $ 9,370     $ 15,244     $ -     $ 339  

____________

(1) Amount represents the total of principal and interest due on March 13, 2011 under the Exchangeable Note, unless repaid earlier.  The Exchangeable Note bears interest at a rate of 8% per annum, which began to accrue on October 16, 2009.  If the approval by Chinese governmental authorities of the assignment to Arrow has been obtained or the requirement to obtain the approval has been waived, the Exchangeable Note will automatically be exchanged in full for shares of common stock at an exchange rate of 21,052.63 shares per $10,000.
(2) We enter into operating leases in the normal course of business primarily for our office space and equipment.
(3)   We include in purchase obligations contractual agreements to purchase goods or services that are legally enforceable and that specify all significant terms, including fixed or minimum quantities, fixed, minimum or variable price provisions and the approximate timing of the transaction. We have included our obligations under the PSCs for the Yunnan Province and the Shanxi Province projects (assuming approval for the Qinnan PSC exploration phase is granted by the Chinese government) for which the amounts were specified in the contracts. We have elected to enter into Phase II for the Yunnan Province project and Phase III for the Shanxi Province projects and have included contractual expenses through completion of these phases, which are currently required to be completed by June 30, 2011.
(4)   Amount represents our asset retirement and environmental obligations.


Off-Balance Sheet Arrangements

As part of our ongoing business, we do not participate in transactions that generate relationships with unconsolidated entities or financial partnerships, such as entities often referred to as structure finance or special purpose entities (SPEs), which would have been established for the purpose of facilitating off-balance sheet arrangements or other contractually narrow or limited purposes. As of December 31, 2009, we were not involved in any form of off-balance sheet arrangement.

Critical Accounting Policies

Our discussion and analysis of our financial condition and results of operations is based on our consolidated financial statements, which have been prepared in accordance with accounting principles generally accepted in the United States. The preparation of our consolidated financial statements requires us to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses. We consider an accounting estimate to be critical if (1) it requires assumptions to be made that were uncertain at the time the estimate was made; and (2) changes in the estimate or different estimates that could have been selected could have a material impact on our results of operations or financial condition.

Management has discussed the development and selection of its critical accounting policies with our Audit Committee, and the Audit Committee has reviewed the disclosures presented below relating to them.

We believe the following critical accounting policies reflect our significant estimates and judgments used in the preparation of our financial statements:

Accounting for Oil and Gas Properties. We use the successful efforts method of accounting for our oil and gas properties. Under this method, oil and gas lease acquisition costs and intangible drilling costs associated with exploration efforts that result in the discovery of proved reserves and costs associated with development drilling, whether or not successful, are capitalized when incurred. If proved commercial reserves are not discovered, such drilling costs are expensed. In some circumstances, it may be uncertain whether proved commercial reserves have been found when drilling has been completed. Under Financial Accounting Standards Board ("FASB") Accounting Standards Codification ("ASC") Topic 932, Extractive Activities – Oil and Gas ("ASC 932"), such exploratory well drilling costs may continue to be capitalized if the reserve quantity is sufficient to justify its completion as a producing well and sufficient progress in assessing the reserves and the economic and operating viability of the project is being made. We assess our capitalized exploratory wells pending evaluation each quarter to determine whether costs should remain capitalized or should be charged to earnings. Other exploration costs, including geological and geophysical costs, are expensed as incurred. We recognize gain or loss on the sale of properties on a field basis.

Unproved leasehold costs are capitalized and reviewed periodically for impairment on a property-by-property basis, considering factors such as drilling and exploitation plans and lease terms. The estimated fair value of unproved leasehold costs includes the present value of probable reserves discounted at rates commensurate with the risks involved in each classification of reserve. Costs related to impaired prospects are charged to expense. An impairment expense could result if oil and gas prices decline in the future or if downward reserves revisions are recorded, as it may not be economic to develop some of these unproved properties.  We also evaluate current drilling results, lease expiration dates, current oil and gas industry conditions, international economic conditions, capital availability, foreign currency exchange rates, political stability in the countries in which the Company has an investment, and available geological and geophysical information. Any impairment assessed is charged to expense.

Share-based Compensation.  We measure the compensation expense for stock options granted as compensation to our employees  based on the grant date fair value of the awarded options under FASB ASC Topic 718, Compensation – Stock Compensation ("ASC 718").  We determine the fair value of stock option grants using the Black-Scholes option pricing model.   We determine the fair value of shares of nonvested stock based on the last quoted price of our stock on the OTC Bulletin Board on the date of the share grant.   The fair value determined represents the cost for the award and is recognized over the vesting period during which an employee is required to provide service in exchange for the award.  As share-based compensation expense is recognized based on awards

 
ultimately expected to vest, we have reduced the expense for estimated forfeitures based on historical forfeiture rates.  Previously recognized compensation costs may be adjusted to reflect the actual forfeiture rate for the entire award at the end of the vesting period.  Excess tax benefits, as defined in ASC 718, if any, are recognized as an addition to paid-in capital.

Impairment of unproved oil and gas properties. Unproved leasehold costs and exploratory drilling in progress are capitalized and are reviewed periodically for impairment. Costs related to impaired prospects or unsuccessful exploratory drilling are charged to expense. The estimated fair value of unproved leasehold costs includes the present value of probable reserves discounted at rates commensurate with the risks involved in each classification of reserve. Our assessment of the results of exploration activities, commodity price outlooks, planned future sales or expiration of all or a portion of such leaseholds impacts the amount and timing of impairment provisions. An impairment expense could result if oil and gas prices decline in the future, as it may not be economical to develop some of these unproved properties. As of December 31, 2009, we had total unproved oil and gas property costs of approximately $34.4 million, consisting of undeveloped leasehold costs of $0.3 million in China and unevaluated exploratory drilling costs of $34.1 million incurred in China.

Estimates of future dismantlement, restoration, and abandonment costs. The accounting for future development and abandonment costs is determined by FASB ASC Topic 410, Asset Retirement and Environmental Obligations requires the fair value of a liability for an asset retirement obligation to be recognized in the period in which it is incurred if a reasonable estimate of fair value can be made. The associated asset retirement costs are capitalized as part of the carrying amount of the long-lived asset. The accrual is based on estimates of these costs for each of our properties based upon the type of production structure, reservoir characteristics, depth of the reservoir, market demand for equipment, currently available procedures and consultations with construction and engineering consultants. Based on our experience and technical and financial data collected from managing our projects over the years, we were able to record the costs related to our asset retirement and environmental obligations in our financial statements beginning the fourth quarter of 2009.  Because these costs typically extend many years into the future, estimating these future costs is difficult and requires management to make estimates and judgments that are subject to future revisions based on numerous factors, including changing technology, the political and regulatory environment, estimates as to the proper discount rate to use and timing of abandonment.

We have drilled a number of horizontal wells and vertical wells in the Shanxi Province and Yunnan Province.  Phillips drilled three wells in the Shanxi Province, which we acquired through our farmout agreements with Phillips.  We will be required to plug and abandon those wells and restore the well site upon completion of their production. Sufficient testing on the wells has not been completed to determine the lives of these wells and, therefore, we have insufficient information to determine the timing of the obligations related to plugging, abandoning and restoring the site and cannot determine the present value of the obligation. Due to the small number of wells, we do not believe the obligation is material, and we will recognize the liability when a reasonable estimate of fair value can be made. Therefore, there is no provision in the accompanying consolidated financial statements.

Assessments of functional currencies.  Periodically, we assess the functional currencies of our Chinese subsidiaries to ensure that the appropriate currencies are utilized in accordance with the guidance in FASB ASC Topic 830, Foreign Currency Matters.  We determine whether the U.S. or the Chinese currency is the appropriate functional currency based on an assessment of the economic and financing environments in which the Chinese subsidiary is situated.  The assessment includes, among other factors, in what currencies the financing and operating expenditures are denominated and whether the subsidiary's operations are sufficient to service additional financings.  The assessment of functional currencies can have a significant impact on periodic results of operations and financial position.


ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

In addition to the U.S. Dollar, we conduct our business in Chinese RMB and, therefore, are subject to foreign currency exchange risk on cash flows related to expenses and investing transactions. Prior to July 2005, the exchange rate between U.S. Dollars and Chinese RMB was fixed, and, consequently, we experienced no fluctuations in the value of goods and services we purchased in China because of currency exchange.  In July 2005, the Chinese government began to permit the Chinese RMB to float against the U.S. Dollar.  All of our costs to operate our Chinese offices are paid in Chinese RMB.  Our exploration costs in China may be incurred under contracts denominated in Chinese RMB or U.S. Dollars.  During 2009, the U.S. Dollar to RMB exchange rate was basically flat, fluctuated within a small range of 1:6.79 to 1:6.84, with a yearly average of 1:6.84.  If the Chinese RMB appreciates with respect to the U.S. Dollar, our costs in China may increase.  To date we have not engaged in hedging activities to hedge our foreign currency exposure.  In the future, we may enter into hedging instruments to manage our foreign currency exchange risk or continue to be subject to exchange rate risk.  If the exchange rate increased by 10%, it is estimated that our costs would  be approximately $0.7 million lower in 2009.  If the exchange rate were 10% lower during 2009, our costs would increase by approximately $0.8 million in 2009.

Although inflation has not materially impacted our operations in the recent past, increased inflation in China or the U.S. could have a negative impact on our operating and general and administrative expenses, as these costs could increase.  In the last couple of years, we have increased our use of Chinese suppliers, including drilling contractors, that are paid in RMB.  In 2008, China experienced inflationary pressures, which increased our costs associated with our operations in China.  In 2009, China did not experience any significant inflation.  In the future, inflation in China may result in higher minimum expenditure requirements under our PSCs if our Chinese partner companies adjust these requirements for inflation.  The actual inflationary impact on the Company may also be exacerbated by the increasing demand for goods and services in the oil and gas industry.  A material increase in these costs as a result could adversely affect our operations and, if there are material changes in our costs, we may seek to obtain additional funds earlier than anticipated.
 

ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA

Management's Report on Internal Control Over Financial Reporting

Our management is responsible for establishing and maintaining adequate internal control over financial reporting (as defined in Rule 13a-15(f) under the Exchange Act). Our internal control over financial reporting is designed, under the supervision and with the participation of our Chief Executive Officer and Chief Financial Officer, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of our published financial statements. All internal control systems, no matter how well designed, have inherent limitations. Therefore, even those systems determined to be effective can provide only reasonable assurance with respect to financial statement preparation and presentation. Further, because of changes in conditions, the effectiveness of internal controls may vary over time.

Our management, under the supervision and with the participation of our Chief Executive Officer and Chief Financial Officer, assessed the effectiveness of our internal control over financial reporting as of December 31, 2009. In making this assessment, our management used the criteria set forth by the Committee of Sponsoring Organizations of the Treadway Commission in Internal Control-Integrated Framework. Our management has concluded that, as of December 31, 2009, our internal control over financial reporting is effective based on these criteria.

Our independent registered public accounting firm, JonesBaggett LLP, that audited our consolidated financial statements included in this report, has issued an attestation report on the effectiveness of our internal control over financial reporting as of December 31, 2009, which is included on page 51 of this Annual Report on Form 10-K.
 
/s/ Michael R. McElwrath
/s/ K. Andrew Lai
Michael R. McElwrath
K. Andrew Lai
Chief Executive Officer
Chief Financial Officer

Houston, Texas
March 12, 2010
 
 
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

 
To the Board of Directors and Stockholders of
Far East Energy Corporation and Subsidiaries:

We have audited the accompanying consolidated balance sheets of Far East Energy Corporation and Subsidiaries (a development stage company) (the “Company”) as of December 31, 2009 and 2008 and the related consolidated statements of operations, changes in stockholders’ equity and cash flows for each of the three years in the period ended December 31, 2009 and for the period from the date of incorporation on February 4, 2000 to December 31, 2009. Our audits also included the financial statement schedule listed at Item 15(a)(2). These financial statements and schedule are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements and schedule based on our audits.

We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the consolidated financial position of Far East Energy Corporation and Subsidiaries at December 31, 2009 and 2008, and the consolidated results of their operations and their cash flows for each of the three years in the period ended December 31, 2009 and for the period from the date of incorporation on February 4, 2000 to December 31, 2009, in conformity with accounting principles generally accepted in the United States of America. Also, in our opinion, the related financial statement schedule, when considered in relation to the basic financial statements taken as a whole, presents fairly in all material respects the information set forth therein.

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the effectiveness of Far East Energy Corporation and Subsidiaries’ internal control over financial reporting as of December 31, 2009, based on criteria established in Internal Control-Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission and our report dated March 15, 2010, expressed an unqualified opinion thereon.

/s/ JonesBaggett LLP
JonesBaggett LLP (formerly Payne Smith & Jones, P.C.)

Dallas, Texas

 
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM


To the Board of Directors and Stockholders of
Far East Energy Corporation and Subsidiaries:
 
We have audited Far East Energy Corporation and Subsidiaries' (a development stage company) (the “Company”) internal control over financial reporting as of December 31, 2009, based on criteria established in Internal Control—Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (the COSO criteria). Far East Energy Corporation’s management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting included in the accompanying Management's Report on Internal Control Over Financial Reporting. Our responsibility is to express an opinion on the effectiveness of the Company’s internal control over financial reporting based on our audit.
 
We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects. Our audit of internal control over financial reporting included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, testing and evaluating the design and operating effectiveness of internal control based on the assessed risk, and performing such other procedures as we considered necessary in the circumstances.  We believe that our audit provides a reasonable basis for our opinion.
 
A company's internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company's internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company's assets that could have a material effect on the financial statements.
 
Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.
 
In our opinion, Far East Energy Corporation and Subsidiaries maintained, in all material respects, effective internal control over financial reporting as of December 31, 2009, based on the COSO criteria.
 
We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the consolidated balance sheets of Far East Energy Corporation and Subsidiaries, as of December 31, 2009 and 2008 and the related consolidated statements of operations, changes in stockholders' equity, and cash flows for each of the three years in the period ended December 31, 2009 and for the period from the date of incorporation on February 4, 2000 to December 31, 2009, and our report dated  March 15, 2010 expressed an unqualified opinion thereon.
 
 
/s/ JonesBaggett LLP
JonesBaggett LLP (formerly Payne Smith & Jones, P.C.)
 
Dallas, Texas
 
FAR EAST ENERGY CORPORATION
(A Development Stage Company)
Consolidated Balance Sheets
(In Thousands, Except Share Data)

   
At December 31,
  
   
2009
    
2008
  
             
             
ASSETS
  
Current assets
            
Cash and cash equivalents
   $ 5,567     $ 7,880  
Restricted cash
     739       -  
Inventory
     225       188  
Prepaid expenses
     166       262  
Deposits
     346       124  
Stock subscription receivable
     275       -  
Other current assets
     16       46  
Total current assets
     7,334       8,500  
                 
Unevaluated oil and gas properties
     34,421       30,837  
Other fixed assets, net
     480       546  
Total property and equipment
     34,901       31,383  
                 
Deferred financing costs
     169       -  
Total assets
   $ 42,404     $ 39,883  
                 
                 
LIABILITIES AND STOCKHOLDERS' EQUITY
  
                 
Current liabilities
                
Accounts payable
   $ 3,098     $ 2,249  
Accrued liabilities
     1,354       2,323  
Total current liabilities
     4,452       4,572  
                 
Exchangeable note payable
     10,000       -  
Discount on exchangeable note payable
     (228 )     -  
Long-term debt
     9,772       -  
                 
Accrued interest payable - noncurrent
     171       -  
                 
Asset retirement and environmental obligation
     339       -  
                 
Commitments and contingencies
                
                 
Stockholders' equity
                
Preferred stock, $0.001 par value, 500,000,000 shares authorized, none outstanding
     -       -  
Common stock, $0.001 par value, 500,000,000 shares authorized, 173,836,960 and 161,305,390 issued and outstanding, respectively
     174       161  
Additional paid-in capital
     111,982       105,915  
Unearned compensation
     (279 )     (313 )
Deficit accumulated during the development stage
     (84,207 )     (70,452 )
Total stockholders' equity
     27,670       35,311  
Total liabilities and stockholders' equity
   $ 42,404     $ 39,883  

See the accompanying notes to consolidated financial statements.

FAR EAST ENERGY CORPORATION
(A Development Stage Company)
Consolidated Statements of Operations
(In Thousands, Except Per Share Data)

   
Year ended December 31,
    
February 4, 2000
(Inception) through
  
   
2009
    
2008
    
2007
    
December 31, 2009
  
                         
Operating revenues
   $ -     $ -     $ -     $ -  
Operating expenses:
                                
Exploration costs
     4,503       15,283       3,345       31,521  
Lease operating expense
     1,892       2,904       1,945       7,699  
General and administrative
     6,479       4,515       7,230       41,567  
Impairment loss
     -       -       -       3,778  
Loss on investment in joint venture
     -       -       -       22  
Amortization of contract rights
     -       -       -       81  
Total operating expenses
     12,874       22,702       12,520       84,668  
Operating loss
     (12,874 )     (22,702 )     (12,520 )     (84,668 )
Other income (expense):
                                
Interest expense
     (863 )     -       -       (1,040 )
Interest income
     5       260       721       1,875  
Gain on sale of assets
     (5 )     -       -       3  
Foreign currency transaction loss
     (18 )     (149 )     (50 )     (377 )
Total other income
     (881 )     111       671       461  
Loss before income taxes
     (13,755 )     (22,591 )     (11,849 )     (84,207 )
Income taxes
     -       -       -       -  
Net loss
   $ (13,755 )   $ (22,591 )   $ (11,849 )   $ (84,207 )
                                 
Comprehensive loss
   $ (13,755 )   $ (22,591 )   $ (11,849 )   $ (84,207 )
                                 
Net loss per share:
                                
Basic and diluted
   $ (0.08 )   $ (0.15 )   $ (0.09 )        
                                 
Weighted average shares outstanding:
                                
Basic and diluted
     162,251       151,231       128,631          

See the accompanying notes to consolidated financial statements.


FAR EAST ENERGY CORPORATION
(A Development Stage Company)
Consolidated Statements of Stockholders' Equity
(In Thousands, Except Share Data)

   
Common Stock
    
Additional
          
Deficit
Accumulated
During the
    
Total
  
   
Number of
Shares
    
Par
Value
    
Paid-In
Capital
    
Unearned
Compensation
    
Development
Stage
    
Stockholders'
Equity
  
 
                                     
For the Years Ended December 31, 2007, 2008 and 2009
                                    
                                     
Balance at December 31, 2006
     123,767,342     $ 124     $ 77,599     $ -     $ (36,012 )   $ 41,711  
Net loss
     -       -       -       -       (11,849 )     (11,849 )
Common shares issued
     11,480,452       11       14,803       -       -       14,814  
Shares issued to consulting firm
     60,000       -       60       -       -       60  
Nonvested shares issued
     1,032,292       1       922       (764 )     -       159  
Stock options issued
     -       -       1,171       -       -       1,171  
Stock options exercised
     660,000       1       428       -       -       429  
Warrants exercised
     5,208       -       -       -       -       -  
Balance at December 31, 2007
     137,005,294       137       94,983       (764 )     (47,861 )     46,495  
Net loss
     -       -       -       -       (22,591 )     (22,591 )
Common stock issued
     24,000,000       24       11,784       -       -       11,808  
Shares issued to consulting firm
     20,000       -       14       -       -       14  
Nonvested shares issued
     538,500       -       325       451       -       776  
Nonvested shares withheld for taxes
     (258,404 )     -       (136 )     -       -       (136 )
Stock options issued
     -       -       (1,055 )     -       -       (1,055 )
Balance at December 31, 2008
     161,305,390       161       105,915       (313 )     (70,452 )     35,311  
Net loss
     -       -       -       -       (13,755 )     (13,755 )
Common stock issued
     11,558,645       11       4,349       -       -       4,360  
Shares issued to consulting firm
     -       -       -       -       -       -  
Nonvested shares issued
     990,000       2       285       34       -       321  
Nonvested shares withheld for taxes
     (17,075 )     -       (5 )     -       -       (5 )
Stock options issued
     -       -       844       -       -       844  
Warrants issued
     -       -       594       -       -       594  
Balance at December 31, 2009
     173,836,960     $ 174     $ 111,982     $ (279 )   $ (84,207 )   $ 27,670  
                                                 
                                                 
Inception (February 4, 2000) through December 31, 2009
                                                
                                                 
Balance at February 4, 2000
     -     $ -     $ -     $ -     $ -     $ -  
Net loss
     -       -       -       -       (84,207 )     (84,207 )
Common shares issued
                                                
- Placements
     160,384,832       159       91,352       -       -       91,511  
- Newark Valley
                                                
Oil & Gas Inc. acquisition
     1,600,000       2       3,598       -       -       3,600  
Shares issued to consulting firm
     231,259       -       297       -       -       297  
Nonvested shares issued
     2,560,792       4       1,532       (279 )     -       1,257  
Nonvested shares withheld for taxes
     (275,479 )     -       (141 )     -       -       (141 )
Stock options issued
     -       -       5,274       -       -       5,274  
Stock options exercised
     1,410,000       1       915       -       -       916  
Warrants issued
     -       -       804       -       -       804  
Warrants exercised
     7,925,556       8       8,185       -       -       8,193  
Warrants redeemed unexercised
     -       -       (2 )     -       -       (2 )
Debt issued with beneficial conversion feature
     -       -       168       -       -       168  
Balance at December 31, 2009
     173,836,960     $ 174     $ 111,982     $ (279 )   $ (84,207 )   $ 27,670  

See the accompanying notes to consolidated financial statements.

 
FAR EAST ENERGY CORPORATION
(A Development Stage Company)
Consolidated Statements of Cash Flows
(In Thousands)

   
For the Years Ended December 31,
    
February 4, 2000
(Inception) through
  
   
2009
    
2008
    
2007
    
December 31, 2009
  
                         
Cash flows from operating activities
                        
Net loss
   $ (13,755 )   $ (22,591 )   $ (11,849 )   $ (84,207 )
Adjustments to reconcile net loss to cash used in operating activities:
                                
Depreciation and amortization
     182       171       88       694  
Amortization of deferred financing costs
     863       -       -       863  
Prior period capitalized exploratory well costs expensed
     -       7,907       157       -  
Stock issued to pay expense
     -       14       61       297  
Share-based compensation
     1,165       (279 )     1,330       6,530  
Changes in components of working capital and asset retirement and environmental obligations
                                
Restricted cash
     (739 )     -       -       (739 )
Inventory
     (37 )     109       (241 )     (226 )
Prepaid expenses
     96       (113 )     68       (166 )
Deposits
     (222 )     (30 )     269       (346 )
Stock subscription receivable
     (245 )     -       -       (245 )
Other current assets
     -       (16 )     (21 )     (46 )
Accounts payable and accrued liabilities
     (133 )     1,687       (645 )     4,854  
Asset retirement and environmental obligations
     156       -       -       156  
Impairment expense
     -       -       -       3,778  
Loss (gain) on sale of assets
     5       -       -       (3 )
Other, net
     (5 )     (136 )     -       237  
Net cash used in operating activities
     (12,669 )     (13,277 )     (10,783 )     (68,569 )
                                 
Cash flows from investing activities
                                
Additions to unproved oil and gas properties in China
     (3,388 )     (7,343 )     (7,657 )     (34,713 )
Other oil and gas investment
     -       -       -       (1,278 )
Additions to other properties
     (123 )     (214 )     (398 )     (1,106 )
Sale of oil and gas properties
     -       -       -       1,108  
Sale of other fixed assets
     2       -       -       2  
Net cash used in investing activities
     (3,509 )     (7,557 )     (8,055 )     (35,987 )
                                 
Cash flows from financing activities
                                
Net proceeds from exchangeable note
     10,000       -       -       10,000  
Net proceeds from sale of common stock
     4,360       11,808       14,814       91,511  
Net proceeds from exercise of options
     -       -       429       916  
Net proceeds from exercise of warrants
     -       -       -       8,191  
Deferred financing costs
     (495 )     -       -       (495 )
Net cash provided by financing activities
     13,865       11,808       15,243       110,123  
                                 
(Decrease) increase in cash and cash equivalents
     (2,313 )     (9,026 )     (3,595 )     5,567  
Cash and cash equivalents--beginning of period
     7,880       16,906       20,501       -  
Cash and cash equivalents--end of period
   $ 5,567     $ 7,880     $ 16,906     $ 5,567  

See the accompanying notes to consolidated financial statements.

FAR EAST ENERGY CORPORATION
(A Development Stage Company)
Notes to Consolidated Financial Statements


1.  Summary of Significant Accounting Policies


Business.  We were incorporated in the state of Nevada on February 4, 2000, and on January 10, 2002, we changed our name to Far East Energy Corporation. The terms "we," "us," "our," "FEEC" and "our company" refer to Far East Energy Corporation.  We are an independent energy company.  FEEC, together with its subsidiaries, engages in the acquisition, exploration and development of coalbed methane ("CBM") gas properties in the People's Republic of China ("PRC"). We are a development stage company, and our activities have been limited to organizational activities, including developing a strategic operating plan, capital funding, hiring personnel, entering into contracts acquiring rights to explore for, develop, produce and sell oil and gas or coalbed methane, and drilling, testing and completion of exploratory wells.

Principles of Consolidation.  Our consolidated financial statements include the accounts of our wholly-owned subsidiaries after the elimination of all intercompany accounts and transactions.

Use of Estimates.  The preparation of our financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, expenses and disclosure of contingent assets and liabilities that exist at the date of the financial statements. While we believe our estimates are appropriate, actual results can, and often do, differ from those estimates.

Cash and Cash Equivalents.  We consider short-term investments with little risk of change in value because of changes in interest rates and purchased with an original maturity of three months or less to be cash equivalents.

Restricted Cash.  Restricted cash represents the amount of cash which is restricted by legal or contractual requirements. Of the $10 million proceeds from the issuance of an exchangeable note (the "Exchangeable Note") to Arrow Energy International Pte Ltd ("Arrow"), $2 million of the proceeds was set aside to be used exclusively to satisfy of FEEB existing exploration and development commitments in connection with the Qinnan production sharing contract ("PSC").  The restricted cash balance is reduced as the related expenditures are incurred.  As of December 31, 2009, our balance in restricted cash was $0.7 million.
 
Inventory.  Inventory consists primarily of tubular goods and drilling equipment used in our operations and is carried at cost with adjustments made from time to time to recognize any reductions in value.

Unevaluated Oil and Gas Property.  We use the successful efforts method of accounting for our oil and gas properties. Under this method, oil and gas lease acquisition costs and intangible drilling costs associated with exploration efforts that result in the discovery of proved reserves and costs associated with development drilling, whether or not successful, are capitalized when incurred. If proved commercial reserves are not discovered, such drilling costs are expensed. In some circumstances, it may be uncertain whether proved commercial reserves have been found when drilling has been completed.  Under Financial Accounting Standards Board ("FASB") Accounting Standards Codification ("ASC") Topic 932, Extractive Activities – Oil and Gas ("ASC 932"), such exploratory well drilling costs may continue to be capitalized if the reserve quantity is sufficient to justify its completion as a producing well and sufficient progress in assessing the reserves and the economic and operating viability of the project is being made. We assess our capitalized exploratory wells pending evaluation each quarter to determine whether costs should remain capitalized or should be charged to earnings. Other exploration costs, including geological and geophysical costs, are expensed as incurred. We recognize gain or loss on the sale of properties on a field basis.


Unproved property costs are capitalized and reviewed periodically for impairment on a property-by-property basis, considering factors such as drilling and exploitation plans and lease terms. The estimated fair value of unproved leasehold costs includes the present value of probable reserves discounted at rates commensurate with the risks involved in each classification of reserve. Costs related to impaired prospects are charged to expense. An impairment expense could result if oil and gas prices decline in the future or if downward reserves revisions are recorded, as it may not be economical to develop some of these unproved properties.  We also evaluate current drilling results, lease expiration dates, current oil and gas industry conditions, international economic conditions, capital availability, foreign currency exchange rates, political stability in the countries in which the Company has an investment, and available geological and geophysical information. Any impairment assessed is charged to expense.

Estimates of future dismantlement, restoration, and abandonment costs. The accounting for future development and abandonment costs is determined by FASB ASC Topic 410, Asset Retirement and Environmental Obligations, which  requires the fair value of a liability for an asset retirement obligation to be recognized in the period in which it is incurred if a reasonable estimate of fair value can be made. The associated asset retirement costs are capitalized as part of the carrying amount of the long-lived asset. The accrual is based on estimates of these costs for each of our properties based upon the type of production structure, reservoir characteristics, depth of the reservoir, market demand for equipment, currently available procedures and consultations with construction and engineering consultants. Based on our experience and technical and financial data collected from managing our projects over the years, we were able to record the costs related to our asset retirement and environmental obligations in our financial statements beginning the fourth quarter of 2009.  Because these costs typically extend many years into the future, estimating these future costs is difficult and requires management to make estimates and judgments that are subject to future revisions based on numerous factors, including changing technology, the political and regulatory environment, estimates as to the proper discount rate to use and timing of abandonment.

Convertible Debts and Warrants.  We applied FASB ASC Topic 815, Derivatives and Hedging ("ASC 815") and FASB ASC Topic 470, Debt ("ASC 470"), in recording the Exchangeable Note and warrants issued to Arrow in conjunction with a strategic alliance between the parties. Derivative financial instruments, as defined in ASC 815, consist of financial instruments or other contracts that contain a notional amount and one or more underlying, require no initial net investment and permit net settlement. Derivative financial instruments may be free-standing or embedded in other financial instruments. Further, derivative financial instruments are initially, and subsequently, measured at fair value and recorded as liabilities or, in rare instances, assets.  Convertible debt, as defined in ASC 470, generally includes an interest rate which is lower than the issuer could establish for nonconvertible debt, an initial conversion price which is greater than the market value of the common stock at the time of issuance, and a conversion price which does not decrease except pursuant to anti-dilution provisions.  Also, under ASC 470, the portion of the proceeds from the issuance of the debt which is allocable to the warrant should be accounted for as additional paid-in capital.  The allocation should be based on the relative fair values of the two securities at time of issuance.

Income Taxes.  Deferred income taxes are accounted for under the asset and liability method of accounting for income taxes. Under this method, deferred income taxes are recognized for the tax consequences of temporary differences by applying enacted statutory tax rates applicable to future years to differences between the financial statements carrying amounts and the tax basis of existing assets and liabilities. The effect on deferred taxes of a change in tax rate is recognized in income in the period the change occurs. Valuation allowances are established when necessary to reduce deferred tax assets to the amount expected to be realized.

Environmental Matters. Environmental expenditures are expensed or capitalized depending on their future economic benefit. Expenditures that relate to an existing condition caused by past operations, and do not contribute to current or future revenue generation are expensed. Liabilities are recorded when assessments and/or remediation are deemed probable and the costs can be reasonably estimated.

Net Loss Per Share.  We apply FASB ASC Topic 260, Earnings Per Share ("ASC 260") for the calculation of basic and diluted earnings per share. Basic earnings per share includes no dilution and is computed by dividing income available to common stockholders by the weighted average number of common shares outstanding for the period. Diluted earnings per share reflects the potential dilution of securities that could share in our earnings.

 
Share-based Compensation.  We measure the cost of employee services received in exchange for stock options based on the grant date fair value of the awarded options under FASB ASC Topic 718, Compensation – Stock Compensation ("ASC 718").  We determine the fair value of stock option grants using the Black-Scholes option pricing model.   We determine the fair value of shares of nonvested stock (also commonly referred to as restricted stock) based on the last quoted price of our stock on the OTC Bulletin Board on the date of the share grant.   The fair value determined represents the cost for the award and is recognized over the vesting period during which an employee is required to provide service in exchange for the award.  As share-based compensation expense is recognized based on awards ultimately expected to vest, we have reduced the expense for estimated forfeitures based on historical forfeiture rates.  Previously recognized compensation costs may be adjusted to reflect the actual forfeiture rate for the entire award at the end of the vesting period.  Excess tax benefits, as defined in ASC 718, if any, are recognized as an addition to paid-in capital.

Foreign Currency Transactions.  Periodically, we assess the functional currencies of our Chinese subsidiaries to ensure that the appropriate currency is utilized in accordance with the guidance in FASB ASC Topic 830, Foreign Currency Matters ("ASC 830").  During the fourth quarter of 2006, we determined that the functional currency for our Chinese operations was U.S. Dollars, instead of the Chinese Renminbi ("RMB") as previously reported and utilized.  Foreign currency transaction gains or losses, which resulted from transactions denominated in the Chinese RMB, were recorded in the Consolidated Statement of Operations.

Fair Values of Financial Instruments.  Our company's financial instruments consist primarily of cash and cash equivalents, payables, and accrued payables.  The carrying values of these financial instruments approximate their respective fair values as they are short-term in nature.

Credit Concentration.  We had deposited with one financial institution approximately $5.9 million in cash at December 31, 2009, which exceeded the limit of the Federal Deposit Insurance Corporation. The funds were deposited in U.S. government agency supported funds.  We did not require collateral from the financial institutions on these deposits.

Adoption of New Accounting Pronouncement. In June 2009, the FASB issued authoritative accounting guidance which established the FASB Accounting Standards Codification (Codification or ASC) as the source of authoritative accounting principles recognized by the FASB to be applied by nongovernmental entities and stated that all guidance contained in the Codification carries an equal level of authority. The authoritative accounting guidance recognized that rules and interpretive releases of the SEC under federal securities laws are also sources of authoritative U.S. GAAP for SEC registrants. The Company adopted the provisions of the authoritative accounting guidance during 2009, the adoption of which did not have a material effect on the Company’s consolidated financial statements.

2.  Liquidity and Realization of Assets

We have not established a source of revenue and are not able to accurately predict the timing of our first revenue.  We have funded our exploration and development activities primarily through the sale and issuance of common stock. During the second quarter of 2008, we completed a transaction for the sale of 24 million shares of our common stock and warrants to purchase up to 8.4 million shares of our common stock for total net proceeds of $11.8 million under our shelf registration in effect at that time.  That shelf registration expired in March 2009.  In September 2009, the Company filed with the SEC a shelf registration statement on Form S-3 for the offer and sale from time to time of up to $75 million of the Company's debt and equity securities.  In December 2009, we completed a transaction for the sale of 11.6 million shares of our common stock and warrants to purchase up to 4.6 million shares of our common stock for total net proceeds of $4.3 million under our shelf registration.  On March 11, 2010, we completed a transaction for the sale of 11.7 million shares of our common stock and warrants to purchase up to 4.7 million shares of our common stock for total net proceeds of $4.6 million under our shelf registration.  The amount available under the registration statement at March 12, 2010 was approximately $65.1 million.


On March 13, 2009, we formed a strategic alliance related to our Qinnan Block with Arrow Energy International Pte Ltd, the Singapore-based subsidiary of Arrow Energy Limited, a large Australian CBM producer.    Assuming that we obtain approval from our Chinese partner company and the MOC, and satisfy the other conditions under the Farmout Agreement with Arrow, then the additional payment due upon the occurrence of these events from Arrow together with funds currently available should provide sufficient working capital to meet our currently planned work programs through 2010.  Our current work programs would satisfy the minimum exploration expenditures for all three of our PSCs for 2010.  Management will continue to seek to raise additional capital to continue operations and to meet future expenditure requirements necessary to retain our rights under the PSCs.  Management intends to seek to obtain funds by entering into a strategic relationship or transaction, such as a joint venture or farmout, and/or obtaining debt or equity financing.  The global financial crisis has created liquidity problems for many companies and financial institutions and international capital markets have stagnated, especially in the United States and Europe.  A continuing downturn in these markets could impair our ability to obtain, or may increase our costs associated with obtaining, additional funds through the sale of our securities.  While we will continue to seek to raise funds, there can be no assurance that we will be able to enter any strategic relationship or transaction or that we will be successful in obtaining funds through debt or equity financing.  Under certain circumstances, the structure of a strategic transaction may require the approval of the Chinese authorities, which could delay closing or make the consummation of a transaction more difficult.  There can be no assurance that the Chinese authorities will provide the approvals necessary for a transaction or transfer.  In addition, the terms and conditions of any potential strategic relationship or transaction or of any debt or equity financing are uncertain and we cannot predict the timing, structure or other terms and conditions of any such arrangements.  There can be no guarantee of future fundraising or exploration success or that we will realize the value of our unevaluated exploratory well costs. Management believes that we will continue to be successful in obtaining the funds necessary to continue as a going concern.

As of December 31, 2009, we had unevaluated exploratory well costs totaling $34.0 million, of which $30.6 million have been capitalized for a period greater than one year.  Such costs, which related to the Shouyang Block in Shanxi Province, were initially capitalized under successful efforts accounting, pending a determination of whether sufficient quantities of economically recoverable proved reserves are found.  We make periodic assessments of whether these costs qualify for continuing capitalization, based on whether we are making sufficient progress in assessing the reserves and determining the economic and operating viability of the project, as more fully discussed in Note 5.

In addition to these periodic assessments, we also assess whether we have a reasonable expectation of recovering these costs through future net cash flows from the project, if we are successful in establishing proved reserves. During the first quarter of 2008, we received the report of an independent engineering firm, which was commissioned to study the various technical aspects of the current pilot project in the Shouyang Block.  The study indicated that significant gas content is present in the pilot area and that the coal in the area has relatively high permeability, based on production data available from the first seven wells (three horizontal and four vertical) drilled in the pilot area.  The report also indicated that we have made progress in lowering the field pressure to a level which appears to be approaching the critical desorption pressure necessary for CBM gas production.  Although there are many uncertainties associated with our exploration and dewatering efforts, we believe the results of the study provide the Company with a reasonable basis for the long-term viability of this project, and support the continued capitalization of our unevaluated capitalized exploratory well costs in the project while we are continuing to evaluate the field.

The report noted that the initial seven pilot wells evaluated by the independent engineering firm had suffered varying degrees of wellbore damage while being drilled.  Without taking into consideration future planned wells, the report also indicates that the seven pilot wells appear insufficient to properly confine the area for dewatering purposes.  As such, the report indicates that we are unlikely to produce meaningful quantities of gas from these initial seven wells without drilling additional wells and/or conducting remedial activities on the seven wells.  Subsequent to the drilling of the seven wells included in the report, we have drilled additional 3 horizontal, 15 vertical and 7 deviated wells as of December 31, 2009 in the 1H Pilot Area.  The unevaluated exploratory well costs at December 31, 2009 comprised of exploratory drilling and related costs for 31 wells in the 1H Pilot Area.  During the fourth quarter of 2008, we expensed the previously capitalized costs related to one of the seven pilot wells, FCC-HZ02, pursuant to FSP No. 19-1, as more fully discussed in Note 5.  We also planned to drill additional wells in the near future to further explore and assess the potential of the property.  However, there are many risks and

 
uncertainties involved in early stages of exploring and attempting to develop a new CBM gas field and we cannot make any assurances that our efforts will be successful in making the pilot area commercially viable.  In the event we are not successful, we may be required to write off some or all of these unevaluated exploratory well costs.

3.  Strategic Alliance with Arrow

On March 13, 2009, we formed a strategic alliance related to our Qinnan Block with Arrow.  In conjunction with the strategic alliance, one of our wholly owned subsidiaries, FEEB, and Arrow entered into a Farmout Agreement (the "Farmout Agreement") under which, subject to certain conditions, FEEB will assign to Arrow 75.25% of its rights in the Qinnan PSC in Shanxi Province (the "Assignment").  The Farmout Agreement conditions the Assignment on, among other things, the receipt of required approvals from the government of the PRC on or prior to December 19, 2009 or such later date as we may agree upon.  The terms of the Farmout Agreement were subsequently amended in November 2009 to provide, among other things, that requisite approvals from Chinese authorities must be received and other conditions must be satisfied by December 16, 2009 rather than by November 20, 2009 (the "Amendment").  In conjunction with the Amendment, FEEB and Arrow also agreed that interest on the Exchangeable Note would begin to accrue as originally scheduled on October 16, 2009.  Since December 19, 2009, each of the Company and Arrow has had the right to terminate the Farmout Agreement at any time, though neither party has elected to exercise that right and the parties are continuing to use efforts to satisfy the conditions contemplated by the Farmout Agreement.

Upon satisfaction of the conditions, Arrow will make an initial payment of $8 million to us, and, subject to certain conditions, will fund all exploration costs associated with the Qinnan PSC, up to a maximum of $30 million. In addition, under the Farmout Agreement, if we obtain Chinese governmental approval of an overall development program for the Qinnan area, Arrow will pay FEEB an additional $8 million in cash as a bonus. If the conditions under the Farmout Agreement are not satisfied prior to November 20, 2009, then either party has the right to terminate the agreement by delivering notice of such termination to the other party.  Additionally, on March 13, 2009, (i) we entered into a securities purchase agreement with Arrow ("Securities Purchase Agreement"); (ii) FEEB issued the Exchangeable Note, $10 million principal amount, to Arrow for $10 million in cash; (iii) we issued a warrant to Arrow for 7,420,000 shares of our common stock, at an exercise price of $1.00 per share ("Warrant"); and (iv) the Company and Arrow entered into a registration rights agreement.

Under the Securities Purchase Agreement, the Company issued the Warrant to Arrow and FEEB issued the Exchangeable Note to Arrow for $10 million in cash, of which $2 million was to be set aside to be used exclusively to satisfy FEEB's existing exploration and development commitments in connection with the Qinnan PSC.  This restricted portion of the proceeds was recorded as restricted cash on the consolidated balance sheet. During the period from the formation of the strategic alliance to the year ended December 31, 2009, we used approximately $1.3 million of the $2 million for exploration expenditures related to the Qinnan PSC.  See Note 1 – "Summary of Significant Accounting Policies – Restricted Cash."

The Exchangeable Note has an initial principal amount of $10 million.  If the Chinese government does not approve the Assignment, the Exchangeable Note bears interest at a rate of 8% per annum, which began to accrue on October 16, 2009, and principal and interest is due and payable on the maturity date of March 13, 2011.  Arrow has the right at any time to exchange the Exchangeable Note in whole or in part for shares of common stock at an exchange rate of 21,052.63 shares per $10,000, or $0.475 per share (the "Exchange Rate"), of principal and interest.  If the Chinese government approves the Assignment on or before November 20, 2009, the entire principal amount of the Exchangeable Note will automatically be exchanged for shares of common stock at the Exchange Rate.

The Exchangeable Note contains certain restrictive covenants applicable to the Company and FEEB, including, among others, restrictions on the incurrence of indebtedness that ranks senior to or pari passu with the Exchangeable Note and restrictions on FEEB's ability to sell all of its rights under the Shouyang PSC.  The Company has guaranteed FEEB's payment obligations under the Exchangeable Note.

 
The Warrant entitled Arrow to purchase 7,420,000 shares of common stock at an exercise price of $1.00 per share, subject to certain equitable adjustment mechanisms in the event of a sale of the Company, stock split or similar occurrence.  The Warrant expired in December 2009.

For additional information on the strategic alliance, see Item 1 – "Business" of our 2008 Annual Report.

We applied ASC 815 and ASC 470 in the recording of the transaction with Arrow.  According to ASC 815, the Exchangeable Note and the Warrant were afforded the exemption from derivative accounting treatment as they were not derivative instruments because (i) their conversion features were indexed to the Company's stock, and (ii) the Warrant is and, in the case of the Exchangeable Note, the conversion feature standalone would be classified in stockholders’ equity in the balance sheet.  Pursuant to ASC 470, no portion of the proceeds from the issuance of the Exchangeable Note should be accounted for as attributable to the conversion feature due to the inseparability of the debt and the conversion option.  Also, under ASC 470, the portion of the proceeds from the issuance of the Exchangeable Note which is allocable to the Warrant should be accounted for as paid-in capital.  The allocation should be based on the relative fair values of the two securities at time of issuance.  We determined the fair value of the Warrant using a combination of the Black-Scholes-Merton valuation technique and a Monte Carlo simulation.

The significant assumptions used in the valuation were as follows:

   
Black-Scholes
-Merton
    
Monte Carlo
Simulation
  
Volatility
     124.60 %     110.16 %
Risk free interest rate
     0.67 %     0.83 %
Expected dividend yield
     -       -  
Expected term
  
0.99 year
    
1.51 years
  
 
Based on the combination of the Black-Scholes-Merton valuation technique and the Monte Carlo simulation, the Warrant was valued at $624,612 at time of issuance.   The amount was recorded as a debt discount to the Exchangeable Note in the liabilities section and as additional paid-in capital in the equity section of the balance sheet.  The debt discount is accreted as interest expense periodically over the term of the Exchangeable Note.  We have recorded an accretion amount of $396,593 from the issuance date to December 31, 2009.

The Company incurred approximately $0.5 million in direct costs in connection with the formation of the strategic alliance.  These direct costs were allocated between the Exchangeable Note and the Warrant in proportion to their respective fair values at time of issuance.  The costs related to the Warrant were recorded as an offset to the value of the Warrant in paid-in capital.  The costs related to the Exchangeable Note were capitalized as deferred financing costs and amortized based on the effective interest method over the term of the Exchangeable Note.  The objective of that method is to arrive at a periodic interest cost which represents a level effective rate over the term of the Exchangeable Note on its face amount reduced by the unamortized discount and expense at the beginning of the period.  The effective interest rate for the Exchangeable Note as calculated is 11.64% per annum.  We have recorded an amortization amount of $294,682 for the period from the issuance date to end of the fourth quarter of 2009.

4.  Statements of Cash Flows

We use the indirect method to present cash flows from operating activities. Cash paid for interest expense and income taxes for 2009, 2008, and 2007 was zero.  Other supplemental cash flow information for 2009, 2008 and 2007, is presented as follows (in thousands):

   
2009
    
2008
    
2007
  
Non-cash transactions:
                  
Non-cash interest expense
   $ 863     $ -     $ -  
Issuance of common stock to pay consulting expenses
     -       14       61  
Non-cash Share-based compensation
     1,165       (279 )     1,330  
 

5.  Unevaluated Oil and Gas Properties

The costs associated with our unevaluated oil and gas properties include the following (in thousands):

   
At December 31,
  
   
2009
    
2008
  
Unproved leasehold costs
   $ 275     $ 275  
Unevaluated exploratory well costs
     34,146       30,562  
    $ 34,421     $ 30,837  

Unproved property Costs. Unproved leasehold costs are composed of amounts we paid to the PRC's Ministry of Commerce ("MOC") and the China United Coalbed Methane Corporation ("CUCBM") pursuant to a PSC we entered into in 2002 with CUCBM to acquire the mineral rights in the Enhong and Laochang areas in Yunnan Province.

Unevaluated Wells Costs.  Unevaluated well costs include only suspended well costs which are direct exploratory well costs pending determination of whether proved reserves have been discovered. Accounting guidance regarding capitalization of suspended well costs is provided by FASB ASC Topic 932.  FASB ASC 932 addresses whether there are circumstances under the successful efforts method of accounting for oil and gas producing activities that would permit the continued capitalization of exploratory well costs beyond one year, other than when additional exploration wells are necessary to justify major capital expenditures and those wells are under way or firmly planned for the near future.  Capitalization of costs should be continued beyond one year in cases where reserves for the project are not yet proven, but the Company demonstrates sufficient continuing progress toward assessing those reserves.  For the capitalized costs at December 31, 2009, our assessment indicated that our current work programs demonstrated our efforts in making sufficient continuing progress toward assessing the reserves in the areas for which the costs were incurred. Therefore, we have continued to capitalize these costs.

The following table provides an aging of capitalized exploratory well costs based on the date the costs were incurred and the number of related wells for which these exploratory well costs have been capitalized for a period greater than one year (in thousands, except number of projects):

   
At December 31,
  
   
2009
    
2008
  
Unevaluated exploratory well costs that have been capitalized for a period of one year or less
   $ 3,584     $ 6,993  
Unevaluated exploratory well costs that have been capitalized for a period greater than one year (1)
     30,562       23,569  
Total unevaluated exploratory well costs
   $ 34,146     $ 30,562  
                 
Number of projects that have exploratory well costs that have been capitalized for a period greater than one year
     1       1  

(1)
Costs related to our exploratory project in the Shouyang Block in the Shanxi Province.
 

The following table reflects the net changes in capitalized exploratory well costs during 2009, 2008 and 2007 (in thousands):

   
2009
    
2008
    
2007
  
Beginning balance at January 1
   $ 30,562     $ 31,539     $ 24,039  
Additions to unevaluated exploratory well costs pending the determination of proved reserves
     3,584       6,930       7,657  
Reclassifications to wells, facilities, and equipment based on the determination of proved reserves
     -       -       -  
Unevaluated exploratory well costs charged to expense
     -       (7,907 ) (1)     (157 )
Ending balance at December 31
   $ 34,146     $ 30,562     $ 31,539  

 
(1)
During 2008, we determined that $7.9 million of unevaluated exploratory well costs incurred previously no longer met the requirements for continued capitalization.  Accordingly, we charged this amount to exploration costs.  The amount includes $7.0 million related to the FCC-HZ02 well in the Shouyang project.

6.  Asset Retirement and Environmental Obligations

Estimates of future dismantlement, restoration, and abandonment costs. The accounting for future development and abandonment costs is determined by FASB ASC Topic 410, Asset Retirement and Environmental Obligations, which requires the fair value of a liability for an asset retirement obligation to be recognized in the period in which it is incurred if a reasonable estimate of fair value can be made. The associated asset retirement costs are capitalized as part of the carrying amount of the long-lived asset. The accrual is based on estimates of these costs for each of our properties based upon the type of production structure, reservoir characteristics, depth of the reservoir, market demand for equipment, currently available procedures and consultations with construction and engineering consultants. Based on our experience and technical and financial data collected from managing our projects over the years, we were able to record the costs related to our asset retirement and environmental obligations in our financial statements as of December 31, 2009.  Because these costs typically extend many years into the future, estimating these future costs is difficult and requires management to make estimates and judgments that are subject to future revisions based on numerous factors, including changing technology, the political and regulatory environment, estimates as to the proper discount rate to use and timing of abandonment.

The following table presents the reconciliation of the beginning and ending aggregate carrying amounts of short-term and long-term legal obligations associated with the retirement of property, plant and equipment for the years ended December 31, 2009 and 2008 (in thousands):

   
2009
    
2008
  
Carrying amount at beginning of period
   $ -     $ -  
Liabilities incurred
     339       -  
Liabilities settled
     -       -  
Accretion
     -       -  
Revisions
     -       -  
Foreign currency translations
     -       -  
Carrying amount at end of period
   $ 339     $ -  
                 
Current portion
   $ -     $ -  
Noncurrent portion
   $ 339     $ -  
 

7.  Other Fixed Assets

Other fixed assets, net include the following (in thousands):

   
At December 31,
  
   
2009
    
2008
  
Other fixed assets
   $ 984     $ 919  
Accumulated depreciation
     (504 )     (373 )
Other fixed assets, net
   $ 480     $ 546  

Other fixed assets include leasehold improvements, equipment and furniture.  Depreciation expense for the years ended December 31, 2009, 2008, and 2007 was approximately $182,000, $171,000, and $88,000, respectively.

8.  Income Taxes

 
Deferred income taxes reflect the net tax effects of temporary differences between the recorded amounts of assets and liabilities for financial reporting purposes and the amounts used for income tax purposes. Significant components of our deferred tax assets and liabilities as of December 31, 2009 and 2008 are as follows (in thousands):
 

   
2009
    
2008
  
Deferred tax assets:
            
Net operating loss
   $ 3,210     $ 2,024  
Accrued expense and other
     -       31  
Stock-based compensation
     529       381  
Total deferred tax assets
     3,739       2,436  
Total deferred tax liabilities
     (12 )     -  
Net deferred tax assets
   $ 3,727     $ 2,436  
                 
Net deferred tax assets
   $ 3,727     $ 2,436  
Less: valuation allowance
     (3,727 )     (2,436 )
    $ -     $ -  
 
Net operating loss, which can be carried forward for federal income tax purposes, was estimated to be approximately $9.4 million at December 31, 2009. We had net operating loss for federal income tax purposes of approximately $6.0 million at December 31, 2008.  The net operating loss will begin to expire in 2016.  At December 31, 2009 and 2008, management believed that the above indicated valuation allowance was necessary in order to comply with the provisions of FASB ASC Topic 740, Income Taxes (“ASC 740”).

Income taxes for financial reporting purposes differed from the amounts computed by applying the statutory federal income tax rates because Bermuda has no income tax that would apply to FEEB, and because of our recording of the valuation allowance for the losses generated by us. The net increase in the valuation allowance for the year ended December 31, 2009 was $1.3 million.  This increase was primarily attributable to the net operating loss generated during 2009.  The net decrease in the valuation allowance for the year ended December 31, 2008 was $0.4 million.  This decrease was primarily attributable to the reversal of temporary timing differences related to stock-based compensation.
 
ASC 740 prescribes a minimum recognition threshold and measurement methodology that a tax position taken or expected to be taken in a tax return is required to meet before being recognized in the financial statements. It also provides guidance for derecognition, classification, interest and penalties, accounting in interim periods, disclosure, and transition.  We recognize interest and penalties related to unrecognized tax benefits within the provision for income taxes on continuing operations in our consolidated statements of income. There were no unrecognized tax benefits as of the date of adoption.  There are no unrecognized tax benefits that if recognized would affect the tax

 
rate for the year ended December 31, 2009. There is no interest or penalties recognized as of the date of adoption or for the year ended December 31, 2009.
 
9.  Commitments and Contingencies

Legal Proceedings.  We are periodically named in legal actions arising from normal business activities. We evaluate the merits of these actions and, if we determine that an unfavorable outcome is probable and can be estimated, we will establish the necessary accruals. We do not anticipate any material losses as a result of commitments and contingent liabilities. We are involved in no material legal proceedings.

Shouyang and Qinnan Production Sharing Contracts. We are the operator under two separate PSCs with CUCBM to develop the Shouyang and Qinnan Blocks in the Shanxi Province. The term of each of the Shouyang and Qinnan PSCs consists of an exploration period, a development period and a production period. During the exploration period, we hold a 100% participating interest in the properties, and we must bear all exploration costs for discovering and evaluating CBM-bearing areas. If any CBM field is discovered, the development costs for that CBM field will be borne by us and CUCBM in proportion to the respective participating interests. The exploration period is divided into three phases called Phase I, Phase II and Phase III. We have completed our Phase I and Phase II obligations under the PSCs, and elected to enter into Phase III. Our work commitment to complete Phase III consists of furthering the horizontal drilling in the coal seam begun in Phase II to a total of 12,000 meters. We completed eight horizontal wells which totaled approximately 12,058 meters of horizontal drilling in coal for the Shouyang PSC and Qinnan PSC together in 2009. Therefore, we have satisfied the exploration work commitment. During the third quarter of 2009, the MOC approved a modification agreement to extend Phase III of the exploration period for the Shouyang PSC to June 30, 2011 from June 30, 2009. With regard to the Qinnan PSC, CNPC has recently replaced CUCBM as our Chinese partner company. For many months CNPC has been awaiting authorization from the Chinese government allowing it to deal with foreign partners on CBM projects. On March 7, 2010, several major news outlets reported that CNPC stated that it has been authorized to jointly develop coalbed methane projects with foreign partners, but we have not yet obtained official confirmation of this. There can be no assurance that CNPC will approve an extension of the exploration period or approve the Farmout Agreement with Arrow. We have had discussions with CNPC regarding the extension of the exploration period, which expired on June 30, 2009. At CNPC's request, we have provided certain operational and financial information about our Company to assist them in the decision making process. There can be no assurance that we will be successful in extending the Qinnan PSC.

Under the PSCs, we have committed to satisfy certain annual minimum exploration expenditure requirements for each PSC.  Our minimum exploration expenditure requirement for each block is based on the minimum exploration expenditure requirements of CUCBM established by the Ministry of Land and Resources ("MLR").  The MLR sets its requirements by applying a minimum expenditure per acre to the total acreage encompassed by each PSC.  The annual minimum exploration expenditure requirement is approximately $2.9 million and $3.4 million, for the Shouyang PSC and the Qinnan PSC, respectively, based on the currency exchange rate between the U.S. Dollar and the Chinese RMB as of December 31, 2009.  For 2009, our exploration expenditure at Shouyang Block exceeded minimum requirement. Pursuant to the 2009 Shouyang PSC Modification Agreement, the portion of the exploration expenditures which exceeds the current year's minimum exploration expenditure requirement can no longer be carried forward toward the satisfaction of the subsequent year's minimum requirement. These expenditure requirements are denominated in the RMB and therefore, are subject to fluctuations in the currency exchange rate between the U.S. Dollar and the Chinese RMB.  Assuming that we obtain approval from our Chinese partner company and the MOC, and satisfy the other conditions under the Farmout Agreement with Arrow, then the additional payment due upon the occurrence of these events from Arrow together with funds currently available should provide sufficient working capital to meet our currently planned work programs through 2010.  Our current work programs would satisfy the minimum exploration expenditures for all three of our PSCs for 2010.  The MLR minimum expenditure requirements are a significant factor that influences the Company's exploration work program.


Under the PSCs, we are required to make the following yearly payments to our Chinese partner companies.  As indicated below, certain amounts may change from year to year.

   
Shouyang PSC
    
Qinnan PSC
  
Exploration Period
            
Salary and Benefit
            
2009
   $ 162,200     $ 143,100  
2010
     195,900 (1)     143,100 (2)
Exploration Permit Fee
                
2009
     140,136       165,529  
2010
     143,622       169,693 (2)
Training Fee
     60,000       60,000  
Assistance Fee
     50,000       50,000  
                 
Development & Production Period
                
Signature Fee (3)
     150,000       150,000  
Training Fee
     150,000       150,000  
Assistance Fee
     120,000       120,000  
 
(1) The increase from 2009 to 2010 is due to the increase of standard amount of the CUCBM's professionals’ salary and benefit under the amended Shouyang PSC. The salary and benefits for CUCBM professionals during the development and production periods is to be determined by negotiation with CUCBM.
(2) The increase from 2009 to 2010 is due to the phaseout of a discount on exploration permit fee pursuant to MLR’s regulations.
(3) Due within 30 days after first approval of the ODP following the exploration period.
 
 
Yunnan Production Sharing Contract. We are the operator under one PSC with CUCBM to develop two areas in the Yunnan Province: Enhong and Laochang. The term of the PSC consists of an exploration period, a development period and a production period. The exploration period is divided into two phases, Phase I and Phase II.  We have completed Phase I and are operating in Phase II.  During the third quarter of 2009, the MOC approved a modification agreement to extend Phase II of the exploration period for the Enhong-Laochang PSC to June 30, 2011 from June 30, 2009.

During the exploration period, we must bear all exploration costs for discovering and evaluating CBM-bearing areas.  Our work commitment to complete Phase II consists of drilling at least one horizontal well with a minimum of two laterals.   We are reviewing the data collected from the vertical wells we drilled and other wells drilled by the Chinese coal industry to plan for the drilling of the horizontal well.

Under the Yunnan PSC, we have committed to satisfy certain annual minimum exploration expenditure requirements.  Our minimum exploration expenditure requirements for the blocks subject to the PSC are based on the minimum exploration expenditure requirements of CUCBM established by the MLR.  The MLR sets its requirements by applying a minimum expenditure per acre to the total acreage encompassed by the PSC.  The annual minimum exploration expenditure requirement is approximately $1.6 million, based on the currency exchange rate between the U.S. Dollar and the Chinese RMB as of December 31, 2009.  Pursuant to the 2009 Yunnan PSC Modification Agreement, the portion of the exploration expenditures which exceeds the current year's minimum exploration expenditure requirement can no longer be carried forward toward the satisfaction of the subsequent year's minimum requirement.  Our 2009 exploration expenditure and the cumulative amount carried forward from 2008 amounted to approximately $1.5 million. Therefore we were approximately $0.1 million short of the requirement.  The shortage will be discussed in the next joint management committee meeting currently scheduled in late March.  Based on previous experience and the shortage being immaterial, we are hopeful that permission will be granted from CUCBM to add the underage to the 2010 requirement.  These requirements are denominated in the RMB, and therefore, are subject to fluctuations in the currency exchange rate between the U.S.

 
Dollar and the Chinese RMB.  The MLR minimum expenditure requirements are a significant factor that influences the Company's exploration work program.

Pursuant to the terms of the Yunnan PSC, we have paid CUCBM signature fees totaling $350,000.  Under the PSC, we are required to make certain payments to CUCBM, including: (1) CUCBM assistance fees for Chinese personnel totaling $45,000 per year during the exploration phase and $80,000 per year during the development and production periods; (2) training fees for Chinese personnel working on the projects of $45,000 per year during the exploration period and $80,000 per year during the development and production periods; (3) reimbursement to CUCBM for government-imposed fees for CBM exploration rights during the exploration period, which were $74,000 in 2009 and are estimated to be approximately $79,000 in 2010, and in proportion to our participating interest in the development and production periods; and (4) salary and benefits paid to CUCBM professionals during the exploration period, which was approximately $210,000 in 2009 and are estimated to be approximately $257,000 in 2010.  This increase is due to the increase of standard amount of CUCBM’s professionals salary and benefit under the extended Yunnan PSC.  The allocation of salary and benefits for CUCBM professionals during the development and production periods are to be determined by negotiation with CUCBM.

Minimum Commitments.  At December 31, 2009, total minimum commitments from long-term non-cancelable operating leases and other purchase obligations are as follows (in thousands):

   
Amount
  
2010
   $ 9,370  
2011 - 2012
     15,244  
2013 - 2014
     -  
2015 and beyond
     339  
Total minimum commitments
   $ 24,953  

10.  Employee Savings Plan

At December 31, 2009, we maintained a defined contribution plan covering all of our U.S. employees. Employees participating in the plan may select from several investment options. We match the participant's contribution up to a maximum of four percent of the participant's salary. The amounts contributed by the participants and us vest immediately. We expensed $40,000, $48,000, and $41,000 under this plan for 2009, 2008 and 2007, respectively.

11.  Share-Based Compensation

We grant shares of nonvested stock of common stock and options to purchase common stock to employees, members of the board of directors and consultants under our shareholder-approved 2005 Stock Incentive Plan (the "2005 Plan").  Options granted under the 2005 Plan must carry an exercise price equal to or above the market value of the stock at the grant date, and a term of no greater than ten years.  The 2005 Plan provides that, unless otherwise agreed, shares of nonvested stock granted under the 2005 Plan must be forfeited upon termination of service.  We issue new shares when options are exercised or shares are granted.  Our option grants under the 2005 Plan to date have generally utilized these terms: exercise price above or equal to average market price on the date of the grant; vesting periods up to four years from date of grant; term of up to ten years; and forfeiture of unexercised vested options after 60-90 days after termination of employment with the Company.  Our shares of nonvested stock granted under the 2005 Plan to date have utilized vesting periods of up to three years.

Grants prior to the adoption of the 2005 Plan and inducement grants associated with hiring of new employees and appointment of new directors are issued outside of the 2005 Plan.  These grants of options included varying terms, some differing from the above.

During the first half of 2009, we awarded options to purchase up to 1,686,000 shares of our common stock and 1,190,000 shares of nonvested stock under the 2005 Plan to employees and members of the board of directors, and options to purchase up to 220,000 shares of our common stock and 100,000 shares of nonvested stock outside the 2005 Plan to a new employee and consultants. At the annual general meeting of stockholders of the Company held

 
on July 15, 2009, the Company's stockholders approved an amendment to the 2005 Plan which increased the number of shares of common stock issuable from 7,500,000 shares to 12,500,000 shares and increased the number of shares of common stock that may be granted as restricted stock (shares of nonvested stock), restricted stock units or any other stock-based awards from 2,400,000 to 3,900,000 shares.  Since the amendments were approved, we have not awarded any options to purchase our common stock or any share of nonvested stock or other full-valued stock-based award.  As of December 31, 2009, we had 5,752,333 shares available for awards under the 2005 Plan, of which 1,921,500 shares could be issued as shares of nonvested stock or other full-valued stock-based awards.

In the fourth quarter of 2008, we reviewed the data we utilized to determine our estimated forfeiture rates for the share based awards.  The estimated forfeiture rates were used in the calculations of the share based compensation costs.  The data indicated that most of the estimated forfeiture rates should be increased.  Consequently, we adjusted certain previously recognized compensation costs to reflect the higher estimated forfeiture rates.  As a result, we reduced the compensation costs by approximately $2.1 million.  The following table summarizes share based compensation costs recognized under ASC 718 for 2009, 2008 and 2007 (in thousands):

   
2009
    
2008
    
2007
  
General and administrative
   $ 930     $ (621 )   $ 1,242  
Exploration Costs
     235       342       69  
Tax benefit
     -       -       -  
Total share-based compensation costs, net of tax
   $ 1,165     $ (279 )   $ 1,311  


We utilized certain assumptions in determining the fair value of options using the Black-Scholes option pricing model.  We calculated the estimated volatility for grants of options made in 2006 and 2007 by averaging the historical daily price intervals for our common stock for the portion of the expected life that our shares were publicly traded and the historical daily price intervals of similar peer companies for the remaining period.  As of the first quarter of 2008, expected volatility is based completely on the Company's own historical volatility since we have sufficient data to determine the 6-year volatility.  The risk-free interest rate is based on observed U.S. Treasury rates at date of grant, appropriate for the expected lives of the options. The expected life of options granted during 2006 and 2007 was determined based on the method provided in Staff Accounting Bulletin No. 107, as we do not have an adequate exercise history to determine the average life for the options with the characteristics of those granted in 2007 and 2006.

Compensation expenses for the stock option grants determined under ASC 718 for 2008, 2007 and 2006 were calculated using the Black-Scholes option pricing model with the following assumptions:

   
Actual
2009
    
Actual
2008
    
Actual
2007
  
Dividend yield
     0 %     0 %     0 %
Expected volatility
     85 - 89 %     77 - 82 %     82 - 84 %
Risk-free interest rate
     1.5 - 1.7 %     2.5 - 3.1 %     4.2 - 4.9 %
Expected life of options (years)
     5.5 - 6       5.5 - 6       5.5 - 6  
Weighted average fair value per share at grant date
   $ 0.17     $ 0.44     $ 0.71  
 

The following table summarizes stock option transactions for 2009:

   
2009
  
   
Shares
Underlying
Options
    
Weighted
Average
Exercise
Price
    
Weighted
Average
Remaining
Life (Years)
    
Aggregate
Intrinsic
Value
  
Outstanding at beginning of year
     11,320,500     $ 1.25              
Granted
     1,906,000       0.40              
Exercised
     -       -              
Canceled
     -       -              
Forfeited
     (433,333 )     0.54              
Expired
     (2,841,000 )     1.16              
Outstanding at end of year
     9,952,167       1.14       6.32     $ -  
                                 
Options exercisable at end of year
     6,636,167     $ 1.41       5.19     $ -  


No options were exercised during 2009 and 2008.  The total intrinsic value of options exercised during 2007 was $383,000.

A summary of options outstanding as of December 31, 2009 is as follows:

     
Options Outstanding
    
Options Exercisable
  
Range of
Exercise Prices
    
Number
Outstanding
    
Weighted
Average
Remaining
Contractual
Life (Years)
    
Weighted
Average
Exercise
Price
    
Number
Exercisable
    
Weighted
Average
Exercise
Price
  
$ 0.28 to $0.45       1,496,000       9.18     $ 0.28       166,667     $ 0.31  
$ 0.46 to $0.70       3,248,167       7.14       0.67       1,723,833       0.66  
$ 0.71 to $0.99       823,000       7.32       0.81       574,667       0.80  
$ 1.00 to $1.99       1,000,000       5.69       1.18       915,000       1.19  
$ 2.00 to $2.37       3,385,000       4.22       2.04       3,256,000       2.04  
          9,952,167       6.32       1.14       6,636,167       1.41  

The following table summarizes activity in shares of nonvested stock for 2009:

   
Shares of
Nonvested Stock
    
Weighted
Average
Grant Date
Fair Value
  
Outstanding at beginning of year
     703,500     $ 0.70  
Granted
     1,290,000       0.28  
Vested
     (322,425 )     0.66  
Forfeited
     (300,000 )     0.28  
Withheld for Taxes
     (17,075 )     0.60  
Outstanding at end of year
     1,354,000       0.40  
 

At December 31, 2009, we had approximately $0.9 million in total unrecognized compensation cost related to share-based compensation, of which $0.3 million was related to shares of nonvested stock grants and was recorded in unearned compensation on our consolidated balance sheets.  This cost is expected to be recognized over a weighted average period of 1.54 years at December 31, 2009.

12.  Stockholders' Equity

Common Stock. Holders of our common stock are entitled to one vote for each share held on all matters submitted to a vote of stockholders and do not have cumulative voting rights. Accordingly, holders of a majority of the shares of common stock entitled to vote in any election of directors may elect all other directors standing for election. Holders of common stock are entitled to receive proportionately any dividends that may be declared by our board of directors, subject to any preferential rights of outstanding preferred stock. In the event of our liquidation, dissolution or winding up, holders of common stock will be entitled to receive proportionately any of our assets remaining after the payment of liabilities and subject to the prior rights of any outstanding preferred stock. Holders of common stock have no preemptive, subscription, redemption or conversion rights.

Shelf Registration. In September 2009, we filed with the SEC a shelf registration statement on Form S-3 for the offer and sale from time to time up to $75 million of our debt and equity securities.  The amount available under the registration statement at March 12, 2010 was approximately $65.1 million.

Issuances of Common Stock and Warrants.  The table below summarizes placements of our shares of common stock and warrants since the inception of the Company and warrants outstanding at December 31, 2009:

   
Shares
    
Proceeds
    
Warrants Outstanding
at December 31, 2009
  
   
Common Stock
    
Warrant
    
Gross
    
Net
    
Amount
    
Exercise Price
    
Expiration
  
Company
                                          
Formation
     40,500,000       -     $ 53,000     $ 53,000       -       -       -  
Shares issued
                                                        
2002
     5,250,500       -       3,413,000       3,051,000       -       -       -  
2003
     10,595,961       8,903,270       6,607,000       5,382,000       -       -       -  
2004
     18,186,471       11,042,215       15,962,000       14,621,000       198,314     $ 0.80 - $2.50    
Jan 2010
  
2005
     14,893,292       150,000       13,404,000       12,469,000       -       -       -  
2006
     25,514,511       -       25,881,000       24,953,000       -       -       -  
2007 (1)
     11,485,452       4,019,908       15,000,000       14,814,000       4,019,908     $ 2.61    
Aug 2012
  
2008 (2)
     24,000,000       8,400,000       12,000,000       11,808,000       8,400,000     $ 1.00    
May 2013
  
2009 (3)
     11,558,645       12,043,458       14,900,855       13,898,173       4,623,458     $ 1.25    
Dec. 2014
  
      161,984,832       44,558,851       107,220,855       101,049,173       17,241,680                  
 
(1)
Registered offering completed in August 2007.  The warrants will terminate on the earlier of expiration date indicated or the date fixed for redemption under the warrant agreement.  We may redeem the warrants if the shares of the Company's common stock trade at a price equal to or in excess of $3.92 per share for fifteen or more consecutive trading days.
(2)
Registered offering completed in the second quarter of 2008.  The warrants will terminate on the earlier of expiration date indicated or the date fixed for redemption under the warrant agreement.  We may redeem the warrants if the shares of the Company's common stock trade at a price equal to or in excess of $2 per share for fifteen or more consecutive trading days.
(3)
On March 13, 2009, FEEB issued an Exchangeable Note, $10 million principal amount, to Arrow for $10 million cash.  In addition, Arrow received warrants to purchase 7,420,000 shares of common stock, which expired in December 2009.  A registered offering was completed in the fourth quarter of 2009.  The warrants will terminate on the earlier of expiration date indicated or the date fixed for redemption under the warrant agreement.  We may redeem the warrants if the shares of the Company's common stock trade at a price equal to or in excess of $1.875 per share for fifteen or more consecutive trading days.

 
Registered offering completed in March 2010.  Warrants to purchase up to 4.7 million shares of common stock were issued.  The warrants issued to the investors in the offering expire on March 11, 2015 and the warrants issued to the placement agent expire on November 4, 2014.  See Note 13 – "Subsequent Event."

Basic and Diluted Shares Outstanding.  Our basic and diluted numbers of shares outstanding in each of the three years presented were the same because we had net losses.  There were (1) 9,952,167, 11,320,500, and 9,965,000 options as of December 31, 2009, 2008 and 2007, respectively; and (2) 17,241,680, 12,618,222, and 4,368,222 warrants as of December 31, 2009, 2008 and 2007, respectively.

Resale Restrictions.  On December 31, 2009, we had 173,836,960 shares of common stock outstanding, of which 6,085,533 shares, or 3.5%, were subject to resale restrictions.

Preferred Stock. Our board of directors has the authority, without further action by the stockholders, to issue up to 500,000,000 shares of preferred stock in one or more series and to designate the rights, preferences, privileges and restrictions of each series. The issuance of preferred stock could have the effect of restricting dividends on the common stock, diluting the voting power of the common stock, impairing the liquidation rights of the common stock or delaying or preventing our change in control without further action by the stockholders. We have no present plans to issue any shares of preferred stock.

Stock Subscription Receivable. In December 2009, we completed a transaction for the sale of 11.6 million shares of our common stock and warrants to purchase up to 4.6 million shares of our common stock for total net proceeds of $4.3 million under our shelf registration.  Stock subscription receivable at December 31, 2009 was $275,000, which was paid on January 5, 2010.

Warrants. The following table summarizes warrant transactions for the years ended December 31, 2009, 2008 and 2007.

   
2009
    
2008
    
2007
  
Outstanding at beginning of year
     12,618,222       4,368,222       8,661,589  
Issued related to
                        
Current year's share placements
     12,043,458       8,400,000       4,019,908  
Prior year's share placements
     -       -       -  
Exercised
     -       -       (12,650 )
Expired
     (7,420,000 )     (150,000 )     (8,300,625 )
Outstanding at end of year (1)
     17,241,680       12,618,222       4,368,222  

(1)
The same amount of shares of our common stock authorized was reserved for the exercise of the warrants.
 
Stock Options. In May 2005, our stockholders approved the 2005 Plan, which permits the granting of incentive stock options, stock appreciation rights, restricted stock, restricted stock units and other stock-based awards to employees, consultants and members of the board of directors.  At the annual general meeting of stockholders of the Company held on July 15, 2009, the Company's stockholders approved an amendment to the 2005 Plan which increased the number of shares of common stock issuable from 7,500,000 shares to 12,500,000 shares and increased the number of shares of common stock that may be granted as nonvested stock, nonvested stock units or any other stock-based awards from 2,400,000 to 3,900,000 shares.  Since the amendments were approved, we have not awarded any options to purchase our common stock or any shares of nonvested stock or other full-valued stock-based award.  Our shareholders voted in December 2007 to add 4,000,000 shares of common stock to the 2005 Plan.

During the first half of 2009, we awarded options to purchase up to 1,686,000 shares of our common stock and 1,190,000 shares of nonvested stock under the 2005 Plan to employees and members of the board of directors, and options to purchase up to 220,000 shares of our common stock and 100,000 shares of nonvested stock outside the 2005 Plan to a new employee and consultants.


The following table summarizes stock option transactions for the years ended December 31, 2009, 2008 and 2007:

   
2009
    
2008
    
2007
  
   
Shares
Underlying
Options
    
Weighted
Average
Exercise
Price
    
Shares
Underlying
Options
    
Weighted
Average
Exercise
Price
    
Shares
Underlying
Options
    
Weighted
Average
Exercise
Price
  
Outstanding at beginning of year
     11,320,500     $ 1.25       9,965,000     $ 1.36       10,203,000     $ 1.44  
Granted
     1,906,000       0.40       2,604,500       0.65       3,581,000       1.16  
Exercised
     -       -       -       -       (660,000 )     0.65  
Canceled
     -       -       (125,133 )     1.04       (1,840,000 )     1.09  
Forfeited
     (433,333 )     0.54       (543,867 )     1.09       (1,219,000 )     2.00  
Expired
     (2,841,000 )     1.16       (580,000 )     0.65       (100,000 )     3.85  
Outstanding at end of year
     9,952,167       1.14       11,320,500       1.25       9,965,000       1.36  
                                                 
Options exercisable at end of year
     6,636,167       1.41       8,085,467       1.43       7,176,200     $ 1.47  

13.  Subsequent Event

On March 11, 2010, we completed a transaction for the sale of 11.7 million shares of our common stock and warrants to purchase up to 4.7 million shares of our common stock for total net proceeds of $4.6 million under our shelf registration.  The amount available under the registration statement at March 12, 2010 was approximately $65.1 million.

 
SUPPLEMENTAL INFORMATION TO CONSOLIDATED FINANCIAL STATEMENTS

Unaudited Quarterly Financial Information (In Thousands, Except Per Share Data):

   
Quarter Ended
        
   
March 31
    
June 30
    
September 30
    
December 31
    
Year
  
2009
                              
Revenues
   $ -     $ -     $ -     $ -     $ -  
Total expenses
     3,109       3,506       3,343       2,916       12,874  
Net loss
     (3,161 )     (3,775 )     (3,627 )     (3,192 )     (13,755 )
                                         
Basic and diluted
                                        
- Earnings per share
   $ (0.02 )   $ (0.02 )   $ (0.02 )   $ (0.02 )   $ (0.08 )
- Weighted average shares outstanding
     161,301       162,370       162,582       162,730       162,251  
                                         
2008
                                        
Revenues
   $ -     $ -     $ -     $ -     $ -  
Total expenses
     5,220       4,175       4,369       8,938       22,702  
Net loss
     (5,126 )     (4,222 )     (4,335 )     (8,908 )     (22,591 )
                                         
Basic and diluted
                                        
- Earnings per share
   $ (0.04 )   $ (0.03 )   $ (0.03 )   $ (0.06 )   $ (0.15 )
- Weighted average shares outstanding
     137,207       144,978       161,213       161,305       151,231  
 

SCHEDULE II

FAR EAST ENERGY CORPORATION
VALUATION AND QUALIFYING ACCOUNTS

For Years Ended December 31, 2009, 2008 and 2007
(In thousands)

         
Additions
              
Description
  
Balance at
Beginning
of Period
    
Charged to
Cost and
Expense
    
Charged to
Other
Accounts
    
Deductions
    
Balance
at End of
Period
  
2009 deferred tax valuation allowance
   $ 2,436     $ 1,291     $ -     $ -     $ 3,727  
2008 deferred tax valuation allowance
     2,789       (353 )     -       -       2,436  
2007 deferred tax valuation allowance
     1,950       839       -       -       2,789  
 

ITEM 9.  CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE

None.

ITEM 9A.  CONTROLS AND PROCEDURES

Evaluation of Disclosure Controls and Procedures

We carried out an evaluation under the supervision and with the participation of our management, including our chief executive officer and chief financial officer, of the effectiveness of our disclosure controls and procedures (as defined in Rule 13a-15(e) under the Exchange Act), as of the end of the period covered by this report. Based upon that evaluation, our Chief Executive Officer and Chief Financial Officer concluded that our disclosure controls and procedures were effective as of the end of the period covered by this report.

Management's Report on Internal Control over Financial Reporting

Management's report on internal control over financial reporting as of December 31, 2009 is included on page 49 of this report. Additionally, our independent registered public accounting firm, JonesBaggett LLP , that audited our consolidated financial statements included in this report, has issued an attestation report on the effectiveness of our internal control over financial reporting as of December 31, 2009, which is included on page 51 of this report.

Changes in Internal Controls

In connection with the evaluation described above, our management, including our Chief Executive Officer and Chief Financial Officer, identified no change in our internal control over financial reporting that occurred during the fiscal quarter ended December 31, 2009, that has materially affected, or is reasonably likely to materially affect, our internal controls over financial reporting.

ITEM 9B.  OTHER INFORMATION

Annual Meeting of Shareholders

The Company’s annual meeting of shareholders is scheduled for December 9, 2010, 10:00 a.m. at the Crowne Plaza North Greenspoint, 425 N. Sam Houston Parkway E., Houston, Texas.  The Board of Directors has established Thursday, October 28, 2010, as the record date for determining stockholders of record entitled to notice of, and to vote at, the 2010 Annual Meeting of Stockholders.  In order to be considered for the 2010 annual meeting of shareholders and included in the Company’s proxy materials, shareholders must have submitted proposals and nominations between August 11, 2010 and September 10, 2010 and complied with the requirements set forth in the Company’s bylaws.


PART III

ITEM 10.  DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE

Certain information regarding our executive officers has been presented under “Executive Officers” included in Item 1. “Business,” above.

Reference is made to the sections entitled “Election of Directors” "Corporate Governance" and “Consideration of Director Nominees” and “Section 16(a) Beneficial Ownership Reporting Compliance” of our Proxy Statement for our 2010 Annual Meeting of Stockholders, which sections are incorporated herein by reference.
 
We have adopted a Code of Business Conduct, which applies to all employees, including our chief executive officer and our chief financial officer and principal accounting officer. The full text of our Code of Business Conduct is published on our website, at www.fareastenergy.com, under the “Investor-Relations” caption. We intend to disclose future amendments to, or waivers from, certain provisions of this Code on our website within four business days following the date of such amendment or waiver.  Information contained on the website is not part of this report.
 
 
ITEM 11.  EXECUTIVE COMPENSATION

Reference is made to the sections entitled “Compensation Discussion and Analysis,” “Executive Compensation,”  "Compensation Committee Interlocks and Insider Participation," “Report of the Compensation Committee,” and "Directors' Compensation" of our Proxy Statement for our 2010 Annual Meeting of Stockholders, which sections are incorporated herein by reference. The portion of the incorporated material from the Report of the Compensation Committee and references to the independence of directors are not deemed to be “soliciting material” or “filed” with the SEC, are not subject to the liabilities of Section 18 of the Exchange Act and shall not be deemed incorporated by reference into any of the filings previously made or made in the future by our company under the Exchange Act or the Securities Act of 1933, as amended (except to the extent our company specifically incorporates any such information into a document that is filed).
 
 
ITEM 12.  SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS

Reference is made to the section entitled “Security Ownership” “Equity Compensation Plan Information” of our Proxy Statement for its 2010 Annual Meeting of Stockholders, which section is incorporated herein by reference.


ITEM 13.  CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR INDEPENDENCE

Reference is made to the section entitled "Certain Relationships and Related Transactions, and Director Independence” of our Proxy Statement for our 2010 Annual Meeting of Stockholders, which section is incorporated herein by reference.


ITEM 14.  PRINCIPAL ACCOUNTANT FEES AND SERVICES

The information required by this item is incorporated herein by reference from the section entitled “Independent Registered Public Accounting Firm Fee Information” of our Proxy Statement for our 2010 Annual Meeting of Stockholders.


PART IV

ITEM 15.  EXHIBITS AND FINANCIAL STATEMENT SCHEDULES

 
(a)
The following documents are filed as part of this report:

 
1.
Financial Statements.

Our consolidated financial statements are included in Part II, Item 8 of this report:

 
Page
Report of Independent Registered Public Accounting Firm
50
Consolidated Balance Sheets
52
Consolidated Statements of Operations
53
Consolidated Statements of Stockholders' Equity
54
Consolidated Statements of Cash Flows
55
Notes to the Consolidated Financial Statements
56

 
2.
Financial statement schedules and supplementary information required to be submitted.

Schedule II — Valuation and qualifying accounts.
74

Schedules other than that listed above are omitted because they are not applicable.

 
3.
Exhibits

A list of the exhibits filed or furnished with this report on Form 10-K (or incorporated by reference to exhibits previously filed or furnished by us) is provided in the Exhibit Index beginning on page 79 of this report. Those exhibits incorporated by reference herein are indicated as such by the information supplied in the parenthetical thereafter. Otherwise, the exhibits are filed herewith.


SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized, on March 15, 2010.

 
FAR EAST ENERGY CORPORATION
     
 
By:
/s/ Michael R. McElwrath
   
Michael R. McElwrath
   
Chief Executive Officer

Pursuant to the requirements of the Securities Exchange Act of 1934, this report is signed below by the following persons on behalf of the registrant and in the capacities with Far East Energy Corporation indicated and on March 15, 2010.



 
Signature
 
  
Title
  
 
/s/ Michael R. McElwrath
  
Chief Executive Officer,
  
 
(Michael R. McElwrath)
  
President and Director
(Principal Executive Officer)
  
         
 
/s/  K. Andrew Lai
  
Chief Financial Officer
  
 
(K. Andrew Lai)
  
(Principal Financial and Accounting Officer)
  
         
 
*  Donald A. Juckett
  
Chairman of the Board
  
 
(Donald A. Juckett)
      
         
 
*  William A. Anderson
  
Director
  
 
(William A. Anderson)
      
         
 
*  C. P. Chiang
  
Director
  
 
(C. P. Chiang)
      
         
 
* Thomas E. Williams
  
Director
  
 
(Thomas E. Williams)
      
         
 
*  John C. Mihm
  
Director
  
 
(John C. Mihm)
      
         
 
*  Lucian L. Morrison
  
Director
  
 
(Lucian L. Morrison)
      
         
         
*
By:   /s/   K. Andrew Lai
      
 
(K. Andrew Lai)
      
 
(Attorney-in-fact for persons indicated)
      
 

INDEX OF EXHIBITS
Exhibit
Number
Description
3.1
Articles of Incorporation of the Company, as amended (filed as Exhibit 3.1 to the Company's Annual Report on Form 10-K for the year ended December 31, 2004, which was filed on March 15, 2005, and incorporated herein by reference).
3.2
Amended and Restated Bylaws of the Company (filed as Exhibit 3.1 to the Company's Current Report on Form 8-K filed on March 17, 2005, and incorporated herein by reference).
4.1
Articles of Incorporation of the Company, as amended (included as Exhibit 3.1).
4.2
Amended and Restated Bylaws of the Company (included as Exhibit 3.2).
4.3
Specimen stock certificate (filed as Exhibit 4.5 to the Company's Annual Report on Form 10-K for the year ended December 31, 2004, which was filed on March 15, 2005, and incorporated herein by reference).
4.4
Form of Warrant (filed as Exhibit 4.1 to the Company's Current Report on Form 8-K filed on August 27, 2007, and incorporated herein by reference).
4.5
Warrant Agreement, dated August 27, 2007, between the Company and Continental Stock Transfer & Trust Company (filed as Exhibit 4.2 to the Company's Current Report on Form 8-K filed on August 27, 2007, and incorporated herein by reference).
4.6
Form of Warrant (filed as Exhibit 4.1 to the Company's Current Report on Form 8-K filed on May 30, 2008, and incorporated herein by reference).
4.7
Warrant Agreement, dated May 30, 2008, between the Company and Continental Stock Transfer & Trust Company (filed as Exhibit 4.2 to the Company's Current Report on Form 8-K filed on May 30, 2008, and incorporated herein by reference).
4.8
Warrant, dated March 13, 2009, issued to Arrow Energy International Pte Ltd. (filed as Exhibit 4.2 to the Company's Current Report on Form 8-K filed on March 16, 2009, and incorporated herein by reference).
4.9
Exchangeable Note, dated March 13, 2009, by Far East Energy (Bermuda), Ltd. for the benefit of Arrow Energy International Pte Ltd. (filed as Exhibit 4.1 to the Company's Current Report on Form 8-K filed on March 16, 2009, and incorporated herein by reference).
4.10
Registration Rights Agreement, dated March 13, 2009, between the Company and Arrow Energy International Pte Ltd. (filed as Exhibit 4.3 to the Company's Current Report on Form 8-K filed on March 16, 2009, and incorporated herein by reference).
4.11
Warrant Agreement between the Company and Continental Stock Transfer & Trust Company (including the form of warrant) (filed as Exhibit 4.1 to the Company's Current Report on Form 8-K filed on December 22, 2009, and incorporated herein by reference).
4.12
Form of Warrant (filed as Exhibit 4.1 to the Company’s Current Report on Form 8-K filed on March 9, 2010, and incorporated herein by reference).
4.13
Form of Securities Purchase Agreement (filed as Exhibit 10.1 to the Company’s Current Report on Form 8-K filed on March 9, 2010, and incorporated herein by reference).
10.1*
Amended and Restated Employment Agreement, dated December 23, 2004, by and between the Company and Michael R. McElwrath (filed as Exhibit 10.1 to the Company's Current Report on Form 8-K filed on December 28, 2004, and incorporated herein by reference).
10.2*
Amended and Restated Nonqualified Stock Option Agreement, dated December 23, 2004, by and between the Company and Michael R. McElwrath (filed as Exhibit 10.3 to the Company's Current Report on Form 8-K filed on December 28, 2004, and incorporated herein by reference).
10.3*
Amended and Restated Nonqualified Stock Option Agreement, dated December 23, 2004, by and between the Company and Michael R. McElwrath (filed as Exhibit 10.4 to the Company's Current Report on Form 8-K filed on December 28, 2004, and incorporated herein by reference).
10.4*
Nonqualified Stock Option Agreement, dated December 23, 2004, by and between the Company and Michael R. McElwrath (filed as Exhibit 10.6 to the Company's Current Report on Form 8-K filed on December 28, 2004, and incorporated herein by reference).
10.5*
Stock Option Agreement, dated May 18, 2004, by and between the Company and Donald Juckett (filed as Exhibit 10.13 to the Company's Annual Report on Form 10-K for the year ended December 31, 2004, which was filed on March 15, 2005, and incorporated herein by reference).
10.6*
Stock Option Agreement, dated June 18, 2004, by and between the Company and Randall D. Keys (filed as Exhibit 10.14 to the Company's Annual Report on Form 10-K for the year ended December 31, 2004, which was filed on March 15, 2005, and incorporated herein by reference).
10.7*
Stock Option Agreement, dated May 24, 2004, by and between the Company and John C. Mihm (filed as
 
 
 
Exhibit 10.15 to the Company's Annual Report on Form 10-K for the year ended December 31, 2004, which was filed on March 15, 2005, and incorporated herein by reference).
10.8*
Stock Option Agreement, dated February 24, 2004, by and between the Company and Thomas Williams (filed as Exhibit 10.16 to the Company's Annual Report on Form 10-K for the year ended December 31, 2004, which was filed on March 15, 2005, and incorporated herein by reference).
10.9
Production Sharing Contract for Exploitation of Coalbed Methane Resources in Enhong and Laochang, Yunnan Province, the People's Republic of China, dated January 25, 2002, by and between China United Coalbed Methane Corp. Ltd. and the Company (filed as Exhibit 2(i) to the Company's Current Report on Form 8-K filed on February 11, 2002, and incorporated herein by reference).
10.10
Modification Agreement for Product Sharing Contract for Exploitation of Coalbed Methane Resources in Enhong and Laochang, Yunnan Province, the People's Republic of China, dated October 20, 2005, between China United Coalbed Methane Corporation Ltd. and the Company (filed as Exhibit 10.1 to the Company's Current Report on Form 8-K filed on October 26, 2005, and incorporated herein by reference).
10.11
Production Sharing Contract for Exploitation of Coalbed Methane Resources for the Quinnan Area in Shanxi Province, Qinshui Basin, the People's Republic of China, dated April 16, 2002, by and between China United Coalbed Methane Corporation Ltd. and the Phillips China Inc. (filed as Exhibit 10.21 to the Company's Annual Report on Form 10-K filed on March 15, 2005, and incorporated herein by reference).
10.12
Application for the Extension of Phase Two of the Exploration Period under the Quinnan PSC, dated December 2, 2005, by and between the Company and China United Coalbed Methane Corporation Ltd. (filed as Exhibit 10.20 to the Company's Annual Report on Form 10-K for the year ended December 31, 2005, which was filed on March 14, 2006, and incorporated herein by reference).
10.13
Application for the Extension of Phase Two of the Exploration Period under the Quinnan PSC, dated March 16, 2006, by and between the Company and China United Coalbed Methane Corporation Ltd. (filed as Exhibit 10.1 to the Company's Current Report on Form 8-K filed on March 17, 2006, and incorporated herein by reference).
10.14
Approval Certificate from the Ministry of Foreign Trade and Economic Cooperation dated December 30, 2002 (filed as Exhibit 2(i) to the Company's Current Report on Form 8-K filed on January 13, 2003, and incorporated herein by reference).
10.15
Memorandum of Understanding, dated March 18, 2003, by and between Phillips China Inc. and the Company (filed as Exhibit 10.1 to the Company's Amendment No. 1 to its Quarterly Report on Form 10-QSB/A for the quarter ended June 30, 2003, which was filed on December 24, 2003, and incorporated herein by reference).
10.16
Farmout Agreement Quinnan PSC, dated June 17, 2003, by and between Phillips China Inc. and the Company (filed as Exhibit 10.2 to the Company's Amendment No. 1 to its Quarterly Report on Form 10-QSB/A for the quarter ended June 30, 2003, which was filed on December 24, 2003, and incorporated herein by reference).
10.17
First Amendment to Farmout Agreement Quinnan PSC, dated December 15, 2003, by and between Phillips China Inc. and the Company (filed as Exhibit 10.26 to the Company's Annual Report on Form 10-K for the year ended December 31, 2004, which was filed on March 15, 2005, and incorporated herein by reference).
10.18
Second Amendment to Farmout Agreement Quinnan PSC, dated December 17, 2004, by and between Phillips China Inc. and the Company (filed as Exhibit 10.01 to the Company's Current Report on Form 8-K filed on December 23, 2004, and incorporated herein by reference).
10.19
Third Amendment to Farmout Agreement Quinnan PSC, dated December 19, 2005, by and between ConocoPhillips China Inc. and the Company (filed as Exhibit 10.1 to the Company's Current Report on Form 8-K filed on December 21, 2005, and incorporated herein by reference).
10.20
Assignment Agreement Quinnan PSC, dated June 17, 2003, by and between Phillips China Inc. and the Company (filed as Exhibit 10.4 to the Company's Amendment No. 1 to its Quarterly Report on Form 10-QSB/A for the quarter ended June 30, 2003, which was filed on December 24, 2003, and incorporated herein by reference).
10.21
Farmout Agreement Shouyang PSC, dated June 17, 2003, by and between Phillips China Inc. and the Company (filed as Exhibit 10.3 to the Company's Amendment No. 1 to its Quarterly Report on Form 10-QSB/A for the quarter ended June 30, 2003, which was filed on December 24, 2003, and incorporated herein by reference).
10.22
First Amendment to Farmout Agreement Shouyang PSC, dated December 15, 2003, by and between Phillips China Inc. and the Company (filed as Exhibit 10.30 to the Company's Annual Report on Form 10-K for the year ended December 31, 2004, which was filed on March 15, 2005, and incorporated herein by
 
 
 
reference).
10.23
Second Amendment to Farmout Agreement Shouyang PSC, dated December 17, 2004, by and between Phillips China Inc. and the Company (filed as Exhibit 10.02 to the Company's Current Report on Form 8-K filed on December 23, 2004, and incorporated herein by reference).
10.24
Third Amendment to Farmout Agreement Shouyang PSC, dated December 19, 2005, by and between ConocoPhillips China Inc. and the Company (filed as Exhibit 10.2 to the Company's Current Report on Form 8-K filed on December 21, 2005, and incorporated herein by reference).
10.25
Assignment Agreement Shouyang PSC, dated June 17, 2003, by and between Phillips China Inc. and the Company (filed as Exhibit 10.5 to the Company's Amendment No. 1 to its Quarterly Report on Form 10-QSB/A for the quarter ended June 30, 2003, which was filed on December 24, 2003, and incorporated herein by reference).
10.26
Application for the Extension of Phase Two of the Exploration Period under the Shouyang PSC, dated December 2, 2005, by and between the Company and China United Coalbed Methane Corporation Ltd. (filed as Exhibit 10.46 to Company's Annual Report on Form 10-K for the year ended December 31, 2005, which was filed on March 14, 2006, and incorporated herein by a reference).
10.27
Application for the Extension of Phase Two of the Exploration Period under the Shouyang PSC, dated March 16, 2006, by and between the Company and China United Coalbed Methane Corporation Ltd. (filed as Exhibit 10.2 to the Company's Current Report on Form 8-K filed on March 17, 2006, and incorporated herein by reference).
10.28*
Far East Energy Corporation 2005 Stock Incentive Plan (filed as Exhibit 10.28 to the Company’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2009, which was filed on August 10, 2009, and incorporated herein by reference).
10.29*
Form of Restricted Stock Agreement for Far East Energy Corporation 2005 Stock Incentive Plan (filed as Exhibit 10.1 to the Company's Current Report on Form 8-K filed on March 23, 2007, and incorporated herein by reference).
10.30*
Form of Non-Qualified Stock Option Agreement for Far East Energy Corporation 2005 Stock Incentive Plan (filed as Exhibit 10.1 to the Company's Current Report on Form 8-K filed on April 19, 2007, and incorporated herein by reference).
10.31*
Form of Incentive Stock Option Agreement for Far East Energy Corporation 2005 Stock Incentive Plan (filed as Exhibit 10.2 to the Company's Current Report on Form 8-K filed on April 19, 2007, and incorporated herein by reference).
10.32*
Form of Letter Agreement with the Company's non-employee directors (filed as Exhibit 10.4 to the Company's Current Report on Form 8-K filed on April 19, 2007, and incorporated herein by reference).
10.33*
First Amendment to Amended and Restated Employment Agreement, dated April 16, 2007, between the Company and Michael R. McElwrath (filed as Exhibit 10.5 to the Company's Current Report on Form 8-K filed on April 19, 2007, and incorporated herein by reference).
10.34
Modification Agreement, dated April 24, 2007, for Production Sharing Contract for Exploitation of Coalbed Methane Resources for the Shouyang Area in Shanxi Province, Qinshui Basin, the People's Republic of China, dated April 16, 2002, by and among China United Coalbed Methane Corporation Ltd., ConocoPhillips China Inc. and Far East Energy (Bermuda), Ltd. (filed as Exhibit 10.1 to the Company's Current Report on Form 8-K filed on April 27, 2007, and incorporated herein by reference).
10.35
Modification Agreement, dated April 24, 2007, for Production Sharing Contract for Exploitation of Coalbed Methane Resources for the Quinnan Area in Shanxi Province, Qinshui Basin, the People's Republic of China, dated April 16, 2002, by and among China United Coalbed Methane Corporation Ltd., ConocoPhillips China Inc. and Far East Energy (Bermuda), Ltd. (filed as Exhibit 10.2 to the Company's Current Report on Form 8-K filed on April 27, 2007, and incorporated herein by reference).
10.36
Modification Agreement dated April 24, 2007 for Production Sharing Contract for Exploitation of Coalbed Methane Resources for the Enhong and Laochang Area in Yunnan Province, the People's Republic of China, dated December 3, 2002, between China United Coalbed Methane Corporation Ltd. and Far East Energy (Bermuda), Ltd. (filed as Exhibit 10.3 to the Company's Current Report on Form 8-K filed on April 27, 2007, and incorporated herein by reference).
10.37
Stock Subscription Agreement, dated August 24, 2007, between the Company and International Finance Corporation (filed as Exhibit 10.1 to the Company's Current Report on Form 8-K filed on August 27, 2007, and incorporated herein by reference).
10.38*
Non-Qualified Stock Option Agreement, dated October 1, 2007, by and between the Company and William A. Anderson (filed as Exhibit 10.52 to the Company's Quarterly Report on Form 10-Q for the
 
 
 
quarter ended September 30, 2007, which was filed on November 7, 2007, and incorporated herein by reference).
10.39*
Second Amendment to Amended and Restated Employment Agreement, dated November 26, 2007, between the Company and Michael R. McElwrath (filed as Exhibit 10.1 to the Company's Current Report on Form 8-K filed on November 27, 2007, and incorporated herein by reference).
10.40*
Form of Restricted Stock Agreement (filed as Exhibit 4.4 to the Company's Registration Statement on Form S-8 (File No. 333-148363) filed on December 27, 2007, and incorporated herein by reference).
10.41*
Form of Non-Qualified Stock Option Agreement (filed as Exhibit 10.54 to the Company's Annual Report on Form 10-K for the year ended December 31, 2007, which was filed on March 13, 2008, and incorporated herein by reference).
10.42*
Restricted Stock Agreement, dated December 27, 2007, between the Company and Michael R. McElwrath (filed as Exhibit 10.55 to the Company's Annual Report on Form 10-K for the year ended December 31, 2007, which was filed on March 13, 2008, and incorporated herein by reference).
10.43*
Restricted Stock Agreement, dated December 27, 2007, between the Company and Thomas E. Williams (filed as Exhibit 10.56 to the Company's Annual Report on Form 10-K for the year ended December 31, 2007, which was filed on March 13, 2008, and incorporated herein by reference).
10.44*
Non-Qualified Stock Option Agreement, dated January 9, 2008, between the Company and Lucian L. Morrison (filed as Exhibit 10.58 to the Company's Annual Report on Form 10-K for the year ended December 31, 2007, which was filed on March 13, 2008, and incorporated herein by reference).
10.45*
Employment Agreement, dated March 12, 2008, between Far East Energy (Bermuda), Ltd. and Phil Christian (filed as Exhibit 10.1 to the Company's Current Report on Form 8-K filed on March 13, 2008, and incorporated herein by reference).
10.46*
Non-Qualified Stock Option Agreement, dated March 12, 2008, between the Company and Phil Christian (filed as Exhibit 10.2 to the Company's Current Report on Form 8-K filed on March 13, 2008, and incorporated herein by reference).
10.47*
Amended and Restated Nonqualified Stock Option Agreement, dated December 27, 2007, by and between the Company and Thomas Williams (filed as Exhibit 10.61 to the Company's Annual Report on Form 10-K for the year ended December 31, 2007, which was filed on March 13, 2008, and incorporated herein by reference).
10.48*
Second Amended and Restated Nonqualified Stock Option Agreement, dated December 27, 2007, by and between the Company and Michael McElwrath (filed as Exhibit 10.64 to the Company's Annual Report on Form 10-K for the year ended December 31, 2007, which was filed on March 13, 2008, and incorporated herein by reference). The original option agreement was entered into on January 29, 2002.
10.49*
Second Amended and Restated Nonqualified Stock Option Agreement, dated December 27, 2007, by and between the Company and Michael McElwrath (filed as Exhibit 10.65 to the Company's Annual Report on Form 10-K for the year ended December 31, 2007, which was filed on March 13, 2008, and incorporated herein by reference). The original option agreement was entered into on October 13, 2003.
10.50*
Third Amendment to Amended and Restated Employment Agreement, dated March 7, 2008, between the Company and Michael R. McElwrath (filed as Exhibit 10.3 to the Company's Current Report on Form 8-K filed on March 13, 2008, and incorporated herein by reference).
10.51
Stock Subscription Agreement, dated June 2, 2008, between the Company and International Finance Corporation (filed as Exhibit 10.64 to the Company's Quarterly Report on Form 10-Q for the quarter ended June 30, 2008, which was filed on August 6, 2008, and incorporated herein by reference).
10.52*
Amended and Restated Employment Agreement, dated October 1, 2008, by and between the Company and Andrew Lai (filed as Exhibit 10.1 to the Company's Current Report on Form 8-K/A filed on October 6, 2008, and incorporated herein by reference).
10.53*
First Amendment to Non-Qualified Stock Option Agreement, dated December 19, 2008, between the Company and Michael McElwrath (filed as Exhibit 10.63 to the Company's Annual Report on Form 10-K for the year ended December 31, 2008, which was filed on March 30, 2009, and incorporated herein by reference). The original option agreement was entered into on February 2, 2006.
10.54*
Second Amended and Restated Nonqualified Stock Option Agreement, dated January 14, 2009, between the Company and Michael McElwrath (filed as Exhibit 10.64 to the Company's Annual Report on Form 10-K for the year ended December 31, 2008, which was filed on March 30, 2009, and incorporated herein by reference). The original option agreement was entered into on January 29, 2002.
10.55*
Second Amended and Restated Nonqualified Stock Option Agreement, dated January 14, 2009, between the Company and Thomas Williams (filed as Exhibit 10.65 to the Company's Annual Report on Form 10-K
 
 
 
for the year ended December 31, 2008, which was filed on March 30, 2009, and incorporated herein by reference). This Agreement amended 100,000 options, which vested on or prior to December 31, 2004, of the original option agreement dated February 24, 2004.
10.56*
Third Amended and Restated Nonqualified Stock Option Agreement, dated January 14, 2009, between the Company and Thomas Williams (filed as Exhibit 10.66 to the Company's Annual Report on Form 10-K for the year ended December 31, 2008, which was filed on March 30, 2009, and incorporated herein by reference). This Agreement amended 300,000 options, which vested on or after January 1, 2005, of the original option agreement dated February 24, 2004.
10.57*
Amended and Restated Nonqualified Stock Option Agreement, dated January 14, 2009, between the Company and John Mihm (filed as Exhibit 10.67 to the Company's Annual Report on Form 10-K for the year ended December 31, 2008, which was filed on March 30, 2009, and incorporated herein by reference). The original option agreement was entered into on May 24, 2004.
10.58*
Amended and Restated Nonqualified Stock Option Agreement, dated January 14, 2009, between the Company and Don Juckett (filed as Exhibit 10.68 to the Company's Annual Report on Form 10-K for the year ended December 31, 2008, which was filed on March 30, 2009, and incorporated herein by reference). The original option agreement was entered into on May 18, 2004.
10.59*
First Amendment to Employment Agreement, dated December 19, 2008, between the Company and Phil Christian (filed as Exhibit 10.69 to the Company's Annual Report on Form 10-K for the year ended December 31, 2008, which was filed on March 30, 2009, and incorporated herein by reference).
10.60*
Second Amendment to Employment Agreement, dated December 31, 2008, between the Company and Phil Christian (filed as Exhibit 10.70 to the Company's Annual Report on Form 10-K for the year ended December 31, 2008, which was filed on March 30, 2009, and incorporated herein by reference).
10.61*
First Amendment to Amended and Restated Employment Agreement, dated December 19, 2008, between the Company and Andrew Lai (filed as Exhibit 10.71 to the Company's Annual Report on Form 10-K for the year ended December 31, 2008, which was filed on March 30, 2009, and incorporated herein by reference).
10.62*
Fourth Amendment to Amended and Restated Employment Agreement, dated December 19, 2008, between the Company and Michael McElwrath (filed as Exhibit 10.72 to the Company's Annual Report on Form 10-K for the year ended December 31, 2008, which was filed on March 30, 2009, and incorporated herein by reference).
10.63*
Form of Nonqualified Stock Option Agreement for Far East Energy Corporation 2005 Stock Incentive Plan (filed as Exhibit 10.73 to the Company's Annual Report on Form 10-K for the year ended December 31, 2008, which was filed on March 30, 2009, and incorporated herein by reference).
10.64
Securities Purchase Agreement, dated March 13, 2009, among the Company, Far East Energy (Bermuda), Ltd., and Arrow Energy International Pte Ltd. (filed as Exhibit 10.1 to the Company's Current Report on Form 8-K filed on March 16, 2008, and incorporated herein by reference).
10.65
Farmout Agreement, dated March 13, 2009, between the Company, Far East Energy (Bermuda), Ltd., and Arrow Energy International Pte Ltd. (filed as Exhibit 10.2 to the Company's Current Report on Form 8-K filed on March 16, 2008, and incorporated herein by reference).
10.66*
Fifth Amendment to Amended and Restated Employment Agreement, dated May 18, 2009, between the Company and Michael R. McElwrath (filed as Exhibit 10.1 to the Company's Current Report on Form 8-K filed on May 18, 2009, and incorporated herein by reference).
10.67
Modification Agreement for Production Sharing Contract for Exploitation of Coalbed Methane Resources for the Shouyang Area in Shanxi Province, Qinshui Basin, The People’s Republic of China (filed as Exhibit 10.1 to the Company’s Current Report on From 8-K filed on August 27, 2009, and incorporated herein by reference).
10.68
Modification Agreement for Production Sharing Contract for Exploitation of Coalbed Methane Resources in Enhong and Laochang Area, Yunnan Province, The People’s Republic of China (filed as Exhibit 10.2 to the Company’s Current Report on From 8-K filed on August 27, 2009, and incorporated herein by reference).
10.69
Agreement, dated October 6, 2009, between Far East Energy (Bermuda), Ltd. and Arrow Energy International Ltd (filed as Exhibit 10.1 to the Company's Current Report on Form 8-K filed on October 7, 2009, and incorporated herein by reference).
10.70*
Release of Claims, dated October 6, 2009, by and among Phil Christian, the Company, and Far East Energy (Bermuda), Ltd. (filed as Exhibit 10.70 to the Company's Quarterly Report on Form 10-Q for the quarter ended September 30, 2009, and incorporated herein by reference).
 
 
10.71
Agreement, dated November 20, 2009, between Far East Energy (Bermuda), Ltd. and Arrow Energy International Ltd (filed as Exhibit 10.1 to the Company's Current Report on Form 8-K filed on November 23, 2009, and incorporated herein by reference).
10.72
Placement Agent Agreement between the Company and Pritchard Capital Partners, LLP (filed as Exhibit 10.2 to the Company's Current Report on Form 8-K filed on December 22, 2009, and incorporated herein by reference).
21.1
List of Subsidiaries of Far East Energy Corporation.
23.1
Consent of JonesBaggett LLP.
Powers of Attorney.
Certification of Chief Executive Officer of the Company under Section 302 of the Sarbanes-Oxley Act of 2002.
Certification of Chief Financial Officer of the Company under Section 302 of the Sarbanes-Oxley Act of 2002.
Certification of Chief Executive Officer of the Company Pursuant to 18 U.S.C. Sec. 1350.
Certification of Chief Financial Officer of the Company Pursuant to 18 U.S.C. Sec. 1350.
 
____________
*
Management contract or compensatory plan arrangement.
†
Filed herewith
 
 
84