UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-K

(Mark One)

~~[X]~~x ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 For the fiscal year ended December 31, ~~2012~~2014

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

For the transition period from ________________ to _________________.

Commission file number 000-52852

BIOFUELS POWER CORPORATION

(Exact name of registrant as specified in its charter)

TEXAS	56-2471691
(State or other jurisdiction of	(I.R.S. Employer
incorporation or organization)	Identification No.)

20202 Hwy 59 N, Suite 210 Humble, Texas	77338
(Address of principal executive offices)	(zip code)

Registrant’s telephone number, including area code:

(281) 364-7590

Securities Registered pursuant to Section 12(g) of the 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 ~~___~~o	No Xx
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 ~~___~~o	No Xx
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 and (2) has been subject to such filing requirements for the past 90 days.	Yes Xx	No o
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.

Table of Contents

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

Large accelerated filer	o	Accelerated filer		o
Non-accelerated filer	o	Smaller reporting company		x
Indicate by check mark if the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).			~~Yes___~~Yes o		No Xx

State the aggregate market value of the voting and non-voting common equity held by non-affiliates computed by reference to the price at which the common equity was last sold, or the average bid and asked price of such common equity, as of the last business day of the registrant’s most recently completed second fiscal quarter.

There has never been a public market for our stock. Based on the most recent price report on over the counter exchanges the aggregate market value of the Company is $39,~~768~~708,000 at March 31, ~~2011~~2015.

Indicate the number of shares outstanding of each of the registrant’s classes of common stock, as of the latest practicable date.

Title of Class	Outstanding at March 31, ~~2013~~2015
Common Stock, $0.001 Par Value	3134,~~442~~672,760 Shares

No documents are incorporated by reference in this Form 10-K.

Table of Contents

TABLE OF CONTENTS

PART I

ITEM 1	Business	5
ITEM 1A	Risk Factors	138
ITEM 2	Properties	2013
ITEM 3	Legal Proceedings	2013
ITEM 4	Submission of Matters to a Vote Of Security Holders	2013

PART II

ITEM 5	Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities	2114
ITEM 6	Selected Financial Data	2416
ITEM 7	Management’s Discussion and Analysis of Financial Condition and Results of Operations	2416
ITEM 7A	Quantitative and Qualitative Disclosures About Market Risks	2618
ITEM 8	Financial Statements and Supplementary Data	2719
ITEM 9	Changes in and Disagreements With Accountants on Accounting and Financial Disclosure	4233
ITEM 9A	Controls And Procedures	4233

PART III

ITEM 10	Directors, Executive Officers and Corporate Governance	4334
ITEM 11	Executive Compensation	4637
ITEM 12	Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters	4839
ITEM 13	Certain Relationships and Related Transactions, and Director Independence	4940
ITEM 14	Principal Accounting Fees and Services	5041

PART IV

ITEM 15	Exhibits, Financial Statement Schedules	5041
	Signatures	5143

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CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING STATEMENTS

“Forward-looking” statements have been included throughout this report on Form 10-K. These statements arise most frequently in connection with our attempt to predict future events. The words “may,” “will,” “expect,” “believe,” “plan,” “intend,” “anticipate,” “estimate,” “continue,” and similar expressions, as well as discussions of our strategy, are intended to identify forward-looking statements. Although we believe that these forward-looking statements are based on reasonable assumptions, we can give no assurance that our expectations will in fact occur and caution that actual results may differ materially from those in the forward-looking statements. The important factors listed in the section entitled “Risk Factors,” as well as any cautionary language in this report on Form 10-K, provide examples of risks, uncertainties and events that may cause our actual results to differ materially from the expectations described in any forward-looking statements. You should be aware that the occurrence of the events described in this Report on Form 10-K could have an adverse effect on our business or financial condition. You should also be aware that the “forward-looking” statements are subject to a number of risks, assumptions and uncertainties, such as:

· Our early stage of development, our brief operating history and our rapidly evolving business plan which make our prospects difficult to evaluate; · Our need to raise substantial capital to finance our planned expansion, our history of significant operating losses and our inability to provide any assurances that our planned operations will be profitable; · Our history of significant related party transactions with former affiliates that may give rise to conflicts of interest, result in significant losses to our company or otherwise impair investor confidence; · Our reliance on part-time executive officers who are engaged in other activities and will face conflicts of interest in allocating their time among various interests; · Our need to obtain a premium price for green electricity, successfully execute our growth strategy in a rapidly evolving market and develop ancillary sources of revenue; · Our exposure to substantial volatility in the market prices for agricultural commodities used as biodiesel feedstock and our inability to fully hedge against commodity price changes which may cause our results of operations to fluctuate; · Our exposure to a variety of risks associated with the construction, permitting and operation of biodiesel fueled electric power generating facilities; · Our dependence on tax incentives, governmental subsidies and environmental policies and the risk that incentives that presently favor the use of biodiesel for power generation may change · Our inability to rely on pricing as a principal competitive advantage and our need to focus our marketing efforts primarily on environmental benefits; · Our ability to satisfy our future capital requirements and react to business opportunities; · The absence of a public market for our common stock and the time, effort and expense associated with any effort to develop and active, stable and sustained trading market; and · Other factors including those detailed in this report on Form 10-K under the heading “Risk Factors.”

·	Our need to raise substantial capital to finance our planned expansion, our history of significant operating losses and our inability to provide any assurances that our planned operations will be profitable;

·	Our history of significant related party transactions with former affiliates that may give rise to conflicts of interest, result in significant losses to our company or otherwise impair investor confidence;

·	Our reliance on part-time executive officers who are engaged in other activities and will face conflicts of interest in allocating their time among various interests;

·	Our need to obtain a premium price for our sales, successfully execute our growth strategy in a rapidly evolving market and develop ancillary sources of revenue;

·	Our exposure to substantial volatility in the market prices for feedstock and our inability to fully hedge against commodity price changes which may cause our results of operations to fluctuate;

·	Our exposure to a variety of risks associated with the construction, permitting and operation of our planned facilities;

·	Our inability to rely on pricing as a principal competitive advantage and our need to focus our marketing efforts;

·	Our ability to satisfy our future capital requirements and react to business opportunities;

·	Other factors including those detailed in this report on Form 10-K under the heading “Risk Factors.”

You should not unduly rely on forward-looking statements, which speak only as of the date of this report on Form 10-K. Except as required by law, we are not obligated to publicly release any revisions to these forward-looking statements to reflect events or circumstances occurring after the date of this report or to reflect the occurrence of unanticipated events. All subsequent written and oral forward-looking statements attributable to us, or persons acting on our behalf, are expressly qualified in their entirety by the forward-looking statements in this report.

Table of Contents

ITEM 1— BUSINESS

History:

From inception through mid-2006, we engaged in a largely unsuccessful effort to complete live fire testing and obtain military procurement contracts for the Deto-Stop explosion prevention system. In December 2006, we changed our name to Biofuels Power Corporation, assumed control over two partnerships described below that were organized and syndicated by Texoga during 2006, raised approximately $1.5 million in equity from the sale of common stock and reformulated our business plan to focus on building and operating distributed electrical generating plants in the metropolitan Houston area that are fueled by ~~biodiesel~~alternative ~~and renewable diesel~~fuels. In addition, due to the low cost of natural gas ~~the high price of oil~~ in the U.S., the firm is diversifying to develop ~~a gas~~ Gas-to-Liquids ~~liquids~~ production plants.

Texoga Biofuels 2006-I (“TBF-I”), a Texas limited partnership, was syndicated by Texoga in April 2006 and raised $3.5 million from the private sale of 3,500 units of limited partnership interest to 36 accredited investors. After paying selling commissions of 10% to M1 Energy Capital Securities LLC, the net capital of TBF-I was $3,150,000. TBF-I provided the principal financing for a biodiesel fueled electric power generating facility in Oak Ridge North, Texas. In December 2006, Texoga assigned its general partner interest in TBF-I to us with the written consent of a 2/3 majority of the limited partners. While we assumed all of Texoga’s rights and obligations as general partner of TBF-I, we did not issue any securities or pay any consideration to Texoga in connection with the assignment. After assuming our role as general partner of TBF-I, we offered to exchange shares of our common stock for TBF-I units. Since December 2006, we have issued 4,417,500 shares of our common stock to purchase 2,245 TBF-I units; purchased 500 TBF-I units for cash; and purchased the remaining 755 TBF-I units for convertible subordinated notes. At the date of this annual report on Form 10-K, we have acquired all 3,500 TBF-I units, dissolved the partnership and assumed direct ownership of the Oak Ridge North facility.

Texoga Biofuels 2006-II (“TBF-II”), a Texas limited partnership, was syndicated by Texoga in August 2006 and raised $3.5 million from the private sale of 3,500 units of limited partnership interest to 45 accredited investors. After paying selling commissions of 10% to M1 Energy Capital Securities LLC, the net capital of TBF-I was $3,150,000. TBF-II provided substantial financing for a biodiesel fueled electric power generating facility in Montgomery County Texas. In December 2006, Texoga assigned its general partner interest in TBF-II to us with the written consent of a 2/3 majority of the limited partners. While we assumed all of Texoga’s rights and obligations as general partner of TBF-II, we did not issue any securities or pay any consideration to Texoga in connection with the assignment. After assuming our role as general partner of TBF-II, we offered to exchange shares of our common stock for TBF-II units. Since December 2006, we have issued 4,318,326 shares of our common stock to purchase 3,050 TBF-II units. On the date of this annual report on Form 10-K, we own a 10% general partner interest in TBF-II, together with 87.1% of the limited partner interests.

The exchange of TBF-II units for shares of our common stock has not changed the structure of TBF-II or adversely impacted the rights of its limited partners. However, as the beneficial owner of 87.1% of the limited partner interests, we have voting control over the partnership and are entitled to receive the same distributions the original limited partners would have received. Under the applicable agreements, the holders of the TBF-II units that we do not own are entitled to receive 12.9% of any federal tax credits generated by our turbine power facility until they receive cumulative distributions of $900,000. Thereafter, they will be entitled to receive 1.9% of any federal tax credits generated by our turbine power facility until we exercise the buy-out rights specified in the partnership agreement. Our consolidated financial statements reflect the rights of the TBF-II limited partners as a minority interest. In light of our current ownership of 87.1% of the limited partnership interests, we do not expect the minority interests to have a material impact on our future net income.

Unless we tell you otherwise, references to “our company,” “we,” “us,” and “our” refer collectively to our company, the partnership that we manage as general partner and our recently formed ~~subsidiary~~subsidiaries Alternative Energy Consultants, Inc. and Independence Synfuel, LLC. Our executive office is located at 20202 Hwy 59 N, Suite 210, Humble, Texas 77338. Our telephone number is 281-364-7590.

Introduction: ~~The~~We ~~delivery~~are utilizing our prior experience in the use of ~~useful~~alternative ~~energy~~fuels in small-scale distributed electrical power generating plants to ~~industrial,~~develop ~~commercial~~Gas-to-Liquids (“GTL”) field units that can take cheaper stranded natural gas reserves and ~~residential~~produce ~~buildings~~higher invalued liquid petroleum products. We began producing electricity and selling power into the ~~United~~ERCOT ~~States~~grid ~~has~~in ~~evolved~~2007 ~~over~~and ~~many~~then ~~decades~~we began selling power into the Entergy grid in the first quarter of 2008. Both of these projects utilized 100% renewable fuels to produce electricity during a ~~complex system:~~period when power prices were high. By 2010, a glut in natural gas supplies reduced the power prices by over two-thirds. We discontinued power sales at this time and shifted to our current focus on GTL projects which could take advantage of low natural gas prices versus higher relative oil prices.

· Electricity for lighting, refrigeration, communications and electrical equipment comes from centralized power plants that serve users; and · On-site heating systems that typically use oil or natural gas to fuel boilers and furnaces generally provide space heating, hot water and industrial process heat.5

~~This~~Table ~~dual-pronged energy delivery system has persisted despite a general recognition that the cogeneration~~ of electricity and heat, a practice known as “combined heat and power,” or “CHP,” can be significantly more energy efficient. With the exception of large-scale industrial applications like oil refining and petrochemical and paper manufacturing, CHP has not attained general acceptance. Even with technical improvements, the electric power industry discharges roughly twice the energy in the form of heat than it delivers to users in the form of electricity. While on-site heating systems usually have better thermal efficiency than centralized power plants, they too suffer from significant heat loss. These inefficiencies in centralized power plants and on-site heating systems are a major contributor to rising atmospheric CO2 levels. We believe political and economic pressures may favor the use of alternative energy technologies.Contents

WeAs ~~are~~part ~~pioneering~~of the ~~use~~redirection of ~~biodiesel~~our ~~and~~business ~~renewable~~we ~~diesel~~signed toa ~~fuel~~letter ~~small-scale~~of ~~distributed~~intent ~~electrical~~in ~~power~~2012 ~~generating~~with ~~plants~~RMBI ~~that~~International ~~include~~(now ~~ancillary~~“Liberty ~~heating~~GTL”) ~~and~~to ~~cooling~~perform ~~facilities~~an ~~and~~engineering ~~are~~study ~~located~~with inThyssenKrupp ~~close~~Industrial ~~proximity~~Solutions (“Krupp”) related to the ~~end~~construction of a small scale, modular gas-~~users~~to-liquids ~~they~~(“GTL”) ~~serve.~~facility Welocated ~~use~~at the ~~term~~company’s ~~“Integrated~~Houston Clean Energy ~~Systems,”~~Park or (“~~IES,~~HCEP”). Krupp towas ~~describe~~chosen ~~these~~because ~~facilities.~~of Wetheir ~~believe~~experience ~~Integrated~~in ~~Energy~~the ~~Systems~~gas-to-liquids ~~can~~industry ~~reduce~~when ~~demand~~the onGerman ~~the~~government ~~nation's~~produced ~~utility~~over ~~grid,~~one ~~increase~~billion ~~energy~~barrels ~~efficiency,~~of ~~reduce~~synthetic ~~air~~crude ~~pollution~~oil ~~and~~during ~~greenhouse~~the ~~gas~~last ~~emissions,~~eighty ~~protect~~years. The ~~against~~technology ~~power~~under ~~outages,~~consideration ~~and,~~for inthe ~~many~~engineering ~~cases,~~study ~~significantly~~is ~~reduce~~not ~~total~~new ~~energy~~or ~~costs~~untested ~~for~~but ~~end-users~~rather links conventional equipment in a unique way.

WeThe ~~began~~Front-End ~~producing~~Engineering ~~electricity~~Design ~~and~~(“FEED”) ~~selling~~study ~~power~~has ~~into~~been ~~the~~completed ~~ERCOT~~at ~~grid~~a incost ~~2007.~~of Weover ~~began~~$3 ~~producing~~million ~~electricity~~ and ~~selling~~on ~~power~~July ~~into~~19th ~~the~~2014 ~~Entergy~~we ~~grid~~entered ininto ~~the~~a ~~first~~Joint ~~quarter~~Cooperation ofAgreement ~~2008.~~with ~~Accordingly~~Krupp ~~our~~and ~~revenues~~Liberty GTL to ~~date~~build ~~from~~a ~~power~~small ~~sales~~scale ~~were~~GTL ~~limited.~~demonstration Wefacility ~~are~~at ~~not~~our ~~engaged~~HCEP insite. Krupp ~~the~~agreed ~~business~~to ofprovide ~~manufacturing~~technical ~~biodiesel~~services and wecontribute ~~only~~a ~~refine,~~syngas ~~blend~~refinery ~~and~~(autothermal ~~reprocess~~reformer) ~~biofuels~~from ~~for~~an ~~use~~operating inchemical ~~our~~plant ~~generating~~of ~~facilities~~proven design. Liberty WeGTL ~~believe~~has ~~our refining,~~agreed ~~blending~~to provide intellectual property and ~~reprocessing~~operating ~~equipment~~know ishow ~~sufficient~~regarding ~~for~~crude ~~our~~oil ~~current~~synthesis ~~and~~along ~~anticipated~~with ~~needs~~the relevant catalyst supply. WeThe ~~have~~purpose ~~ceased~~of ~~power~~the ~~sales~~two ~~while~~year weproject ~~move~~is ~~the~~to ~~required~~commercially ~~equipment~~demonstrate converting stranded natural gas resources to ~~the~~synthetic ~~H.O.~~crude ~~Clarke~~oil ~~site. This~~and ~~site~~to ~~may~~test ~~require~~one ~~additional~~or ~~fuel~~more ~~storage~~GTL ~~and~~reactors ~~piping~~that ~~equipment~~would ~~depending~~still onneed ~~future~~to ~~re-development~~be acquired.

InThe ~~addition,~~current ~~the~~low ~~Company~~cost ~~has signed a letter~~ of ~~intent~~natural ~~with~~gas ~~RMBI~~and ~~International~~abundant tosupplies ~~perform~~produced afrom ~~feasibility~~unconventional ~~study~~shale ~~related~~resources toenhances the ~~construction~~opportunity ofto aprofitably ~~small~~convert ~~scale,~~natural ~~modular~~ gas- to~~-liquids~~ ~~(“GTL”)~~higher ~~facility~~value ~~located~~liquid atfuels. ~~the~~The ~~company’s~~focus ~~Houston~~of ~~Clean~~the ~~Energy~~feasibility ~~Park~~study ~~(“GTL~~will ~~Plant”). The~~be ~~technology~~on ~~under~~smaller ~~consideration~~units ~~for~~capable ~~the~~of ~~feasibility~~converting ~~study~~5 is– ~~not~~10 ~~new~~million orcubic ~~untested~~feet ~~but~~per ~~rather~~day ~~links~~of ~~conventional~~natural ~~equipment~~gas ininto aapproximately ~~unique~~500 ~~way. The~~– ~~feasibility~~1,000 ~~study~~bbls isper ~~nearly~~day ~~completed~~of atsyncrude (a ~~cost~~combination of ~~approximately~~petroleum $1components ~~million. A~~including ~~joint~~diesel ~~venture~~grade ~~has~~fuel ~~been~~and ~~formed~~naptha ~~with~~waxes). A plant capacity expansion on the ~~Company~~company’s ~~receiving~~HCEP asite ~~carried~~may ~~25%~~be ~~interest~~initiated inon ~~exchange~~successful completion ~~for~~of the ~~long~~initial ~~term~~GTL ~~use~~Plant. The GTL Plant concept under consideration would also be capable of ~~site~~exporting ~~and~~power ~~certain~~into ~~generation~~the ~~equipment~~Texas ERCOT grid.

~~The~~Future ~~current~~projects ~~low cost~~ of ~~natural~~this ~~gas~~type ~~and~~may ~~abundant~~be ~~supplies~~attractive ~~produced~~to ~~from unconventional shale resources enhances~~ the ~~opportunity~~numerous tooil ~~profitably~~operators ~~convert~~drilling ~~natural~~shale gas towells ~~higher~~that ~~value~~may ~~liquid fuels. The focus of the feasibility study will~~ be onconfronted ~~smaller~~with ~~units~~curtailing ~~capable~~production ofor, ~~converting~~in 5the –extreme ~~10 million cubic feet per day of natural gas into approximately 500 – 1~~case,~~000~~ ~~bbls~~ceasing ~~per~~production ~~day of syncrude (a combination of petroleum components including diesel grade fuel and napthas)~~entirely. These A“stranded ~~plant~~gas ~~capacity~~wells” ~~expansion~~would ~~on the company’s Houston Clean Energy Park may~~ be ~~initiated~~able onto ~~successful completion~~produce ofif the ~~initial~~planned GTL ~~Plant. The~~units ~~GTL~~could ~~Plant~~process ~~concept~~the ~~under~~natural ~~consideration~~gas ~~would~~immediately ~~also~~after becompletion ~~capable~~ of ~~exporting power into~~ the ~~Texas ERCOT grid~~well.

~~Future~~The ~~projects~~Houston ofClean ~~this~~Energy ~~type~~Park ~~may~~is bean ~~attractive~~ideal tolocation for the ~~numerous~~development ~~oil~~of ~~operators~~a ~~drilling~~GTL ~~shale~~facility. ~~gas~~The ~~wells~~site ~~that~~has ~~may~~access beto ~~confronted~~a ~~with~~large ~~curtailing~~intrastate ~~production or~~pipeline, ingrid connection through the ~~extreme~~on-site ~~case,~~substation ~~ceasing~~and ~~production~~easy ~~entirely~~access to the Houston Ship Channel refinery and petrochemical complex. ~~These~~The ~~“stranded~~FEED ~~gas~~study ~~wells”~~is ~~would~~an beimportant ~~released~~step ~~for~~in ~~production~~commercializing if the ~~planned~~technical concept. Future GTL ~~units~~developments like this could ~~process~~fill ~~the~~a ~~natural~~need ~~gas~~in ~~immediately~~the ~~after~~energy ~~completion~~industry offor ~~the~~decades ~~well~~to come.

Business: The ~~Houston~~current ~~Clean~~focus ~~Energy~~of ~~Park~~our business is anthe ~~ideal~~introduction ~~location~~of ~~for~~GTL ~~the~~process ~~development~~units ofto astranded gas~~-to-liquids~~ ~~facility.~~wells ~~The~~located ~~site~~initially ~~has~~in ~~access~~Southern toUnited aStates ~~large~~including ~~intrastate pipeline~~Texas, ~~grid~~Louisiana ~~connection~~and ~~through~~Oklahoma. This ~~the~~area ~~on-site~~is ~~substation~~best ~~and~~for ~~easy~~our ~~access~~business model due to its proximity to the Houston Ship Channel ~~refinery~~with ~~and~~its ~~petrochemical~~numerous ~~complex~~purchasers of petroleum products and chemicals. ~~The~~In ~~feasibility~~addition, ~~study~~Texas is anhome ~~important~~to ~~step~~some inof ~~commercializing~~ the ~~technical~~top ~~concept.~~engineering ~~Future~~firms ~~gas-to-liquids~~and ~~developments~~process ~~like~~equipment ~~this~~fabricators. Finally, ~~could~~these ~~fill~~states ahave ~~need~~thousands inof ~~the~~shale ~~energy~~gas ~~industry~~wells that would be suitable for ~~decades~~the toapplication ~~come~~of GTL technologies.

6The current venture to construct a pilot plant GTL facility could result in both the operation of a GTL plant as well as the sale of these modular plants to others. There are a number of wells drilled for shale gas that are shut in due to lack of a pipeline connection. These wells could produce quicker if modular systems were available to convert the natural gas into salable petroleum products. We would like to build, sell and commission small plants such as these.

~~Biodiesel~~Operations: isOur acurrent ~~diesel~~operations fuel substitute that is made from renewable raw materials such as plant oils and animal fats and has almost the same energy density as petroleum-based diesel. Renewable diesel is a broader class of diesel fuel substitutes that are ~~derived~~conducted ~~from renewable~~at ~~plant~~two ~~and~~sites ~~animal~~near ~~sources~~Houston, ~~including certain byproducts that remain after agricultural products are processed into foods, cosmetics and other products~~Texas. InAll this annual report on Form 10-K, we use the term “off-spec” to describe biodiesel that is made from fats and oils that solidify at cooler temperatures and is not suitable for transportation applications, and renewable diesel that satisfies the technical requirements of ~~various~~our ~~Federal~~facilities ~~and~~are ~~State~~located ~~programs~~within ~~that~~20 ~~encourage~~miles ~~the production and use~~ of ~~renewable~~downtown ~~fuels~~Houston.

The process that transforms raw plant oils and animal fats into biodiesel is called transesterification. The reaction is accomplished through a relatively simple process of mixing lye and methanol with raw plant oil or animal fat; separating the resulting biodiesel and glycerin using conventional gravity separation; and removing any free methanol and water by passing the finished biodiesel through a high-temperature evaporator.Since the carbon dioxide released when biodiesel is burned was removed from the air during production of the feedstock, biodiesel is a “carbon neutral” fuel that does not contribute to the accumulation of atmospheric CO2. Biodiesel also emits fewer ancillary pollutants such as unburned hydrocarbons, sulfates, carbon monoxide and soot(other than fossil fuels). Biodiesel is the only alternative fuel that complies with the health effects testing requirements of the 1990 Clean Air Act Amendments. It is also is the only alternative fuel that runs in any conventional, unmodified diesel engine. Other benefits of biodiesel include:

· Reduced fire risk because the flash point of biodiesel is higher than petroleum-based diesel; · Reduced environmental risk because biodiesel is non-toxic and biodegradable; · Reduced reliance on limited natural resources like coal, oil and natural gas; · Reduced competition for uncertain imported energy supplies; and · Significant long-term benefits for agriculture and the domestic economy.

Biodiesel can be stored anywhere that petroleum-based diesel fuel is stored. It is safer to handle and transport because biodiesel is biodegradable and has a higher flashpoint (260°F) than petroleum-based diesel (130°F). Biodiesel can also extend the life of diesel engines because it is more lubricating than petroleum-based diesel fuel, while fuel consumption, power output, and engine torque are relatively unaffected.

Business: The initial focus of our business is on an eight-county region surrounding Houston, Texas that is generally referred to as the Houston-Galveston-Brazoria Eight Hour Ozone Non-Attainment Area (the “HGB”). The HGB has chronic air quality problems because of the density of petrochemical plants and other heavy industry. As a result, the Texas Commission on Environmental Quality (the “TCEQ”) has adopted a variety of source control regulations and strategies to combat air pollution and improve air quality within the HGB.

We believe the use of biodiesel and renewable diesel in IES facilities can increase air quality in the HGB and provide needed additional generating capacity without adversely impacting the petrochemical and other industries that are the economic lifeblood of the region.

We are also working on other clean technologies to enhance the value of our site. The current venture to study the feasibility of adding a GTL facility could result in both the operation of a gas-to-liquids plant as well as the sale of these modular plants to others. There are a number of wells drilled for shale gas that are shut in due to lack of a pipeline connection. These wells could produce quicker if modular systems were available to convert the natural gas into salable petroleum products. We would like to build, sell and commission small plants such as these.

Operations: Our current operations are conducted at two sites in the HGB surrounding Houston, Texas. All of our facilities are located within 35 miles of downtown Houston.

At the date of this annual report on Form 10-K, we have:

· ~~Leased~~Purchased a ~~1/2-acre~~79 industrial site; built a 3,000 square foot building and control room; and installed a biodiesel fueled generating plant that operated until late 2008. This project was decommissioned in early 2009, equipment to be used at the H.O. Clarke site has been moved and equipment that will not be used has been sold. This lease has been terminated effective June 2011. · Leased a 1.5 acre industrial site in(now ~~an unincorporated area of Conroe, Texas; built a 2,200 square foot building and control room; and installed a GE Frame 5 Turbine generator with a rated capacity of just under 10 MW~~54.3 This project was decommissioned in early 2009 and equipment was moved to the H.O. Clarke site. Certain improvements and fixtures were abandoned and these amounts have been written off from our asset list. The lease has been terminated effective May 1, 2009. · Leased a 5 acre industrial site in an unincorporated area adjacent to Humble Texas that may use a power system to generate exhaust used to recharge a depleted oil reservoir. This type of project is called Carbon Capture Sequestration (CCSacres) and could potentially qualify as a US Dept. of Energy pilot project funding as a research project. A grant application for this project did not achieve funding so this project is on hold. Purchased a 79 acre industrial site in Houston, Texas which was the location of the decommissioned H. O. Clarke Power Plant formerly owned by Houston Light and Power. The decommissioned generating plant generated up to 288 MW from gas fired steam turbines from the 1940’s to the late 1990’s when the industry was deregulated. At that time, Texas Genco acquired the generation assets and Centerpoint Energy acquired the transmission and distribution assets including the 12 kV and 138 kV substations adjacent to the site. Texas Genco installed six GE Frame 5 gas-fired combustion turbines providing over 80 MW as peaker units into the Centerpoint distribution 12 kV system. These combustion turbines were decommissioned in 2004 but the interconnection assets remain intact and the substation is still used continuously. We relocated our remaining power generation equipment to this site but we have redirected our focus to our GTL project. We plan to build a pilot scale GTL project that can be used to demonstrate the ~~Company’s~~technology GEoutlined ~~Frame~~in 5the ~~turbine~~recently ~~from~~completed FEED study. Following the ~~Conroe~~successful demonstration of the pilot plant, we plan to develop well site ~~may~~GTL ~~install~~plants itto atbe ~~this~~used ~~location~~on the numerous stranded gas wells in Texas and surrounding states. Significant additional funds are required to ~~generate~~implement ~~peaking~~these ~~power~~plans and there is no assurance that we will be successful in raising the necessary capital to proceed.

In addition, the Company announced that it plans to help develop the construction of a small scale, modular gas-to-liquids (“GTL”) facility located at the company’s Houston Clean Energy Park (“GTL Plant”). The technology under consideration is not new or untested but rather links conventional equipment in a unique way.6

~~The~~Table ~~current low cost~~ of natural gas and abundant supplies produced from unconventional shale resources enhances the opportunity to profitably convert natural gas to higher value liquid fuels. The focus of the company’s GTL development will be on smaller units capable of converting 5–10 million cubic feet per day of natural gas into feasibility approximately 500–1,000 bbls per day of syncrude. A plant capacity expansion on the company’s Houston Clean Energy Park may be initiated on successful completion of the initial GTL Plant. The GTL Plant concept under consideration would also be capable of exporting power into the Texas ERCOT grid.Contents

~~Future~~The ~~projects~~current low cost of ~~this~~natural ~~type~~gas ~~may~~and beabundant ~~attractive~~supplies toproduced from unconventional shale resources enhances the ~~numerous~~opportunity ~~oil~~to ~~operators~~profitably ~~drilling~~convert ~~shale~~natural gas ~~wells~~to ~~that~~higher ~~may~~value liquid fuels. The focus of the company’s GTL development will be ~~confronted~~on ~~with~~smaller ~~curtailing~~units ~~production~~capable ~~or,~~of inconverting ~~the~~5 ~~extreme~~– ~~case~~10 million cubic feet per day of natural gas into feasibility approximately 500 – 1,000 ~~ceasing~~bbls ~~production~~per ~~entirely~~day of syncrude. ~~These~~ ~~“stranded~~A ~~gas~~plant ~~wells”~~capacity ~~would~~expansion on the company’s Houston Clean Energy Park may be ~~released~~initiated ~~for~~on ~~production~~successful ifcompletion of the ~~planned~~initial GTL ~~units~~Plant. The ~~could~~GTL ~~process~~Plant ~~the~~concept ~~natural~~under ~~gas~~consideration ~~immediately~~would ~~after~~also ~~completion~~be capable of exporting power into the ~~well~~Texas ERCOT grid.

~~The~~Future ~~Houston~~projects ~~Clean~~of ~~Energy~~this ~~Park~~type ismay anbe ~~ideal~~attractive ~~location~~to ~~for~~ the ~~development~~numerous ofoil aoperators ~~gas-to-liquids~~drilling ~~facility.~~shale ~~The~~gas ~~site~~wells ~~has~~that ~~access~~may tobe aconfronted ~~large~~with ~~intrastate~~curtailing ~~pipeline~~production or, ~~grid~~in ~~connection through~~ the ~~on-site~~extreme ~~substation~~case, ~~and~~ceasing ~~easy~~production ~~access~~entirely. These to“stranded ~~the~~gas ~~Houston~~wells” ~~Ship~~would ~~Channel~~be ~~refinery~~restored ~~and~~to ~~petrochemical~~production ~~complex. The~~if ~~feasibility~~the ~~study~~planned isGTL anunits ~~important~~could ~~step~~process ~~in commercializing~~ the ~~technical~~natural ~~concept. Future~~ gas~~-to-liquids~~ ~~developments~~immediately ~~like~~after ~~this~~completion ~~could~~of ~~fill a need in~~ the ~~energy industry for decades to come~~well.

8The Houston Clean Energy Park is an ideal location for the development of a gas-to-liquids facility. The site has access to a large intrastate pipeline, grid connection through the on-site substation and easy access to the Houston Ship Channel refinery and petrochemical complex. The FEED study is an important step in commercializing the technical concept. Future gas-to-liquids developments like this could fill a need in the energy industry for decades to come.

In January 2008, we began operations at our Montgomery County power plant , which was connected to Entergy’s grid. This facility was the first biofuel-fired power plant in the United States to deliver electricity into an inter-connected transmission network. We operated both the Oak Ridge North and Montgomery County facilities as “peaking plants,” which means they were dispatched during periods of peak demand when prices for electricity were higher and idled during low-demand periods when electricity prices were lower. In light of damage to the ERCOT and Entergy transmission networks resulting from Hurricane Ike, high biodiesel and renewable diesel supply costs, lower power prices and ongoing negotiations to acquire the 79 acre industrial site in Houston, we elected to suspend operations at both Oak Ridge North and Montgomery County facilities. Subsequently, we moved equipment from the Montgomergy County facility to the new 79 acre industrial site. For these reasons, we have no revenue from power sales during 2009 and ~~2010~~ we have operated in a cash conservation mode while we attempted to raise expansion capital. There is no assurance that sufficient capital can be raised to continue company operations.

Biodiesel Supply and Production: Biodiesel can be manufactured from almost any plant oil or animal fat. However, the physical characteristics of the resulting fuel depend in large part on the physical characteristics of the original feedstock. Plant oils like soy and cottonseed that remain liquid over a wide temperature range are converted into biodiesel that remains liquid over a wide temperature range and are suitable for making transportation fuels. Animal fats and plant oils that solidify at warmer temperatures produce biodiesel that solidifies at warmer temperatures. As a result, biodiesel made from these types of oils is generally not desirable for use in automobiles, trucks and other transportation applications where the fuel will be exposed to cooler weather conditions.

Biodiesel and renewable diesel are classified as renewable fuels that are eligible for refundable federal credits of $1.00 per gallon for fuels manufactured from new plant oils, fats and other virgin agricultural products and $0.50 per gallon for fuels produced from non-virgin oil and fats. For fuels used in transportation, the credit is claimed as an offset against the federal excise tax for motor fuels. For fuels used in IES and other off-road applications, the credit is paid directly by the federal government. Our business plan depends on the continued availability of tax incentives and other governmental subsidies. If the subsidy regime is modified in a way that significantly curtails the amount of available subsidies, the negative impact on our company could be substantial. Federal subsidies for all biofuels credits expired at the end of 2009 and were extended until the of end of 2011, but there’s no assurance that the Congress will renew them going forward.

Biodiesel requires approximately eight pounds of feedstock for each gallon of finished fuel. It also requires ancillary raw materials (principally methanol and lye). At current feedstock prices, biodiesel can be more expensive than petroleum-based diesel. While various credits and agricultural support payments improve the economics of biodiesel production, it is difficult to profitably produce biodiesel at current feedstock prices.

IES is a stationary activity, meaning that IES facilities are built in a fixed location with the intention of operating from that location for years. In a fixed location, it is a simple matter to use exhaust gases to heat storage tanks and fuel lines. Since we have the ability to heat our fuel systems and fuel costs are the most expensive component of our overall operating costs, we may use biodiesel made from less desirable feedstock supplies like beef tallow, pork tallow, chicken fat and palm oil whenever possible. We believe our ability to use biodiesel made from feedstock sources that are not suitable for transportation fuel will help us to control our fuel costs and maximize our gross margin from power generating activities.

We may purchase off-spec biodiesel and renewable diesel in the open market. Since there are numerous producers of biodiesel that offering off-spec biodiesel into the transportation market and a wide variety of industrial processors of plant oils and animal fats that generate byproduct streams that qualify as renewable diesel, we believe that competition exists among potential suppliers. We do not anticipate difficulties in obtaining adequate fuel supplies in the future. Nevertheless, our experience in the off-spec biodiesel and renewable diesel markets is limited and we have not entered into long-term contracts with any suppliers. Accordingly, we cannot provide any assurance that sufficient quantities of off-spec biodiesel and renewable diesel will be available at attractive prices and in quantities sufficient to serve our future needs.

Electric Power in Texas: The generation, distribution and sale of electricity in Texas is managed by ERCOT, which operates the high voltage transmission and distribution grid and manages the deregulated market for approximately 75% of the State. Unlike other regions in the United States, the ERCOT grid functions as a single regulated system instead of as a network of cooperating utility companies. While the high voltage transmission and distribution of electricity are regulated, the production and retail sale of electricity are deregulated.

Within the ERCOT system, there are numerous power generating companies (“PGCs”) that own facilities for the generation of electricity; certified retail electric providers (“REPs”) that sell electricity to end-users; and registered power marketers (“RPMs”) that act as wholesale intermediaries between the PGCs and REPs. Under Texas law, only RPMs and REPs can purchase electricity from PGCs and sell to retail end-users. REPs are not allowed to own generating facilities, so all retail electricity is purchased in the competitive ERCOT wholesale marketplace. Most electric power in ERCOT is sold under bilateral contracts, but long-term contracts of two years or more are very rare. Much of the electricity generated is sold in very short-term contracts and roughly 5% is sold in a daily “balancing market” based on bids submitted the previous evening. Most wholesale electric prices are indexed in some way to natural gas prices. For all but the periods of very low system load, gas-fired generating units (which constitute 72% of the generating capacity in ERCOT) are the marginal supply of electricity and are dispatched on their relative efficiency of converting natural gas to electricity. As a consequence, ERCOT wholesale prices closely track the price of natural gas in Texas, even for generators not fueled by gas. Municipal utilities, state power authorities and electrical cooperatives are not required to participate in the competitive retail electric market, although some of these do purchase power in the competitive wholesale market.

As a PGC in the ERCOT system, we have the option of selling our electricity:

· under a short-term contract with an end-user; · under a long-term contract with an end-user; · to an RPM or REP for the balancing energy price that is established every 15 minutes; · to an RPM or REP for the day-ahead price that is established on a daily basis;

We can also pre-sell all or part of our electricity in the ERCOT futures market.

Operating Revenues:

By suspending operations at the Conroe and Oak Ridge North sites and relocating equipment to the H. O. Clarke site, we achieved no operating revenue for ~~2011~~2014 and ~~2012~~2013. Should we be successful in ~~restoring~~constructing ~~power~~a ~~generation~~GTL atplant ~~the~~on ~~new~~our site, we hope to derive ~~additional~~ operating revenue ~~and~~in ~~credits~~excess ~~from a variety~~ of ~~sources~~our ~~including:~~expenses.

·	Federal Excise Tax Rebate (FETR) Biodiesel and renewable diesel produced from virgin oils and fats and used as a fuel are entitled to a $1.00 per gallon rebate ($0.50 for non virgin oils and fats) from the Federal Government in the form of an Excise Tax Rebate. IRS Form 720 is a quarterly report that allows registered blenders to request the rebate. Alternative diesel fuel produced from renewable feedstocks (but not classified as biodiesel) entitled to a $0.50 per gallon rebate. As of the date of this filing, these rebates have not been extended by the Federal government. There is no assurance that these rebates will be extended and, if extended, there is no assurance that the extension will continue beyond December 31, 2012. Renewable Identification Numbers (RINs) The use of approved feedstocks such as non-cellulosic portions of food waste (ie.yellow grease) and animal fats can create EPA approved RINs that are purchased by petroleum producers to comply with the new Renewable Fuel Standard (RFS). Under the RFS, petroleum producers are required to have a certain percentage of renewable gallons (traded as RIN gallons) for each volume of petroleum fuel produced. The price of RINs traded depend on the availability of RINs in the marketplace but over the last year RIN values have often exceeded FETR values for qualifying renewable gallons.
	Green Electricity Premium (GEP) Electricity produced from biodiesel is classified as “green” electricity because the carbon dioxide released when biodiesel is burned was removed from the air during production of the feedstock. While we have not done so to date, we believe we may be able to obtain higher prices from end-users that are willing to pay a premium for the goodwill associated with environmentally conscious energy policies.
·	Heating and Air Conditioning Services (HACS) Waste heat produced by our generating plants is currently vented to the atmosphere and lost. Nevertheless, we believe our waste heat has substantial economic value to commercial and industrial concerns that operate in close proximity to our plants and can use it to satisfy their heating and air conditioning requirements. We plan to purchase and install a combination of heat collection and adsorption cooling equipment on each of our generating plants and to sell HACS to customers in the immediate vicinity of our plants. We believe the potential value of our planned HACS may equal or exceed the initial value of our power generation revenue.

There is no assurance that our plans to augment any future revenue from our GTL project will be successful. Even if we realize substantial revenues from these sources and others, there are no assurances that our revenues will ever exceed our operating costs or that we will be able to generate operating profits on a sustained basis. If we are unable to significantly increase our operating revenue or significantly reduce our fuel costs, our business will fail.

· Renewable Energy Credits (REC) RECs have been mandated as part of Texas’ deregulation of the electric utility industry. Generating facilities are granted RECs in direct proportion to the MWh of renewable energy produced from sources such as hydro, wind, solar, biogas and renewable fuels. In turn, all retail electric providers in Texas are required to hold RECs based on the level of their annual retail sales in the state. RECs trade separately from the produced electricity and have an independent value determined by market forces. Since 2003, RECs in Texas generally have traded lower over time as more and more wind assets create a softening of demand and concomitant reduction in REC value. · Emission Reduction Credits (ERC) The HGB Mass Emission Cap & Trade program was adopted in December 2000. The program is managed by the TCEQ and establishes emission caps for the HGB. The emissions covered by the program include NOx; volatile organic compounds; carbon monoxide; SOx; and particulates. Since biodiesel, or biodiesel combined with additives or catalytic converters, can reduce emissions in each of the covered emissions classes and all of our current and planned operations will be conducted within the HGB, we may be able to generate saleable emission reduction credits. · Greenhouse Gas Credits (GGC) Large quantities of CO2, a “greenhouse gas” that is widely believed to be a principal cause of global warming, are produced whenever hydrocarbons are used for fuel. At present, there are no Federal, State or local regulations that restrict the production of CO2 or other greenhouse gases though voluntary programs have emerged in the US. Nevertheless, increased awareness of global warming and other problems associated with greenhouse gas emissions is driving efforts throughout the industrialized world to regulate and restrict future CO2 emissions. If CO2 emission standards are adopted, biodiesel may become a preferred fuel because it is carbon neutral. It is presently impossible to predict whether CO2 reduction initiatives will be adopted in the State of Texas, when such initiatives might be adopted or the potential value of any future carbon reduction credits that may be available to us.

There is no assurance that our plans to augment any future revenue from electricity sales with the incentives described above will be successful. Even if we realize substantial ancillary revenues from these sources and others, there are no assurances that our revenues will ever exceed our operating costs or that we will be able to generate operating profits on a sustained basis. If we are unable to significantly increase our operating revenue or significantly reduce our fuel costs, our business will fail.

Sales and Marketing:

Since we have not ~~sold~~yet ~~green~~built ~~electricity~~a ~~under~~GTL ~~long term contracts~~plant, we cannot specifically identify the principal potential markets or likely customers for ~~green~~these ~~electricity~~projects. However, we believe that ~~green~~GTL ~~electricity~~plants will be attractive to ~~industrial~~natural ~~users~~gas field owners that ~~need~~do not have ready access to ~~reduce~~a ~~their~~pipeline ~~overall~~to ~~air~~allow ~~pollution~~for ~~profile~~the sale of the gas. In addition, ~~environmentally~~there ~~conscious~~are ~~consumers~~numerous oil operators with wells that ~~want~~produce toeconomic ~~make~~amounts of oil with a ~~tangible~~small ~~contribution~~amount toof ~~air~~natural ~~quality,~~gas ~~and~~but ~~retail~~no ~~stores~~pipeline connection. In the past, ~~restaurants~~these ~~and~~wells ~~other~~could ~~commercial~~flare ~~establishments~~the ~~that~~gas ~~want~~to atmosphere to ~~project~~allow anfor ~~environmentally~~the ~~conscious~~production ~~image~~of the oil volumes. The governmental rules have changed to drastically reduce the ~~general~~air ~~public~~emissions associated with flare gas so many of these gas fields to economic production.

~~Newly~~Company ~~formed subsidiary~~subsidiaries: In August 2007, we organized a subsidiary ~~limited liability~~ company named Alternative Energy Consultants, ~~LLC~~Inc. (“AEC”), which will engage in the business of designing and building standardized ~~biodiesel~~GTL ~~refineries~~plants ~~and IES facilities~~ for our company and third parties. Our ultimate goal for AEC is to develop an engineering staff for the design work; a fabrication division to manufacture key components; and a field staff to provide procurement, construction and operating services. ~~AEC’s initial designs are based on modifications to our Oak Ridge North and Montgomery County facilities.~~ As we develop additional experience in the development and construction of new ~~IES~~GTL facilities, those designs will also be made available to third parties through AEC.

~~Competition:~~ In ~~the~~December ~~electric power markets~~2014, we ~~compete~~organized ~~with all major utilities that provide power to the ERCOT grid, and~~ a ~~variety~~subsidiary oflimited ~~small~~liability ~~power~~company ~~producers~~named ~~including~~Independence ~~CHP facilities~~Synfuel, ~~wind~~LLC ~~farms and solar power installations. While we operated our Oak Ridge North and Montgomery County facilities as peak load plants~~(“Independence”), wewhich ~~were not able to secure bilateral contracts for sale of our electricity. Until we are able to sell green electricity under long-term contracts, we~~ will befund ~~forced~~and to operate inour apilot ~~largely~~scale ~~non-competitive~~GTL ~~market~~plant ~~segment~~on ~~consisting~~our ofHCEP ~~small~~site. Our ~~electricity~~goal ~~generators who can either produce electricity and sell it~~ for ~~the~~Independence ~~prevailing~~is ~~price or refrain from producing and selling electricity. If, as and when we are able~~ to ~~market~~develop ~~green~~joint ~~electricity~~venture toopportunities ~~end-users, our principal method of competition will be to emphasize the environmental benefits of our electricity as compared~~ with ~~electricity~~Krupp ~~produced from coal fired plants~~ and ~~other~~Liberty ~~sources~~GTL.

~~Most~~Competition: ofIn ~~our~~the ~~competitors~~oil ~~have greater financial resources~~ and ~~lower~~gas ~~fuel~~process ~~costs~~equipment ~~than~~markets, we ~~do;~~compete ~~are~~with ~~able~~all tomajor ~~produce~~oilfield ~~electricity~~service ~~for~~companies athat ~~lower~~provide ~~cost~~equipment ~~per~~to ~~MWh~~the ~~than~~major ~~we can;~~ and ~~are~~independent ~~better~~oil ~~able~~and togas ~~withstand~~producers. ~~periods~~Until ofwe ~~low~~are ~~electricity~~able ~~prices~~to ~~without~~sell ~~suffering~~GTL ~~negative~~plants ~~cash~~to ~~flows~~others ~~from~~or ~~power~~operate ~~generating~~them ~~activities. In the markets~~ for ~~green~~our ~~and~~own ~~renewable electricity~~account, we will ~~compete~~be ~~primarily~~forced ~~with~~to ~~wind~~operate ~~farms~~in ~~and~~a ~~solar~~largely ~~power~~non-competitive ~~installations,~~market ~~which offer~~segment ~~the~~consisting ~~same~~of ~~renewable~~major ~~and~~oilfield ~~clean~~service ~~power~~companies ~~advantages~~selling ~~that~~to wemajor dooil ~~while incurring significantly lower operating costs~~companies..

Regulatory Compliance: All phases of designing, constructing and operating biodiesel powered facilities for the generation of electricity are subject to environmental regulation by various federal and state government agencies, including, but not limited to, the EPA, the Texas Commission on Environmental Quality (“TCEQ”) and other agencies in each jurisdiction where our existing and proposed facilities are located. Environmental laws and regulations relating to exhaust emissions, air and water quality and the discharge of pollutants in general are extensive and have become progressively more stringent. Since biofuels are non-toxic and biodegradable, and emissions from the combustion of biofuels can be lower than emissions from the combustion of other liquid fuels, we may have lesser costs to ensure compliance with applicable environmental laws and regulations than petroleum-fueled projects. Nevertheless, applicable laws and regulations are subject to change, which could be made retroactively. Violations of environmental laws and regulations or permit conditions can result in substantial penalties, injunctive orders compelling installation of additional controls, civil and criminal sanctions, permit revocations and/or facility shutdowns. If significant unforeseen liabilities arise for corrective action or other compliance, our sales and profitability could be adversely affected.7

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Most of our competitors have greater financial resources than we do; are able to produce equipment cheaper than we can; and are better able to withstand periods of negative cash flows while they introduce new products to the marketplace. In the specific GTL marketplace, there are approximately eight equipment suppliers that have proprietary reactor designs that will require IP agreements or royalty agreements to be negotiated with customers. We have elected to avoid this method of product placement by becoming “first to market” with off the shelf technologies that have been used for decades, are robust and are duplicable for modular field applications.

Regulatory Compliance: All phases of designing, constructing and operating GTL plants are subject to environmental regulation by various federal and state government agencies, including, but not limited to, the EPA, the Texas Commission on Environmental Quality (“TCEQ”) and other agencies in each jurisdiction where our existing and proposed facilities are located. Environmental laws and regulations relating to exhaust emissions, air and water quality and the discharge of pollutants in general are extensive and have become progressively more stringent. Since emissions from GTL processes can be lower than emissions from the combustion of other liquid fuels, we may have lesser costs to ensure compliance with applicable environmental laws and regulations than petroleum-fueled projects. Nevertheless, applicable laws and regulations are subject to change, which could be made retroactively. Violations of environmental laws and regulations or permit conditions can result in substantial penalties, injunctive orders compelling installation of additional controls, civil and criminal sanctions, permit revocations and/or facility shutdowns. If significant unforeseen liabilities arise for corrective action or other compliance, our sales and profitability could be adversely affected.

Our current and planned operations require licenses, permits and in some cases renewals of these licenses and permits from various governmental authorities. Our ability to obtain, amend, comply with, sustain, or renew such licenses and permits on acceptable, commercially viable terms are subject to change, as, among other things, the regulations and policies of applicable governmental authorities may change. Our inability to obtain, amend to conform to our operations, or extend a license or a loss of any of these licenses or permits may have a material adverse effect on our business, financial condition and results of operations.

Failure to comply with government regulations could subject us to civil and criminal penalties, require us to forfeit property rights and may affect the value of our assets or our ability to conduct our business. We may also be required to take corrective actions, including, but not limited to, installing additional equipment, which could require us to make substantial capital expenditures. We could also be required to indemnify our employees in connection with any expenses or liabilities that they may incur individually in connection with regulatory action against them. These could result in a material adverse effect on our business, financial condition and results of operation. To date, our expenditures for regulatory compliance have not been material, but we expect the cost of regulatory compliance to increase as our business develops.

Research and Development, Patents and Intellectual Property: During the last ~~two~~four years, we have no material expenditures for activities that are properly classified as research and development. We do not own any patents and our business plan is not based on intellectual property other than the know-how and experience of our directors, officers and key employees.

Employees: We have four employees at the date of this annual report on Form 10-K including a three-member management and business development team and one administrative employee. We also use part-time independent contractors to perform a variety of specialized services. We are not subject to any collective bargaining agreements. For construction of facilities, the company plans to use outside construction firms and subcontract labor to supplement our workforce.

Exchange Act Registration, Periodic Reporting and Audited Financial Statements

We have registered our common stock under the Securities Exchange Act of 1934 and are required to file annual and quarterly reports, proxy statements and other reports with the SEC. All reports and other filings we make with the SEC will be available on our corporate website at www.biofuelspower.com.

ITEM 1A — RISK FACTORS

Our business involves a high degree of risk. The following risk factors should be considered carefully in addition to the other information contained in this annual report on Form 10-K.

We are an early stage company, our business is evolving and our prospects are difficult to evaluate.

From inception through mid-2006, we engaged in an unsuccessful effort to negotiate military procurement contracts for an explosion preventing aluminum mesh fuel tank filler. In December 2006, we changed our name to Biofuels Power Corporation, raised approximately $1.5 million in new capital and assumed operational and legal responsibility for two partnerships that were organized by Texoga during 2006. ~~This~~In ~~change~~2011, inwe ~~focus~~expanded ~~required~~our usfocus to ~~establish~~include ~~purchasing and power distribution capabilities that we did not need in earlier periods. It has also significantly increased~~ the ~~amount~~development of ~~capital~~GTL ~~required for fuel inventories and increased our exposure to upstream commodity price and downstream power price fluctuations~~technologies. ~~We have no material operating history that you can rely on in connection with an investment decision.~~ Our prospects must be carefully considered in light of our history, our high capital costs, our exposure to commodity ~~and power~~ price fluctuations and the other risks, uncertainties and difficulties that are typically encountered by companies that are implementing novel business models. Some of the principal risks and difficulties we expect to encounter include our ability to:

· Raise substantial capital to finance our planned expansion, together with the losses we expect to incur as we begin a period of rapid growth; · Install our planned HACS facilities and design and build new IES facilities while maintaining effective control over the cost of new facilities; · Reduce the risk of commodity price swings and optimize the value of the GEP and HACS we produce through price hedging, forward contracts and similar activities; · Develop, implement and maintain financial and management control systems and processes to control the cost of our power generating activities;8

13Table of Contents

· ~~Develop,~~Raise ~~implement~~substantial ~~and~~capital ~~maintain systems~~ to ~~ensure~~finance ~~compliance~~our ~~with~~planned ~~a variety of governmental and quasi-governmental rules~~expansion, ~~regulations~~together ~~and~~with ~~policies;~~the ·losses ~~Adapt~~we ~~and~~expect ~~successfully execute our rapidly evolving and inherently unpredictable business plan and respond~~ to ~~competitive~~incur ~~developments~~as ~~and~~we ~~changing~~begin ~~market~~a ~~conditions;~~period ~~· Attract, retain and motivate qualified personnel; and · Manage each~~ of ~~the~~rapid ~~other risks identified in this annual report on Form 10-K.~~growth;

·	Install our planned GTL pilot plant and design and build new GTL facilities while maintaining effective control over the cost of new facilities;

·	Reduce the risk of commodity price swings and optimize the value of the GTL project we produce through price hedging, forward contracts and similar activities;

·	Develop, implement and maintain financial and management control systems and processes to control the cost of our GTL activities;

·	Develop, implement and maintain systems to ensure compliance with a variety of governmental and quasi-governmental rules, regulations and policies;

·	Adapt and successfully execute our rapidly evolving and inherently unpredictable business plan and respond to competitive developments and changing market conditions;

·	Attract, retain and motivate qualified personnel; and

·	Manage each of the other risks identified in this annual report on Form 10-K.

Because of our lack of operating history and our early stage of development, we have limited insight into trends and conditions that may exist or might emerge and affect our business. There is no assurance that our business strategy will be successful or that we can or will successfully address these risks.

The auditors report on our financial statements includes a going concern qualification.

For the years ended December 31, ~~2012~~2014 and ~~2011~~2013, we incurred net ~~income~~gains (losses) of ~~$304,922 and~~ ($1,~~322~~089,~~797~~109) ~~respectively.~~and( ~~The net income for the year ended December 31, 2012 was after an extra-ordinary item of recognizing~~ $1606,~~650,919~~556) ~~from restating account payable at December 31, 2012~~respectively. At December 31, ~~2012~~2014, we had approximately ($56,~~264~~536,~~131~~845) in working capital and our accumulated deficit was ($1618,~~710~~405,~~298~~963). Therefore, the independent auditors’ report on our financial statements for the year ended December 31, ~~2012~~2014 contains a fourth explanatory paragraph that our financial statements have been prepared assuming that our company will continue as a going concern and that our history of operating losses and negative cash flow raise substantial doubt about that assumption.

We have significant weaknesses in our system of internal controls that could subject us to regulatory scrutiny or impair investor confidence, which could adversely affect our business and our stock price.

Section 404 of the Sarbanes-Oxley Act of 2002 requires companies to do a comprehensive evaluation of their internal controls. At present, our system of internal controls does not satisfy all applicable regulatory requirements. Future efforts to bring our system of internal controls into compliance with Section 404 and related regulations will likely require the commitment of significant financial and managerial resources. If we fail in that effort, we could be subject to regulatory scrutiny or suffer a loss of investor confidence, which could adversely affect our business and our stock price.

We have engaged in significant related party transactions with former affiliates that may give rise to conflicts of interest, result in significant losses to our company or otherwise impair investor confidence, which could adversely affect our business and our stock price.

We have engaged in significant related party transactions with Texoga, a former affiliate of our company. The principal related party transactions during 2008 include participation under a rent sharing arrangement for the office space that both companies use as their principal executive office. While we are not controlled by or under common control with Texoga, the commonality of ownership between both companies is declining; and all related party transactions must be approved by the disinterested members of our board of directors; related party transactions in general have a higher potential for conflicts of interest than third-party transactions, could result in significant losses to our company and may impair investor confidence, which could adversely effect our business and our stock price.

All our officers are part-time employees who are engaged in other activities and will face conflicts of interest in allocating their time among their various interests.

Our CFO, Sam H. Lindsey, Jr. and our director ~~Richard~~Steve ~~DeGarmo~~McGuire are both actively engaged in other business activities. While our officers or directors aren't engaged in activities that are competitive with our business, they will both face conflicts of interest in allocating their time among their various interests. To the extent that material conflicts of interest arise, those conflicts may have a material adverse impact on our business or stock price. We plan to hire a full-time CEO and a full time CFO, but can offer no assurance respecting the availability of suitably experienced executive officers, the amount of time required to complete our planned executive search, or the terms of any future employment agreement a newly hired executive officer will require.

149

~~Over~~Table ~~the~~of ~~long-term, we must obtain a premium price for our green electricity or our business will fail.~~Contents

~~If our net fuel costs after available tax rebates exceed our revenue from electricity sales we will lose money.~~ Over the long -term, we ~~will~~must ~~not be able to profitably use biodiesel as fuel to generate power unless we are able to~~ obtain a premium price for “green electricity.” We believe a variety of industrial, commercial and individual end-users will be willing to pay a significant premium for a reliable source of green electricity, but we have no end-user contracts at the date of this annual report on Form 10-K and will not be able to negotiate such contracts until we establish our ~~reliability~~GTL asplants ~~a power producer. There is no assurance that our plans to augment any future revenue from electricity sales with ancillary revenue from GEPs, HACS, RECs, ERCs~~ and ~~GGCs~~product ~~will~~prices ~~be successful. Even if we realize substantial ancillary revenues from these sources and others, there are no assurances that our future revenues will ever exceed our operating costs~~ or ~~that we will be able to generate operating profits on a sustained basis. If we are unable to significantly generate operating revenue or significantly reduce~~ our ~~fuel costs, our~~ business will fail.

Since our business will rely on the sale and/or operation of GTL plants we must be able to sell enough plants with a high enough sales commission to generate sufficient revenue to maintain profitability. In operating our own GTL plant, we must receive a low enough feedstock natural gas price combined with a high enough liquid fuel sales price to remain profitable. Even if we realize substantial revenues from these sources and others, there are no assurances that our future revenues will ever exceed our operating costs or that we will be able to generate operating profits on a sustained basis. If we are unable to significantly generate operating revenue or significantly reduce our fuel costs, our business will fail.

Our growth strategy may not be executed as planned which could adversely impact our financial condition and results of operations.

There can be no assurance that our rapidly evolving and inherently unpredictable growth strategy will be successful. For example, there can be no assurance that ~~“green electricity” generated from alternative fuels will command a meaningful premium in~~ the ~~marketplace.~~current ~~Likewise,~~spread ~~there can~~between benatural nogas ~~assurances~~prices ~~that~~and ~~potential~~crude ~~HACS~~prices ~~customers~~ will beremain ~~willing to pay a reasonable price for HACS services. Similarly, there can be no guarantee that our investment~~ in ~~biodiesel~~the ~~fueled IES facilities will not be adversely impacted as a result of unanticipated changes in available technologies, fossil fuel prices or environmental regulatory policies~~marketplace. Execution of our growth strategy, if achieved, may take longer than expected or cost more than expected. Our growth strategy is dependent upon many variables, including, but not limited to, market, ~~legislative~~factors and ~~regulatory~~technology ~~dynamics~~risks. Any change to any of these dynamics could affect the execution our growth strategy, including causing management to change its strategy.

The sale, operation and maintenance of ~~IES~~GTL facilities involves significant risks that could adversely affect our results of operations and financial condition.

The operation and maintenance of ~~IES~~GTL facilities involves many risks, including start-up risks, breakdown or failure of facilities, lack of sufficient capital to maintain the facilities, the dependence on a specific fuel source or the impact of unusual or adverse weather conditions or other natural events, as well as the risk of performance below expected levels of output, efficiency or reliability, the occurrence of any of which could result in lost revenues and/or increased expenses. ~~Our original facilities in Oak Ridge North and Montgomery County were built with used equipment.~~ Even if our equipment is maintained in accordance with good engineering practices, it may require significant expenditures to maintain adequate levels of efficiency and reliability. ~~The risk of increased maintenance and capital expenditures is exacerbated by our current practice of running only during peak demand periods to maximize our revenues.~~ Our ability to successfully and timely complete capital improvements to existing facilities or other capital projects is contingent upon many variables and subject to substantial risks. Should any such efforts be unsuccessful, our company could be subject to additional costs and/or the write-off of its investment in the project or improvement.

We expect to incur substantial losses in the future as we expand our operations, build new facilities and develop new markets for our ~~green~~GTL ~~electricity~~plants.

We ~~commenced~~expect generating activities at our 5 MW facility in Oak Ridge North, Texas in February 2007 and commenced generating activities at our 10 MW Montgomery County facility in January 2008. We have incurred substantial losses as we suspended these operations and moved equipment to agenerate ~~new~~recurring ~~site. When and if we restore power operations, we believe our~~ losses ~~will~~until ~~be highest during winter months of the year when electricity prices are at their lowest. Even during the summer months, however,~~ we docan ~~not~~establish ~~expect~~ our ~~operations~~reliability toas ~~be profitable unless we are able to negotiate~~ a ~~substantial~~GTL ~~power~~operator ~~contract~~and orequipment ~~develop substantial ancillary revenue from other sources~~supplier. Moreover:

15· we will incur substantial additional costs for procurement, marketing and administrative overhead as we retain new management and hire suitable operating personnel;

~~Accordingly,~~· we ~~expect~~will toincur ~~generate~~substantial ~~recurring~~additional ~~losses~~depreciation ~~until~~and weamortization ~~can~~costs ~~establish~~associated ~~our~~with ~~reliability~~new asfacilities ~~a power producer~~ and ~~negotiate~~those ~~end-user~~costs ~~contracts~~may ~~that~~be ~~provide~~significantly ~~premium~~greater ~~prices~~than ~~for~~anticipated; ~~green electricity. Moreover:~~and

· weour ~~will~~activities ~~incur substantial additional costs for procurement, marketing and administrative overhead~~ as wean ~~retain~~active ~~new~~GTL ~~management~~operator and ~~hire~~equipment ~~suitable~~supplier ~~operating personnel; · we~~ will incur substantial additional depreciation and amortization costs associated with new facilities and those costs may be significantly greater than the per unit costs we have incurred to date; and · our activities as an active power producer will expose our company to commodity price risks on both the ~~fuel~~natural gas we use and the ~~electricity~~liquids we ~~generate~~produce.

In combination, the foregoing costs and expenses will likely give rise to substantial near-term operating losses and may prevent our company from achieving profitability for an extended period of time. We expect to rely on equity financing to fund our operating losses and other cash requirements until we are able to negotiate a power contracts and develop ancillary sources of revenue. If our net losses continue, we will experience negative cash flow, which will hamper current operations and prevent our company from expanding. We may be unable to attain, sustain or increase profitability on a quarterly or annual basis in the future, which could require us to scale back or terminate our operations.

The market prices for our natural gas feedstock are highly volatile ~~and subject to increasing pressure from alternative fuel producers~~, which may cause our results of operations to fluctuate.

The principal raw materials used in ~~biofuels~~GTL plants are commodities that are subject to substantial price variations due to factors beyond our control. Commodity prices are determined from minute to minute based on supply and demand and can be highly volatile. ~~As more producers enter the biofuels business, competition for available feedstock supplies is expected to increase.~~ There can be no assurances that any hedging activities will effectively insulate us from future commodity price volatility or that the value of the feedstock we use will not exceed the value of the ~~electricity~~product we generate. ~~In the event that we are unable to pass increases in the price of raw materials to our customers, our operating results will suffer.~~ We cannot predict the future price of our ~~biofuels~~ feedstock and any material price increases will adversely affect our future operating performance.

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Our activities cannot be fully hedged against changes in commodity prices and our hedging procedures may not work as planned or hedge counterparties may default on their obligations to us.

We cannot fully hedge the risk associated with changes in feedstock ~~and electricity~~ prices. To the extent that we have un-hedged positions, fluctuating commodity ~~and power~~ prices can materially impact our results of operations and financial position. To manage our financial exposure to commodity and energy price fluctuations, we will routinely enter into contracts to hedge portions of our feedstock requirements and may enter into contracts to hedge portions of our ~~generating~~production capacity. As part of this strategy, we may enter into fixed-price forward purchase and sales contracts, futures, financial swaps and option contracts traded ~~in the over-the-counter markets or~~ on exchanges. Although we intend to devote a considerable amount of management time and effort to the establishment of risk management procedures as well as the ongoing review of the implementation of these procedures, the procedures in place may not always be followed or may not always function as planned and we cannot eliminate all the risks associated with these activities. As a result of these and other factors, we cannot precisely predict the impact that risk management decisions may have on our business, results of operations or financial position.

To the extent that we engage in hedging and risk management activities, our company will be exposed to the risk that counterparties that owe us money or commodities as a result of market transactions will not perform their obligations. Should the counterparties to these arrangements fail to perform, we might be forced to make alternative hedging arrangements or honor the underlying commitment at then-current market prices. In such event, we might incur losses in addition to amounts, if any, already paid to the counterparties. ERCOT market participants are also exposed to risks that another ERCOT market participant may default in its obligations to pay ERCOT for power taken, in which case such costs, to the extent not offset by posted security and other protections available to ERCOT, may be allocated to various non-defaulting ERCOT market participants, including our company.

In connection with our possible hedging and risk management activities, we may be required to guarantee or indemnify our performance relating to such activities. We might not be able to satisfy all of these guarantees and indemnification obligations if they were to come due at the same time. In addition, reductions in credit quality or changes in the market prices could increase the cash collateral required to be posted in connection with hedging and risk management activities, which could materially impact our liquidity and financial position.

WeIntroducing ~~are~~GTL ~~dependent~~technologies onto ~~tax~~the ~~incentives~~market is time consuming and ~~other~~expensive ~~governmental~~and ~~subsidies~~may not ultimately result in an operating profit.

~~Our~~To ~~business~~achieve ~~plan~~profitable ~~depends~~operations, onwe ~~the~~must ~~continued~~convince ~~availability~~potential ofcustomers ~~tax~~that ~~incentives~~petroleum ~~and~~liquids ~~other~~produced ~~governmental~~from ~~subsidies.~~natural Ifgas ~~the~~is ~~Federal~~worth ~~and/or~~a ~~State~~significant ~~government~~cost ~~decide~~for tocapital ~~modify~~equipment. ~~the~~The ~~subsidy~~cost ~~regime~~associated inwith aGTL ~~way~~technology ~~that~~development ~~significantly~~can ~~curtails~~be ~~the~~very ~~amount~~high ofand ~~available~~new ~~subsidies,~~product ~~the~~lines ~~impact~~often ongenerate ~~our company could be~~ substantial. ~~While~~losses wefor ~~believe~~an ~~the~~extended ~~prior~~period ~~tax~~of ~~incentives~~time ~~and~~before ~~other~~making ~~governmental~~a ~~subsidies~~meaningful ~~will~~contribution beto ~~extended;~~long asterm ~~of this date they have expired~~profitability. There is ~~also~~ no assurance that ~~future~~our ~~incentives~~GTL plants will becommand ~~comparable~~a ~~with~~premium ~~current~~price ~~incentives.~~in ~~Even with~~ the ~~extension~~market ofor ~~current incentives, there can be no assurance~~ that our ~~business~~marketing activities will be successful or profitable. ~~The~~Even ~~repeal~~if orwe aare ~~material~~ultimately ~~reduction~~successful, ofdelays, ~~the~~additional ~~tax~~expenses ~~incentives~~ and other ~~subsidies~~factors ~~would~~may ~~materially~~significantly ~~impact~~impair our ~~revenue~~potential profitability and ~~could~~there ~~force~~is usno toassurance ~~suspend~~that orour ~~terminate~~company ~~operations~~will ever generate an operating profit. .

~~The~~We ~~repeal~~may orbe ~~modification~~unable ofto ~~environmental~~obtain ~~laws~~commercially ~~favoring~~reasonable ~~the~~terms ~~use~~on ofconstruction ~~biodiesel~~contracts for ~~power generation could reduce the demand for~~ our ~~green~~planned ~~electricity~~GTL ~~and cause our sales and profitability to decline~~facilities.

InWe ~~areas~~served ~~like~~as ~~the~~our ~~HGB~~own ~~that~~contractor ~~suffer from persistent air quality problems, the use of biofuels as fuel~~ for ~~electric~~our ~~generators~~Oak ~~can~~Ridge ~~permit~~North ~~users~~and toMontgomery ~~reduce~~County ~~their~~facilities ~~regulated~~and ~~emissions~~performed ~~without~~all ~~requiring~~necessary ~~exotic~~engineering, ~~pollution~~procurement ~~control equipment~~ and ~~other~~construction ~~expensive~~work ~~modifications~~in-house toor ~~existing~~using ~~facilities~~third-party consultants. ~~Most~~We ~~industrial~~have ~~users~~recently ofcreated ~~electricity require~~ a ~~reliable~~wholly-owned ~~supply~~subsidiary atnamed aAlternative ~~predictable~~Energy ~~cost~~Consultants, ~~and~~Inc. ~~are~~(“AEC”) ~~unwilling~~ to ~~accept~~manage ~~the~~our ~~inherent~~engineering, ~~risk~~procurement ofand ~~supply-chain~~construction ~~disruptions~~work ~~that~~and ~~accompany~~perform acomparable ~~new~~services ~~fuel~~for ~~like~~third ~~biofuels~~parties. orWe ~~new~~presently ~~production~~own ~~facilities~~100% ~~like~~of ~~ours. Therefore~~AEC, wealthough ~~believe~~our wepercentage ~~will~~interest beis ~~unable~~expected to ~~earn~~decline aas ~~significant~~it ~~market~~hires ~~position~~additional instaff ~~the~~and ~~industrial~~expands ~~power~~its ~~market~~operations. ~~until~~We weplan ~~can conclusively demonstrate our ability~~ to ~~reliably~~rely ~~produce~~on ~~and~~AEC ~~deliver~~in ~~green~~connection ~~electricity~~with planned infuture ~~the~~expansion ~~volumes~~of ~~required~~our bygenerating ~~industrial users~~capacity. ~~Since~~If we ~~believe~~are ~~the~~not ~~combination~~able ofto ~~tax~~obtain ~~incentives~~commercially ~~and~~reasonable ~~environmental~~terms ~~regulations~~from ~~make~~AEC ~~biofuels-fueled~~for ~~electricity~~any ~~particularly~~future ~~attractive~~acquisition toand ~~industrial~~construction ~~users~~projects, weour ~~believe~~operations ~~the repeal or substantial amendment of federal~~ and ~~state~~planned ~~air~~growth ~~quality regulations~~ could ~~have~~be ~~a detrimental effect on our business and~~ adversely ~~affect our operating performance~~affected.

We ~~will~~may ~~not~~need ~~be able~~ to ~~offer~~increase ~~direct~~cost ~~performance~~estimates orfor ~~price~~the ~~advantages~~acquisition toor ~~end-users~~construction ~~and~~of ~~our~~future ~~marketing~~GTL ~~efforts will be based primarily on environmental benefits~~facilities.

~~Electricity~~The iscost aof ~~fungible~~engineering, ~~commodity~~procurement and ~~green~~construction ~~electricity~~for ~~has~~new noGTL ~~performance~~facilities ~~advantages~~could ~~over~~increase ~~electricity~~significantly ~~generated~~and ~~from~~there ~~nuclear,~~is ~~coal~~no orassurance ~~gas-fired~~that ~~plants.~~the ~~Therefore,~~final ~~our~~cost ~~only~~of ~~competitive~~any ~~advantages~~GTL ~~are~~facilities ~~indirect~~we ~~benefits~~establish ~~from~~in ~~reduced~~the ~~emissions.~~future ~~While~~will ~~emission~~not ~~reduction~~be ~~benefits~~materially ~~can~~higher ~~have~~than ~~substantial~~anticipated. ~~value~~There tomay ~~end-users~~be ~~who~~design ~~are~~changes, ~~subject~~material tocost ~~regulatory~~escalations ~~compulsion~~or tobudgetary ~~reduce~~overruns ~~their~~associated ~~air~~with ~~quality~~the ~~footprint,~~construction ~~that~~of ~~value~~future ~~can be difficult to quantify~~plants. IfAny wesignificant ~~are~~increase ~~unable~~in tothe ~~identify~~estimated ~~environmentally~~construction ~~conscious~~cost ~~end-users~~of ~~who believe that~~ the ~~benefits~~plants ofcould ~~green~~delay ~~electricity~~our ~~outweigh~~ability ~~the~~to ~~premium~~generate ~~price~~revenues ~~that~~or wereduce ~~must~~the ~~obtain,~~amount ~~our~~of ~~business~~revenues ~~will not be successful~~realized.

~~Introducing green electricity to the market is time consuming and expensive and may not ultimately result in an operating profit.~~11

ToTable ~~achieve profitable operations, we must convince potential customers that green electricity generated from renewable fuels is worth a premium price. The cost associated with the introduction~~ of green products can be very high and new product lines often generate substantial losses for an extended period of time before making a meaningful contribution to administrative overhead. There is no assurance that our green electricity will command a premium price in the market or that our marketing activities will be successful or profitable. Even if we are ultimately successful, delays, additional expenses and other factors may significantly impair our potential profitability and there is no assurance that our company will ever generate an operating profit.Contents

17Various risks associated with the construction of our planned GTL facilities may adversely affect our sales and profitability.

~~Violations~~We may experience delays in the construction of ~~environmental~~our ~~regulations~~planned GTL facilities that we decide to build or operate in the future. We may also encounter defects in materials and/or workmanship in connection with such projects. Any defects could ~~subject~~delay ~~our~~the ~~company~~commencement of operations of the facilities, or, if such defects are discovered after operations have commenced, could halt or discontinue operation of a particular facility indefinitely. In addition, construction projects often involve delays in obtaining permits and encounter delays due to ~~severe~~weather ~~penalties~~conditions, the provision of materials or labor or other events. In addition, changes in political administrations at the federal, state or local levels that result in policy change towards oilfield processing or our project in particular, could cause construction and operation delays. Any of these events may adversely affect our sales and profitability.

The generation of electricity in biodiesel-fueled facilities is subject to regulation by various federal and state government agencies, including, but not limited to the EPA, the TCEQ and other agencies in each jurisdiction where our existing and proposed facilities are located. Environmental laws and regulations that affect our operations, and that are expected to affect our planned operations, are extensive and have become progressively more stringent. Applicable laws and regulations are subject to change, which could be made retroactively. Violations of environmental laws and regulations or permit conditions can result in substantial penalties, injunctive orders compelling installation of additional controls, civil and criminal sanctions, permit revocations and/or facility shutdowns. If significant unforeseen liabilities arise for corrective action or other compliance, our sales and profitability could be adversely affected.

We may be unable to obtain commercially reasonable terms on construction contracts for our planned power generation facilities.

We served as our own contractor for our Oak Ridge North and Montgomery County facilities and performed all necessary engineering, procurement and construction work in-house or using third-party consultants. We have recently created a wholly-owned subsidiary named Alternative Energy Consulting LLC (AEC) to manage our engineering, procurement and construction work and perform comparable services for third parties. We presently own 100% of AEC, although our percentage interest is expected to decline as it hires additional staff and expands its operations. We plan to rely on AEC in connection with planned future expansion of our generating capacity. If we are not able to obtain commercially reasonable terms from AEC for any future acquisition and construction projects, our operations and planned growth could be adversely affected.

We may need to increase cost estimates for the acquisition or construction of future IES facilities.

The cost of engineering, procurement and construction for new IES facilities could increase significantly and there is no assurance that the final cost of any IES facilities we establish in the future will not be materially higher than anticipated. There may be design changes, material cost escalations or budgetary overruns associated with the construction of future plants. Any significant increase in the estimated construction cost of the plants could delay our ability to generate revenues or reduce the amount of revenues realized.

Various risks associated with the construction of our planned generating facilities may adversely affect our sales and profitability.

We may experience delays in the construction of our planned additional power generation facilities that we decide to build or acquire in the future. We may also encounter defects in materials and/or workmanship in connection with such projects. Any defects could delay the commencement of operations of the facilities, or, if such defects are discovered after operations have commenced, could halt or discontinue operation of a particular facility indefinitely. In addition, construction projects often involve delays in obtaining permits and encounter delays due to weather conditions, the provision of materials or labor or other events. In addition, changes in political administrations at the federal, state or local levels that result in policy change towards biofuels or our project in particular, could cause construction and operation delays. Any of these events may adversely affect our sales and profitability.

We will be a small player in an intensely competitive industry and may be unable to compete.

The ~~electric~~oil ~~power~~and gas processing industry in Texas is large and intensely competitive. Potential end-users of our ~~electricity~~equipment are generally dependent on their ~~power~~equipment supplies and unlikely to accept our company as a reliable supplier until they are satisfied that our operations will not materially impair the reliability or efficiency of their operations. Therefore, we believe that potential end-users will be unlikely to sign a contract with us until they have completed an extensive and complex internal analysis. As a result, we anticipate a lengthy sales cycle and there can be no assurance that end-users will ~~conclude~~purchase ~~that~~our ~~electricity~~GTL ~~generated~~plants byand ~~us is an acceptable alternative~~services.

We intend to offer generous equity compensation packages to our management and employees.

As a key component of our growth strategy, we intend to offer generous equity compensation packages to our management and employees. We believe such compensation packages will allow us to provide substantial incentives to our executives and employees while minimizing our cash outflow. Nevertheless, we will be required to account for the fair market value of compensatory stock issuances as operating expenses. The non-cash expenses arising from future incentive transactions are expected to materially and adversely affect our future operating results.

We may issue additional shares of common stock or derivative securities that will dilute the percentage ownership interest of our existing shareholders and may dilute the book value per share of our common stock and adversely affect the terms on which our company may obtain additional capital.

Our authorized capital includes 50,000,000 shares of common stock. The Board of Directors has the authority, without action by or vote of our shareholders, to issue all or part of the authorized shares of common and preferred stock for any corporate purpose, including equity-based incentives under existing and future incentive stock plans. We are likely to seek additional equity capital in the future as we develop our business and expand our operations. Any issuance of additional shares of common stock or derivative securities will dilute the percentage ownership interest of our shareholders and may dilute the book value per share of our common stock. Additionally, the exercise or conversion of derivative securities could adversely affect the terms on which our company can obtain additional capital. Holders of derivative securities are most likely to voluntarily exercise or convert their derivative securities when the exercise or conversion price is less than the market price for the underlying common stock. Holders of the securities will have the opportunity to profit from any rise in the market value of our common stock or any increase in our net worth without assuming the risks of ownership of the underlying shares of our common stock.

We will not be required to comply with all of the requirements of the Sarbanes-Oxley Act of 2002 because we will not be quoted or listed on the Nasdaq or a national securities exchange and quotation of our shares on the OTC Bulletin Board will limit the liquidity and price of our securities more than if our securities were so quoted or listed.

Because our securities are not quoted on or expected to qualify for quotation on the Nasdaq or any other national securities exchange, we are not subject to all of the corporate governance requirements of the Sarbanes-Oxley Act of 2002, such as independent director standards and audit committee requirements. While we may choose to voluntarily adopt some of the requirements of Sarbanes-Oxley, you may not have all of the corporate governance protection afforded to investors in companies listed on Nasdaq or a national exchange. Quotation of our securities on the OTC Bulletin Board will limit the liquidity and price of our securities more than if our securities were quoted or listed on Nasdaq or a national exchange.

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Under Rule 144, as recently amended by the SEC, the substantial bulk of our common stock is eligible for unrestricted resale into the public markets and future sales of large numbers of shares into a limited trading market or the perception that those sales could occur may cause our stock price to decline.

Fewer than 20% of our outstanding shares are owned by directors, officers and affiliates of our company and the substantial bulk of our remaining shares have been outstanding for more than six months. Under Rule 144, as recently amended by the SEC, all shares held by non-affiliates that have been issued and outstanding for more than one year are presently eligible for resale. Commencing 90 days after the effective date of our Form 10 registration statement, all shares held by non-affiliates that have been issued and outstanding for more than six months will be eligible for resale. Future sales of large numbers of shares into a limited trading market or the concerns that those sales may occur could cause the trading price of our common stock to decrease or to be lower than it might otherwise be. If an active, stable and sustained trading market does not develop, the market price for our shares will decline and such declines are likely to be permanent.

Our common stock will probably be subject to the “penny stock” rules which would make it a less attractive investment.

SEC rule 3a51-1 defines a “penny stock” as any equity security that is not listed on the NASDAQ system or a national securities exchange and has an inside bid price of less than $5 per share. Our common stock will probably be subject to the penny stock rules. Before effecting a transaction that is subject to the penny stock rules, a broker-dealer must make a determination respecting the suitability of the purchaser; deliver certain disclosure materials to the purchaser and receive the purchaser’s written approval of the transaction. Because of these restrictions, most broker-dealers refrain from effecting transactions in penny stocks and many actively discourage their clients from purchasing such securities. Therefore, both the ability of a broker-dealer to recommend our common stock and the ability of holders of our common stock to sell their shares in the secondary market are likely to be adversely affected. Until the inside bid price of our stock exceeds $5 per share, the penny stock rules will decrease market liquidity and make it difficult for you to use our stock as collateral.

We are unlikely to pay dividends for the foreseeable future.

We have never declared or paid cash dividends and we do not expect to pay cash dividends in the foreseeable future. While our dividend policy will be based on the operating results and capital needs of our business, we believe any future earnings will be retained to finance ongoing operations and the expansion of our business.

ITEM 2 — PROPERTIES

Our executive office is located at 20202 Hwy 59 N, Suite 210, Humble, TX 77338. Our telephone number is 281-364-7590. We are utilizing the space on a monthly basis and are not under a lease agreement with regard to the space.

In addition to our executive office facilities, we have:

·	purchased a 79 acre industrial site in Houston, Texas called H. O. Clarke that has a decommissioned former Houston Light and Power generating plant that had supplied up to 288 MW from gas fired steam turbines to the city from the 1940’s to the late 1990’s when the industry was deregulated.

H.O. Clarke Facility: We purchased the 79 acre H.O. Clarke site from NRG Energy on March 25, 2008. A portion of this site was sold and we currently own just over 54 acres. The facility has a decommissioned 288 MW steam plant, a connection to the adjacent 138 kV Centerpoint Energy transmission substation, 65,000 bbl above ground fuel storage tankage, two 6” and one 12” natural gas pipelines previously connected to a Kinder Morgan high pressure gas pipeline and six turbine pad sites with connections to a 12Kv distribution power line and adjacent to Centerpoint Energy distribution substation.

ITEM 3 — LEGAL PROCEEDINGS

We are not a party to any material litigation, and we are not aware of any pending or threatened litigation against us that could have a material adverse affect on our business, operating results or financial condition.

ITEM 4 — SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS

We have not submitted any matters for a stockholders vote during ~~2012~~2014.

2013

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PART II

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

Market Information

We are currently trading on the OTCBB exchange as BFLS.OBPK.

Holders

As of March 31, ~~2013~~2015, there were 302 holders of record of our common stock, including 100 original Texoga Shareholders; 58 former holders of TBP-I and TBP-II units that exchanged their units for shares of our common stock; 58 shareholders who purchased shares in our private placements; 54 shareholders who purchased outstanding shares from our shareholders and 24 employees who received shares of our stock in compensatory transactions. See "Security Ownership of Certain Beneficial Owners and Management" for information on the holders of our common stock. Also see "Description of Registrant’s Securities to be Registered" for a description of our outstanding and issued capital stock.

Dividends

We have never paid cash dividends on our common stock and do not intend to pay cash dividends in the foreseeable future. Our company is not likely to pay cash dividends for an extended period of time, if ever. You should not subscribe to purchase our shares if you require current income from your investments.

2007 Stock Incentive Plan

Subject to stockholder approval at our next annual meeting, our Board of Directors has adopted an incentive stock plan for the benefit of our employees. Under the terms of the plan, we are authorized to grant incentive awards for up to 2,000,000 shares of common stock. No incentive awards are outstanding at the date of this annual report on Form 10-K. When we are eligible to do so, we intend to file a registration statement under the Securities Act on Form S-8 to register the securities included in and authorized by our 2007 Incentive Stock Plan. That registration statement is expected to become effective upon filing. Shares covered by the registration statement will thereupon be eligible for sale in the public market, subject in certain cases to vesting and other plan requirements.

The plan provides for the grant of incentive awards to full-time employees, non-employee directors and consultants. Within the limits of the plan, the Company will have absolute discretion in deciding who will receive awards and the terms of such awards. The plan authorizes the creation of incentive and/or non-qualified stock options, shares of restricted and/or phantom stock and stock bonuses. In addition, the plan will allow us to grant cash bonuses payable when an employee is required to recognize income for federal income tax purposes because of the vesting of shares of restricted stock or the grant of a stock bonus.

The Compensation Committee will administer the plan; decide which employees will receive incentive awards; make determinations with respect to the type of award to be granted; and make determinations with respect to the number of shares covered by the award. The Compensation Committee will also determine the exercise prices, expiration dates and other features of awards. The Compensation Committee will be authorized to interpret the terms of the plan and to adopt any administrative procedures it deems necessary. The Compensation Committee may not, however, increase the number of shares subject to the plan; materially increase the benefits accruing to holders of incentive awards; or materially modify the eligibility requirements. All decisions of the Compensation Committee will be binding on all parties. We will indemnify each member of the Compensation Committee for good faith actions taken in connection with the administration of the plan.

The following table provides information as of December 31, ~~2012~~2014 with respect to the shares of our common stock that may be issued under our existing equity compensation plans.

Plan Category	Number of Securities to be Issued Upon Exercise of Outstanding Options, Warrants and Rights		Weighted Average Exercise Price of Outstanding Options, Warrants and Rights		Number of Securities Remaining Available For Future Issuance Under Equity Compensation Plan
Equity compensation plans approved by security holders		0		-	2,000,000 (subject to shareholder approval)
Equity compensation plans not approved by security holders		0		-	0
Total		0		-	2,000,000 (subject to shareholder approval)

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Securities Eligible for Resale

Rule 144 Under Rule 144, as recently amended by the SEC, all shares held by non-affiliates that have been issued and outstanding for more than one year are presently eligible for resale and commencing 90 days after the effective date of our registration statement on Form 10, all shares held by non-affiliates that have been issued and outstanding for more than six months will be eligible for resale. Future sales of large numbers of shares into a limited trading market or the concerns that those sales may occur could cause the trading price of our common stock to decrease or to be lower than it might otherwise be. If an active, stable and sustained trading market does not develop, the market price for our shares will decline and such declines are likely to be permanent

Rule 701 Under Rule 701, as currently in effect, shares of common stock acquired in compensatory transactions by employees of privately held companies may be resold by persons, other than affiliates, beginning 90 days after the date of the effectiveness of this annual report on Form 10-K, subject to manner of sale provisions of Rule 144, and by affiliates in accordance with Rule 144 without compliance with its one-year minimum holding period.

22Combined On the date of this annual report on Form 10-K, we had 34,672,760 shares outstanding, including 12,876,846 shares held by persons who are not directors, officers or affiliates of our company. Of this total:

~~Combined~~· On21,374,720 ~~the~~shares ~~date~~held ofby ~~this annual report on Form 10~~non-K,affiliates wehave ~~had~~been ~~31,442,760 shares~~ outstanding, ~~including~~since 12February 28,~~876,846~~ ~~shares~~2007 ~~held~~and ~~by persons who~~ are ~~not~~presently ~~directors,~~eligible ~~officers~~for orresale ~~affiliates~~pursuant ofto ~~our~~Rule ~~company. Of this total:~~144;

· ~~21,374,720 shares held by non-affiliates have been outstanding since February 28, 2007 and are presently eligible for resale pursuant to Rule 144; ·~~ 450,000 shares were issued to non-affiliates pursuant to Rule 701 in November 2007 and will be eligible for resale commencing 90 days after the effectiveness of our pending Form 10 registration statement; and · 1,983,269 shares were issued to non-affiliates between February 28, 2007 and September 10, 2007, and will become eligible for resale pursuant to Rule 144 commencing 90 days after the effectiveness of our Form 10 registration statement.

·	1,983,269 shares were issued to non-affiliates between February 28, 2007 and September 10, 2007, and will become eligible for resale pursuant to Rule 144 commencing 90 days after the effectiveness of our Form 10 registration statement.

Recent Sales of Unregistered Securities

Set forth below is information regarding common stock issued by our company during 2008 and the subsequent interim period. Also included is the consideration, if any, we received and information relating to the section of the Securities Act, or rule of the SEC, under which exemption from registration was claimed.

Sale of Common Stock for Cash

During the year ended December 31, 2014, we sold 3,230,000 shares of our common stock to accredited investors for cash. During the year ended December 31, 2013 there were no shares of our common stock sold.

During the period from November 2006 through March 2008, we sold 6,490,237 shares of our common stock to accredited investors for cash. The offer was directed solely to accredited investors who each had a pre-existing business relationship with our company or M1-Energy Capital Securities and D.E. Wine Investments, the broker-dealers we retained to act as selling agents. All potential investors were provided disclosure documentation that was appropriate for an offering restricted to accredited investors; afforded the opportunity to ask questions and receive answers concerning the terms and conditions of the offering; afforded the opportunity to obtain such additional information and documentation as they deemed necessary to verify the accuracy of information furnished; and afforded the opportunity to obtain any additional information they considered material to their investment decisions. The offer and sale of our shares was affected without any advertising or general solicitation. A total of 58 accredited investors purchased shares of our common stock for cash. All certificates representing shares sold for cash were imprinted with a restrictive legend to the effect that the shares were not transferable by the holders thereof in the absence of an effective registration statement under the Securities Act, or an available exemption therefrom. The sale of our securities for cash was affected in reliance on the exemption from registration set forth in Section 4(2) of the Securities Act and Rule 506 of Regulation D promulgated thereunder

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Issuance of Common Stock in Compensatory Transactions

On November 1, 2007, we issued a total of 1,250,000 shares of common stock to a total of 24 individuals who are directors, officers and employees of, or principal consultants to our company, including 60,000 shares that were subsequently forfeit when the grantees resigned from our board of directors. The total number of grant shares represented less than 5% of the total number of common shares outstanding before the grants. Each recipient of grant shares signed a written agreement that described the terms of the grant and was provided information about the risks associated with our securities, audited financial statements for the year ended December 31, 2006 and unaudited financial statements for the six months ended June 30, 2007. Each recipient of grant shares was also afforded the opportunity to ask questions and receive answers concerning the terms and conditions of the grant; and to obtain such additional information and documentation as they deemed necessary to verify the accuracy of information furnished, or material to their investment decisions. All shares were distributed to the recipients as outright grants and no cash consideration was paid by any recipient. All stock grants were 50% vested on the issue date and the remaining 50% will vest ratably at the rate of 5% per month over the next 10 months. The distribution of compensatory shares was affected without any advertising or general solicitation and all of the purchasers are employees of or consultants to our company. None of the shares were issued in connection with the offer or sale of securities in a capital-raising transaction, or for the purpose of directly or indirectly promoting or maintaining a market for our shares, which are not presently traded on any market. All certificates representing shares issued to employees and consultants were imprinted with a restrictive legend to the effect that the shares were not transferable by the holders thereof in the absence of an effective registration statement under the Securities Act, or an available exemption therefrom. The issuance was affected in reliance on the exemption from registration set forth in Rule 701.

Purchases of Equity Securities

We have never purchased any shares of our common stock and we are not likely to purchase any shares in the foreseeable future. Our founders have not repurchased any shares of our common stock and are not likely to do so in the foreseeable future.

ITEM 6 — SELECTED FINANCIAL DATA.

We are a smaller reporting issuer as defined in Item 10 of Regulation S-K and are not required to report the selected financial data specified in Item 301 of Regulation S-K.

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

The following discussion of the financial condition and plan of operations contains forward-looking statements that involve risks and uncertainties. Please see “Risk Factors” and “Cautionary Note Regarding Forward-Looking Statements” elsewhere in this annual report on Form 10-K.

Financial condition

In December 2006, we became the general partner of TBF-I and TBF-II; sold approximately 2 million shares of our common stock for approximately $1.5 million in cash; recorded 1,050,000 shares of common stock as unissued in exchange for 700 units of limited partnership interest in TBF-I; and issued 870,000 shares of common stock in exchange for 580 units of limited partnership interest in TBF-II. Since December 31, 2006, we have acquired all of the remaining TBF-I units and dissolved the partnership. We have also acquired 2,470 additional TBF-II units and presently own an 87.1% majority of the outstanding TBF-II units. In accordance with FIN 46(R), which requires the consolidation of certain variable interest entities, our consolidated financial statements for the years ended December 31, ~~2012~~2014 and ~~2011~~2013 include the accounts of TBF-I and TBF-II, and reflect the limited partner interests held by others as a long-term liability. During 2007, we sold approximately 4 million additional shares of our common stock for approximately $3 million in cash. The following table provides summary balance sheet information as of December 31, ~~2012~~2014 and ~~2011~~2013, and is based on the audited annual financial statements included elsewhere in this annual report on Form 10-K.

	December 31, 2012			December 31, 2011
ASSETS
Cash and cash equivalents	$	19,052		$	23,508
Accounts Receivable		-			-
Other current assets		-			-
Property and equipment, net		1,211,032			1,869,234
Total assets	$	1,230,084		$	1,869,742
LIABILITIES
Current Liabilities		5,283,183		$	6,250,765
Notes Payable		191,250			191,250
Total liabilities	$	5,474,433		$	6,442,015
STOCKHOLDERS EQUITY
Common stock, 31,442,760 outstanding at December 31, 2012 and 31,442,760 shares outstanding at December 31, 2011	$	31,455		$	31,455
Additional paid in capital		12,434,494			12,434,494
Minority interest		-0-			37,534
Retained earnings (deficit)		(16,710,298	)		(17,052,756	)
Total Stockholders equity	$	(4,244,349)		$	(4,549,272)

24Table of Contents

	December 31, 2014			December 31, 2013
ASSETS
Cash and cash equivalents	$	2,246		$	222
Accounts Receivable		833,110			-
Other current assets		-			-

Property and equipment, net		1,434,083			1,211,032

Total assets	$	2,269,438		$	1,211,254

LIABILITIES
Current Liabilities		7,372,200		$	5,870,908
Notes Payable		191,250			191,250


Total liabilities	$	7,563,450		$	6,062,158

STOCKHOLDERS EQUITY
Common stock, 34,672,760 outstanding at December 31, 2014 and 31,442,760 shares outstanding at December 31, 2013	$	34,685		$	31,455
Additional paid in capital		13,077,264			12,434,494




Retained earnings (deficit)		(18,405,963	)		(17,316,854	)
Total Stockholders' equity (deficit)	$	(5,294,012	)	$	(4,850,904	)

Plan of Operation

We began ~~selling~~producing electricity ~~from~~and ~~our~~selling 5power MWinto ~~facility~~the ERCOT grid in ~~Oak~~2007 ~~Ridge~~and ~~North,~~then ~~Texas~~we inbegan ~~February~~selling ~~2007~~power ~~and~~into ~~commenced~~the ~~commercial~~Entergy ~~sales~~grid in the first quarter of 2008. Both ~~electricity~~of ~~from~~these ~~our~~projects 10utilized MW100% ~~Montgomery~~renewable ~~County~~fuels ~~facility~~to inproduce ~~January~~electricity ~~2008~~during a period when power prices were high. InBy ~~early~~2010, ~~2009~~a weglut ~~decommissioned~~in ~~the~~natural ~~Oak~~gas ~~Ridge~~supplies ~~North~~reduced ~~and~~the ~~Montgomery~~power ~~County~~prices by over two-thirds. We ~~consolidated~~discontinued ~~operations~~power sales at this ~~site~~time ~~because~~and itshifted ~~allowed~~to ~~for~~our ~~both~~current ~~distribution~~focus ~~and~~on ~~transmission~~GTL ~~grid~~projects ~~connections~~which ~~into~~could ~~ERCOT~~take advantage of low natural gas prices versus higher relative oil prices.

WeAs ~~acquired~~part of the ~~H.O.~~redirection ~~Clarke~~of ~~power~~our ~~plant~~business ~~site~~we ~~that~~signed isa ~~adjacent~~letter toof anintent ~~active~~in ~~138~~2012 ~~kV Centerpoint Energy substationinter-connected~~ with ~~ERCOT. Our~~RMBI ~~site~~International ~~has~~(now ~~four~~“Liberty ~~decommissioned~~GTL”) ~~gas–fired~~to ~~steam~~perform ~~generating~~an ~~units~~engineering ~~that~~study ~~totaled~~with ~~288~~ThyssenKrupp ~~MW. These~~Industrial ~~will~~Solutions be(“Krupp”) ~~evaluated~~related ~~for components that can be reused, sold or demolished for the scrap value. Adjacent~~ to the ~~steam~~construction ~~generating~~of ~~units~~a ~~are~~small ~~six~~scale, ~~pad~~modular ~~sites for~~ gas ~~turbines connected~~ -to-liquids ~~Centerpoint’s~~(“GTL”) ~~12kV~~facility ~~distribution~~located ~~system. We~~at ~~moved~~ the ~~Montgomery~~company’s ~~County~~Houston GEClean ~~Frame~~Energy 5Park ~~turbine to this site during 2009 but did not place it in operation~~(“HCEP”). Krupp Wewas ~~are~~chosen ~~presently~~because ~~conducting a technical and mechanical evaluation~~ of ~~equipment~~their ~~that~~experience ~~appears~~in ~~suitable~~the ~~for~~gas-to-liquids ~~our~~industry ~~purposes. We~~when dothe ~~not~~German ~~have~~government ~~sufficient~~produced ~~financial~~over ~~resources~~one tobillion ~~complete~~barrels ~~our planned acquisition and installation~~ of ~~this~~synthetic ~~equipment~~crude ~~and~~oil ~~there~~during ~~can~~the belast noeighty ~~assurance~~years. The ~~that~~technology ~~suitable~~under ~~financing~~consideration ~~will~~for bethe ~~available~~feasibility ~~when~~study ~~needed.~~is ~~If we are~~ not ~~able to attract adequate financing, we may have to delay or abandon our plans to reestablish power production at this~~ new site. In combination, we believe our existing facilities will give us sufficient corporate mass to make credible sales presentations to potential purchasers of green electricity and users of HACS. There can be no assurances that future contract prices for green electricity or ~~HACS~~untested ~~will~~but ~~provide~~rather ~~sufficient~~links ~~revenue~~conventional toequipment ~~offset~~in ~~our~~a ~~anticipated~~unique ~~operating expenses~~way.

WeThe ~~believe~~Front-End ~~our~~Engineering ~~company~~Design (“FEED”) study has abeen ~~unique~~completed ~~market~~at ~~focus,~~a iscost ~~well~~of ~~positioned~~over ~~demographically~~$3 million and ~~has~~on ~~proven~~July to19th be2014 ~~operationally~~we ~~efficient.~~entered ~~Many~~into ~~REPs~~a ~~are~~Joint ~~actively~~Cooperation ~~seeking~~Agreement ~~“green~~with ~~energy”~~Krupp ~~for~~and ~~sale~~Liberty GTL to ~~environmentally~~build ~~conscious~~a ~~residential~~small ~~and~~scale ~~commercial~~Gas-to-Liquids ~~customers~~demonstration ~~who~~facility ~~are~~at ~~willing~~our HCEP site. Krupp agreed to ~~pay~~provide ~~more~~technical ~~for~~services ~~electricity~~and ~~produced~~contribute ~~from~~a ~~renewable~~syngas ~~energy~~refinery ~~resources.~~(autothermal ~~Our~~reformer) ~~expertise~~from inan ~~the~~operating ~~field~~chemical ~~and~~plant ~~our~~of ~~innovative~~proven ~~approach~~design. Liberty toGTL ~~green~~has ~~energy~~agreed ~~distinguish~~to ~~our~~provide ~~company~~intellectual ~~from~~property ~~its~~and ~~competitors.~~operating ~~Nevertheless,~~know ~~there~~how isregarding acrude ~~possibility~~oil ~~that~~synthesis ~~new~~along ~~competitors,~~with ~~who~~the ~~could~~relevant becatalyst ~~better~~supply. The ~~capitalized~~purpose ~~than~~of ~~our~~the ~~company,~~two ~~could~~year ~~seize~~project ~~upon~~is ~~our~~to ~~business~~commercially ~~model~~demonstrate ~~and~~converting ~~produce~~stranded ~~electricity~~natural ~~more~~gas ~~efficiently,~~resources ~~which~~to ~~might~~synthetic ~~allow~~crude ~~them~~oil and to ~~capture~~test aone ~~significant~~or ~~share~~more ofGTL ~~our~~reactors ~~target~~that ~~market~~would still need to be acquired.

InThe ~~addition,~~current ~~the~~low ~~Company~~cost of natural gas and abundant supplies produced from unconventional shale resources enhances the ~~plans~~ opportunity to ~~help~~profitably ~~develop~~convert natural gas to higher value liquid fuels. The focus of the ~~construction~~feasibility study will be on smaller units capable of aconverting ~~small~~5 ~~scale,~~– ~~modular~~10 million cubic feet per day of natural gas~~-to-liquids~~ ~~(“GTL”)~~into ~~facility~~approximately ~~located~~500 at– ~~the~~1,000 ~~company’s~~bbls ~~Houston~~per ~~Clean~~day ~~Energy~~of ~~Park~~syncrude (~~“GTL~~a ~~Plant”~~combination of petroleum components including diesel grade fuel and naptha waxes). isA ~~timely~~plant ~~considering~~capacity expansion on the ~~current~~company’s ~~low~~HCEP ~~price~~site may be initiated on successful completion of ~~natural~~the ~~gas~~initial GTL Plant. The ~~technology~~GTL Plant concept under consideration iswould ~~not~~also ~~new~~be orcapable ~~untested~~of ~~but~~exporting ~~rather~~power ~~links~~into ~~conventional~~the ~~equipment~~Texas inERCOT ~~a unique way~~grid.

The current low cost of natural gas and abundant supplies produced from unconventional shale resources enhances the opportunity to profitably convert natural gas to higher value liquid fuels. The focus of the company’s GTL development will be on smaller units capable of converting 5–10 million cubic feet per day of natural gas into feasibility approximately 500–1,000 bbls per day of syncrude. A plant capacity expansion on the company’s Houston Clean Energy Park may be initiated on successful completion of the initial GTL Plant. The GTL Plant concept under consideration would also be capable of exporting power into the Texas ERCOT grid.

Future projects of this type may be attractive to the numerous oil operators drilling shale gas wells that may be confronted with curtailing production or, in the extreme case, ceasing production entirely. These “stranded gas wells” would be released for production if the planned GTL units could process the natural gas immediately after completion of the well.

The Houston Clean Energy Park is an ideal location for the development of a gas-to-liquids facility. The site has access to a large intrastate pipeline, grid connection through the on-site substation and easy access to the Houston Ship Channel refinery and petrochemical complex. The feasibility study is an important step in commercializing the technical concept. Future gas-to-liquids developments like this could fill a need in the energy industry for decades to come.17

25Table of Contents

~~Until~~The weHouston ~~are~~Clean ~~able~~Energy toPark ~~negotiate contracts~~is ~~that~~an ~~provide~~ideal location for athe ~~significant~~development ~~GEP,~~of wea ~~intend~~ gas-to-liquids ~~rely~~facility. onThe ~~equity~~site ~~financing~~has access to ~~cover~~a ~~our~~large ~~current~~intrastate ~~and~~pipeline, ~~anticipated~~grid ~~operating~~connection ~~losses.~~through Wethe ~~need~~on-site ~~additional~~substation ~~capital~~ and ~~intend~~easy access to ~~take~~the ~~advantage~~Houston ofShip ~~financing~~Channel ~~opportunities~~refinery asand ~~they~~petrochemical ~~arise~~complex. The ~~There~~GTLengineering study is noan ~~assurance~~important ~~that~~step ~~the~~in ~~potential~~commercializing ~~proceeds~~the oftechnical ~~any~~concept. ~~future~~Future ~~financing~~GTL ~~activities~~developments ~~will~~like bethis ~~sufficient~~could tofill ~~pay our operating costs until we can negotiate~~ a ~~significant~~need ~~GEP,~~in orthe ~~that~~energy ~~any~~industry ~~GEP~~for wedecades ~~negotiate will be sufficient~~ to ~~offset all of our operating costs~~come.

Liquidity and capital resources

During the year ended December 31, ~~2012~~2014 and December 31, ~~2011~~2013, we incurred net ~~income~~gains (losses) of $~~304~~(1,~~922~~089,109) and $(1606,~~322,797~~556) respectively. We had $19835,~~052~~355 in current assets and $57,~~283~~372,~~183~~200 in current liabilities at December 31, ~~2012~~2014, leaving us a working capital balance (deficit) of $(56,~~264~~536,~~131~~845).

Our available resources are not sufficient to pay our current operating expenses and the anticipated capital costs and we are presently seeking additional financing. We believe we will need at least $20 million in additional capital to finance our planned ~~facility~~GTL ~~expansions~~plant developments and future ~~acquisitions~~operations. Capital requirements are difficult to plan for companies like ours that are developing novel business models. We expect that we will need additional capital to pay our day-to-day operating costs, finance our feedstock and fuel inventories, finance additions to our infrastructure, and pay for the development of ~~additional~~GTL ~~generating~~ facilities ~~and the marketing of our green electricity~~. We intend to pursue additional financing as opportunities arise.

Our ability to obtain additional financing will be subject to a variety of uncertainties. The inability to raise additional funds on terms favorable to us, or at all, could have a material adverse effect on our business, financial condition and results of operations. If we are unable to obtain additional capital when required, we would be forced to halt operations.

As a result of our limited operating history, our operating plan and our growth strategy are unproven and we have limited insight into the long-term trends that may impact our business. There is no assurance that our operating plan and growth strategy will be successful or that we will be able to compete effectively, achieve market acceptance for green electricity or address the risks associated with our existing and planned business activities.

Contractual obligations

We have no contractual obligations

Off-Balance Sheet Arrangements

We have no off-balance sheet arrangements.

ITEM 7A — QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISKS

We are a smaller reporting issuer as defined in Item 10 of Regulation S-K and are not required to report the selected financial data specified in Item 305 of Regulation S-K.

2618

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ITEM 8 — FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA

Clay Thomas, P.C.

Certified Public Accountant

~~P.O.~~ 500 ~~Box~~Chestnut ~~311195~~Street

~~Houston,~~Suite ~~Texas 77231~~502

Abilene, Texas 79602

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Management of

Biofuels Power Corporation

Humble, Texas

I have audited the accompanying consolidated balance sheet of Biofuels Power Corporation as of December 31, ~~2012~~2014 and ~~2011~~2013 and the related consolidated statements of operations, stockholders' equity (deficit) and cash flows for the years ended December 31, ~~2012~~2014 and ~~2011~~2013. These financial statements are the responsibility of the Company's management. My responsibility is to express an opinion on these financial statements based on my audit.

I conducted my audit of these financial statements in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that I 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. I believe that my audit provides a reasonable basis for my opinion.

In my opinion, the financial statements referred to above present fairly, in all material respects, the financial position of Biofuels Power Corporation as of December 31, ~~2012~~2014 and 2013, and the results of its operations and its cash flows for the period then ended in conformity with accounting principles generally accepted in the United States of America.

The accompanying financial statements have been prepared assuming that the Company will continue as a going concern. As discussed in Note 2 to the financial statements, the Company has suffered significant losses and will require additional capital to develop its business until the Company either (1) achieves a level of revenues adequate to generate sufficient cash flows from operations; or (2) obtains additional financing necessary to support its working capital requirements. These conditions raise substantial doubt about the Company's ability to continue as a going concern. Management's plans in regard to these matters are also described in Note 2. The financial statements do not include any adjustments that might result from the outcome of this uncertainty.

/s/ Clay Thomas, P.C.

www.claythomaspc.com

~~Houston~~Abilene, Texas

~~April~~May 221, ~~2013~~2015

27clay.thomas@claythomaspc.com www.claythomaspc.com

~~BIOFUELS POWER CORPORATION CONSOLIDATED BALANCE SHEET December 31, 2012 and 2011~~19

	December 31,			December 31,
	2012			2011
ASSETS
Current Assets
Cash and cash equivalents	$	19,052		$	23,508
Accounts receivable		-			-
Prepaid expenses		-			-
Total Current Assets		19,052			23,508
Property and equipment, net		1,211,032			1,869,234
Total Assets	$	1,230,084		$	1,892,742
LIABILITIES AND STOCKHOLDERS EQUITY
Current Liabilities
Accounts payable		95,993			1,678,460
Deposits		-			25,000
Notes payable, unsecured		30,065			30,065
Notes payable, secured		3,030,140			2,962,615
Interest payable		2,126,985			1,554,625
Total Current Liabilities		5,283,183			6,250,765
Long Term Debt
Notes payable, unsecured		191,250			191,250
Total Liabilities		5,474,433			6,442,015
Stockholders' Equity
Common stock, $001 par value, 50,000,000 shares authorized;
31,442,760 and 31,442,760 shares issued and outstanding,
respectively		31,455			31,455
Additional paid in capital		12,434,494			12,434,494
Minority interest		(0	)		37,534
Accumulated deficit		(16,710,298	)		(17,052,756	)
Total Stockholders Equity		(4,244,349	)		(4,549,272	)
	$	1,230,084		$	1,892,742
		(0	)
See accompanying notes to consolidated financial statements

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28BIOFUELS POWER CORPORATION

~~BIOFUELS POWER CORPORATION~~ CONSOLIDATED ~~STATEMENT~~BALANCE ~~OF OPERATIONS For the years ended December 31, 2012 and 2011~~SHEET

	Years Ended December 31,
	2012			2011
Revenue
Sales	$	-		$	-
Cost of sales		-			-
Gross profit (deficit)		-			-
Selling, general and administrative expenses		808,387			829,619
Operating loss		(808,387	)		(829,619	)
Other Income:
Other income, net		34,750			34,029
Gain (loss) on disposition of fixed assets		-			(300	)
Interest expense		(572,360	)		(526,907	)
Total other income (loss), net		(537,610	)		(493,178	)
Net Loss before extra-ordinary items		(1,345,997	)		(1,322,797	)
Income recognized from restatement of accounts payable		1,650,919			-
Net Income before minority interest		304,922			(1,322,797	)
Minority interest		37,534			42,485
Net income (loss)		342,456			(1,280,312	)
Basic and diluted net income (loss) per common share	$	0.01		$	(0.04	)
Weighted average common shares outstanding -
basic and diluted		31,442,760			31,442,760
See accompanying notes to consolidated financial statements

December 31, 2014 and 2013

	December 31,			December 31,
	2014			2013
ASSETS

Current Assets
Cash and cash equivalents	$	2,246		$	222
Accounts receivable		833,110			-
Prepaid expenses		-			-

Total Current Assets		835,355			222

Property and equipment, net		1,434,083			1,211,032

Total Assets		2,269,438			1,211,254


LIABILITIES AND STOCKHOLDERS EQUITY

Current Liabilities
Accounts payable		953,487			26,114
Deposits and advances		-			-
Notes payable, unsecured		30,065			30,065
Notes payable, secured		3,131,668			3,126,068
Interest payable		3,256,980			2,688,662

Total Current Liabilities		7,372,200			5,870,909

Long Term Debt
Notes payable, unsecured		191,250			191,250


Total Liabilities		7,563,450			6,062,159

Stockholders' Equity
Common stock, $.001 par value, 50,000,000 shares authorized; 34,672,760 and 31,442,760 shares issued and outstanding, respectively		34,685			31,455
Additional paid in capital		13,077,264			12,434,494
Accumulated deficit		(18,405,963	)		(17,316,854	)

Total Stockholders Equity		(5,294,012	)		(4,850,904	)

	$	2,269,438		$	1,211,254

~~BIOFUELS~~See ~~POWER~~accompanying ~~CORPORATION~~notes ~~CONSOLIDATED~~to ~~STATEMENT~~consolidated OFfinancial ~~CASH FLOWS For years ended December 31, 2012 and 2011~~statements

	For the years ended December 31,
	2012			2011
Cash flows from operating activities:
Net income (loss)	$	342,456		$	(1,280,310	)
Adjustments to reconcile net loss to net cash used in operating activities:
Depreciation		670,155			748,121
Loss on abandoment of leasehold improvements					(269,364	)
Minority interest		(37,534	)		(42,485	)
Changes in operating assets and liabilities:
Accounts payable		(1,582,467	)		195,051
Deposit		(25,000	)
Accrued interest payable		572,360			514,956
Accrued expenses and other, net		(11,952	)		22,251
Net Cash provided (used) in operating activities		(71,982	)		(111,780	)
Cash flows from financing activities:
Net proceeds from notes		67,525			130,150
		-			-
Net cash provided by financing activities		67,525			130,150
Net increase (decrease) in cash and cash equivalents		(4,457	)		18,370
Cash and cash equivalents, beginning of period		23,508			5,138
Cash and cash equivalents, end of period	$	19,052		$	23,508
		(0	)
See accompanying notes to consolidated financial statements

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BIOFUELS POWER CORPORATION
UNAUDITED CONSOLIDATED STATEMENT OF STOCKHOLDERS' EQUITY
For the years ended December 31, 2012 and 2011
					Additional
	Common Stock				Paid In		Minority			Accumulated
	Shares		Amount		Capital		Interest			Deficit			Total
Balance at
December 31, 2010		31,422,760	$	31,455	$	12,434,494	$	80,019		$	(15,772,446	)	$	(3,226,478	)
Net loss		-		-		-		(42,485	)		(1,280,310	)		(1,322,795	)
Balance at
'December 31, 2011		31,422,760		31,455		12,434,494		37,534			(17,052,756	)		(4,549,273	)
Net income (loss)		-		-		-		(37,534	)		342,456			304,922
Balance at
'december 31, 2012		31,422,760	$	31,455	$	12,434,494	$	(0	)	$	(16,710,300	)	$	(4,244,352	)
See accompanying notes to consolidated financial statements

BIOFUELS POWER CORPORATION

31CONSOLIDATED STATEMENT OF OPERATIONS

For the years ended December 31, 2014 and 2013

	For the years ended December 31
	2014			2013
Revenue
Sales	$	-		$	-

Cost of sales		-			-

Gross profit (deficit)		-			-

Selling, general and administrative expenses		520,789			119,392

Operating loss		(520,789	)		(119,392	)

Other Income:
Other income, net		-			47,550
Gain (loss) on disposition of fixed assets		-			-
Interest expense		(568,320	)		(561,676	)

Total other income (loss), net		(568,320	)		(514,126	)

Net income (loss) before extra-ordinary items		(1,089,109	)		(633,519	)

Income recognized from restatement of accounts payable		-			26,963

Net Income (Loss)	$	(1,089,109	)	$	(606,556	)

Basic and diluted net income (loss) per common share	$	(0.03	)	$	(0.02	)

Weighted average common shares outstanding - basic and diluted		32,984,431			31,442,760

See accompanying notes to consolidated financial statements

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BIOFUELS POWER CORPORATION

CONSOLIDATED STATEMENT OF STOCKHOLDERS' EQUITY

For the years ended December 31, 2014 and 2013

					Additional
	Common Stock				Paid In		Minority		Accumulated
	Shares		Amount		Capital		Interest		Deficit			Total

Balance at December 31, 2012		31,422,760		31,455		12,434,494	-			(16,710,298	)		(4,244,348	)

Net (loss)		-		-		-	-			(606,556	)		(606,556	)

Balance at December 31, 2013		31,422,760		31,455		12,434,494		-		(17,316,854	)		(4,850,904	)

Issuance of common stock		3,230,000		3,230		642,770		-		-			646,000

Net income (loss)		-		-		-		-		(1,089,109	)		(1,089,109	)

Balance at Decmber 31, 2014		34,652,760	$	34,685	$	13,077,264	$	-	$	(18,405,963	)	$	(5,294,012	)

See accompanying notes to consolidated financial statements

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BIOFUELS POWER CORPORATION

CONSOLIDATED STATEMENT OF CASH FLOWS

For the years ended December 31, 2014 and 2013

	For the years ended December 31,
	2014			2013

Cash flows from operating activities:
Net income (loss)	$	(1,089,109	)	$	(606,556	)
Adjustments to reconcile net loss to net cash used in operating activities:
Depreciation		-			-
Minority interest		-			-
Changes in operating assets and liabilities:
Accounts receivable		(833,110	)		-
Fixed assets		(223,051	)		-
Accounts payable		927,373			(69,880	)
Deposits and advances		-			-
Accrued interest payable		568,318			561,676
Accrued expenses and other, net		-			-

Net Cash provided (used) in operating activities		(649,578	)		(114,760	)

Cash flows from financing activities:
Net proceeds from notes		5,600			95,928
Net proceeds from sales of common stock		646,000			-

Net cash provided by financing activities		651,600			95,928

Net increase (decrease) in cash and cash equivalents		2,022			(18,831	)

Cash and cash equivalents, beginning of period		222			19,052

Cash and cash equivalents, end of period	$	2,245		$	222

See accompanying notes to consolidated financial statements

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BIOFUELS POWER CORP.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

1. Summary of Significant Accounting Policies

Background

Biofuels Power Corp. (“BPC”), a Texas corporation, was incorporated in 2004 as Aegis Products, Inc. The Company is a distributed energy company that is pioneering the use of biodiesel to fuel small electric generating facilities that are located in close proximity to end-users. BPC’s first power plant is located near Houston, Texas in the city of Oak Ridge North. During February 2007, BPC began generating and selling its power through Fulcrum Power to Centerpoint Energy. In January 2008, BPC’s second power plant located just north of its first facility near the City of Oak Ridge North began generating and selling its power directly to Entergy.

Aegis Products, Inc. was incorporated in Texas on January 20, 2004 as a wholly-owned subsidiary of Texoga Technologies Corp. (“Texoga”). Effective December 31, 2004 Aegis was spun off from Texoga through a share distribution to the Texoga shareholders with 87 owners receiving a total of 14,512,380 shares. During 2006 the Texoga BioFuels 2006-1 and 2006-2 partnerships were established and each raised $3.5 million to develop biofueled power projects in the Houston, Texas area. Texoga began serving as the general partner and on November 6, 2006, Texoga transferred its general partner role to Aegis which simultaneously changed its name to Biofuels Power Corp.

During 2007, ~~BPC~~we created a ~~wholly-owned~~ subsidiary, Alternative Energy Consultants, ~~LLC~~Inc. (“AEC”). AEC will engage in the business of designing and building of standardized ~~biodiesel~~GTL ~~refineries~~plants.

In December 2014, we created a subsidiary, Independence Synfuel, LLC (“Independence”). Independence will further develop the joint venture with Krupp and Liberty GTL.

Consolidation

In accordance with ASC Codification Topic 810: Consolidation of Variable Interest Entities, which requires the consolidation of certain variable interest entities, these consolidated financial statements include the accounts of BPC, Texoga BioFuels 2006-1, Ltd, (“TBF-1”) and Texoga BioFuels 2006-2, Ltd. (“TBF-2”). BPC, TBF-1 and TBF-2 are referred to collectively as the “Company”. For presentation purposes, the equity interests of the limited partners in TBF-1 and TBF-2 have been reflected as minority interest shareholders. The consolidated financial statements also include the accounts of Alternative Energy Consultants, LLC, which is a wholly-owned subsidiary of BPC. All material intercompany transactions have been eliminated in consolidation.

Use of Estimates and Assumptions

The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America (“U.S.”) requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reported periods. Actual results could materially differ from those estimates.

Cash and Cash Equivalents

The Company considers any highly liquid debt instruments purchased with an original maturity of three months or less to be cash equivalents.

Derivative Instruments and Hedging

The Company ~~uses~~used derivatives to hedge against increases in the price of feedstock, primarily soybean oils, used in the production of biodiesel. All derivative instruments ~~are~~were recorded as assets or liabilities on the balance sheet at fair value. Changes in the fair value of derivatives are either recorded in the income statement or other comprehensive income, as appropriate. The gain or loss on derivatives designated as fair value hedges and the offsetting loss or gain on the hedged item attributable to the hedged risk are included in income in the period that changes in fair value occur. The effective portion of the gain or loss on derivatives designated as cash flow hedges is included in other comprehensive income in the period that changes in fair value occur and is reclassified to income in the same period that the hedged item affects income. The remaining gain or loss in excess of the cumulative change in the present value of the cash flows of the hedge item, if any, is recognized in income. As of December 31, ~~2012~~2043 and December 31, ~~2011~~2013, the Company did not have any open hedge contracts.

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Revenue Recognition

Revenue, which began to be recorded during 2007, is recognized when the electricity produced is provided to the electric grid maintained by the Electric Reliability Council of Texas (ERCOT). A power sales agreement is in place with Fulcrum Power, a Qualified Scheduling Entity (QSE) for ERCOT. Electric sales into ERCOT may only be made through the scheduling of a QSE, which also receives payment from ERCOT for all sales in a process called “settlement.” Initial settlement takes place eight (8) days after the date of sale with subsequent adjustments at sixty (60) days and one hundred eighty (180) days after the sale, if needed. To date, the Company has not experienced any material settlement adjustments and it does not anticipate material settlement adjustments in the future. All of the sales from the Company’s Oak Ridge North facility are made into the ERCOT Balancing Energy Market. Such sales are priced by ERCOT for each fifteen (15) minute interval of each hour of each day. The price for all balancing energy dispatched in a given interval is the highest bid of any electricity dispatched by ERCOT in that interval. The price per megawatt is determined at the time of the sale. ERCOT bills each utility company purchaser, collects the money due under a formal settlement process and remits the proceeds to the QSE scheduling the electricity actually purchased. The QSE pays the power generator when it receives payment from ERCOT. The Company pays Fulcrum Power a monthly fee for services that are not directly related to the revenue the Company receives from sales of electricity.

32Revenue from the second power generating plant was sold directly to Entergy under an agreement whereby the power provided to Entergy was metered through Entergy facilities and then paid directly to us based upon the Entergy rate schedule.

Revenue from the second power generating plant is sold directly to Entergy under an agreement whereby the power provided to Entergy is metered through Entergy facilities and then paid directly to Biofuel Power Corporation based upon the Entergy rate schedule.

Biodiesel Tax Credits

Biodiesel is classified as a renewable fuel that is eligible for Federal credits of $1.00 per gallon for biodiesel manufactured from virgin agricultural products and $0.50 per gallon for biodiesel produced from non-virgin oils and fats. The gallons used are reported to the Federal government and the Company receives a payment of $1.00 per gallon, which is accounted for as a direct offset to fuel prices and included in the Company’s cost of sales. BPC received $-0- and $-0- in Federal credits during 2012 and 2011, respectively.

Accounts Receivable

Accounts receivable ~~consist~~consisted primarily of amounts due from certain companies for the sale of power to the electric grid. An allowance for doubtful accounts is provided, when appropriate, based on past experience and other factors which, in management’s judgment, deserve current recognition in estimating probable bad debts. Such factors include circumstances with respect to specific accounts receivable, growth and composition of accounts receivable, the relationship of the allowance for doubtful accounts to accounts receivable and current economic conditions. As of December 31, ~~2012~~2013 and ~~2011~~2012 the Company had no trade accounts receivable or Federal credits receivable.

The Company has entered into a joint venture agreement with Liberty GTL, SA for the purpose of funding and constructing a pilot gas to liquids (GTL) plant at the Hiram Clarke facility, Houston, Texas. The initial joint venture agreement was executed May 25, 2012, and has been amended December 10, 2013, July 9, 2014, and February 26, 2015. The equipment to be used has been billed to both Biofuels Power Corporation and to Liberty GTL, SA as of December 31, 2014. The equipment invoice is reflected in the accounts payable of the Company as well as engineering fees. Biofuels Power Corporation has recorded an accounts receivable from the joint venture as a result of recognizing the joint venture accounts payable. As of December 31, 2014 the receivable from the joint venture was $833,110. There was no receivable from joint venture partners as of December 31, 2013.

Inventory

Inventory is stated at the lower of cost or market. As of December 31, 2009 the inventory was written down to reflect the results of litigation settled in the 4th quarter 2009 pertaining to the leased facility where fuel inventory tanks were located. The result of the settlement the fuel tanks remained at the leased facility and the fuel inventory abandoned. Fuel inventory as of December 31, ~~2012~~2014 and December 31, ~~2011~~2013 were $-0- and $-0- respectively.

Property and Equipment

Property and equipment are stated at cost less accumulated depreciation. Expenditures for normal repairs and maintenance are charged to expense as incurred. Fixed assets are depreciated using the straight-line method for financial reporting purposes over their estimated useful life of 5 years. The cost and related accumulated depreciation of assets sold or otherwise disposed of are removed from the accounts and any gain or loss is included in operations.

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Impairment of Long-Lived Asset

Management reviews long-lived assets for impairment whenever events or changes in circumstances indicate that the carrying amount may not be realizable. If an evaluation is required, the estimated future undiscounted cash flows associated with the asset are compared to the asset’s carrying value amount to determine if an impairment of such asset is necessary. The effect of any impairment would be to expense the difference between the fair value of such asset and its carrying value. Beginning in the third quarter 2009, the Company began relocating to the newly acquired H. O. Clark facility. As a result the remaining un-depreciated value of leasehold improvements at the Oak Ridge North and Tamina facilities were expensed. Equipment at the Oak Ridge North facility that was not relocated, but was sold in the first quarter was written down to its net realizable value. A ($1,233,384) loss was recognized as a result of these write downs as of December 31, 2009. In 2010 additional equipment was sold totaling $178,527 and an additional loss of ($246,473) was recognized as a result of write downs. For the year ended December 31, 2012 a review of the fixed assets resulted in a write down of $1,499,612 in fixed assets with a reduction in allowance for depreciation on those assets of $1,499,612. No gain or loss resulted from the asset write down. No equipment was written off for the year ended December 31, 2014 or 2013.

Income Taxes

The Company uses the liability method in accounting for income taxes. Under this method, deferred tax assets and liabilities are determined based on differences between financial reporting and income tax carrying amounts of assets and liabilities and are measured using the enacted tax rates and laws that will be in effect when the differences are expected to reverse. The Company provides a valuation allowance to reduce deferred tax assets to their net realizable value.

The Partnership’s taxable income or loss for any period is included in the tax returns of the individual partners and, therefore, the Partnership does not provide for federal income taxes.

Loss Per Common Share

The Company provides basic and dilutive loss per common share information for each period presented. The basic net loss per common share is computed by dividing the net loss by the weighted average number of common shares outstanding. Diluted net loss per common share is computed by dividing the net loss, adjusted on an "as if converted" basis, by the weighted average number of common shares outstanding plus potential dilutive securities. For the year ended December 31, ~~2012~~2014 and ~~2011~~2013, the Company did not have any potential dilutive securities.

Stock-Based Compensation

On January 1, 2006, the Company adopted ASC Codification Topic 718 Compensation: Stock Based Compensation, using the modified prospective method. Under the modified prospective method, the Company would begin recognizing expense on January 1, 2006 for the unvested portion of awards granted before the adoption date expected to vest over the remaining vesting period of the award. New awards granted after the adoption date will be expensed ratably over the vesting period of the award.

ASC Codification Topic 718 Compensation: Stock Based Compensation is a codification of SFAS 123(R) which is a revision of SFAS 123, Accounting for Stock-Based Compensation, and supersedes APB No. 25, Accounting for Stock Issued to Employees. Under SFAS 123(R), the cost of employee services received in exchange for stock is measured based on the grant-date fair value (with limited exceptions). That cost is to be recognized over the period during which an employee is required to provide service in exchange for the award (usually the vesting period). The fair value of immediately vested shares is determined by reference to quoted prices for similar shares and the fair value of shares issued subject to a service period is estimated using an option-pricing model. Excess tax benefits, as defined in SFAS 123(R) are recognized as addition to paid-in-capital.

Fair Value of Financial Instruments

The Company includes fair value information in the notes to financial statements when the fair value of its financial instruments is different from the book value. When the book value approximates fair value, no additional disclosure is made. Fair value estimates of financial instruments are based on relevant market information and may be subjective in nature and involve uncertainties and matters of significant judgment. The Company believes that the carrying value of its assets and liabilities approximates the fair value of such items. The Company does not hold or issue financial instruments for trading purposes.

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Concentration of Credit Risk

Financial instruments which subject the Company to concentrations of credit risk include cash and cash equivalents and accounts receivable. The Company maintains its cash and cash equivalents with major financial institutions selected based upon management’s assessment of the banks’ financial stability. Balances periodically exceed the $100,000 federal depository insurance limit. The Company has not experienced any losses on deposits. Accounts receivable generally arise from sales of power to the electric grid. Collateral is generally not required for credit granted. The Company will provide allowances for potential credit losses when necessary.

Recently Issued Accounting Pronouncements

In February 2006, ASC Codification Topic 815, Derivatives and Hedging, FASB issued SFAS No. 155, “Accounting for Certain Hybrid Financial Instruments—an amendment of FASB Statements No. 133 and 140”. This Statement resolves issues addressed in Statement 133 Implementation Issue No. D1, “Application of Statement 133 to Beneficial Interests in Securitized Financial Assets”. This Statement permits fair value re-measurement for any hybrid financial instrument that contains an embedded derivative that otherwise would require bifurcation, clarifies which interest-only strips and principal-only strips are not subject to the requirements of Statement 133, establishes a requirement to evaluate interests in securitized financial assets to identify interests that are freestanding derivatives or that are hybrid financial instruments that contain an embedded derivative requiring bifurcation, clarifies that concentrations of credit risk in the form of subordination are not embedded derivatives, amends Statement 140 to eliminate the prohibition on a qualifying special-purpose entity from holding a derivative financial instrument that pertains to a beneficial interest other than another derivative financial instrument. This statement is effective for fiscal years beginning after September 15, 2006. Its adoption did not have a material impact on the Company’s financial condition or results of operations.

ASC Codification Topic 820, “Fair Value Measurements” (“SFAS 157”), issued in September 2006, establishes a formal framework for measuring fair value under GAAP. It defines and docifies the many definitions of fair value included among various other authoritative literature, clarifies and, in some instances, expands on the guidance for implementing fair value measurements, and increases the level of disclosure required for fair value measurements. Although Codification Topic 820 (SFAS 157) applies to and amends the provisions of existing FASB and AICPA pronouncements, it does not, of itself, require any new fair value measurements, nor does it establish valuation standards. Codification Topic 820 (SFAS 157) applies to all other accounting pronouncements requiring or permitting fair value measurements, except for Codification Topic 718, share-based payment and related pronouncements, the practicability exceptions to fair value determinations allowed by various other authoritative pronouncements, and ASC Codification Topic 985 (AICPA Statements of Position 97-2 and 98-9) that deal with software revenue recognition. This statement is effective for financial statements issued for fiscal years beginning after November 15, 2007, and interim periods within those fiscal years. Management does not believe the adoption of Codification Topic 820 will have a material impact on the Company’s financial condition or results of operations.

In February 2007, the FASB issued ASC Codification Topic 825 (SFAS 159, “The Fair Value Option for Financial Assets and Financial Liabilities”), which is an elective, irrevocable election to measure eligible financial instruments and certain other assets and liabilities at fair value on an instrument-by-instrument basis. The election may only be applied at specified election dates and to instruments in their entirety rather than to portions of instruments. Upon initial election, the entity reports the difference between the instruments’ carrying value and their fair value as a cumulative-effect adjustment to the opening balance of retained earnings. At each subsequent reporting date, an entity reports in earnings, unrealized gains and losses on items for which the fair value option has been elected. ASC Codification Topic 825 (SFAS 159) is effective for financial statements issued for fiscal years beginning after November 15, 2007, and is applied on a prospective basis. Early adoption of ASC Codification Topic 825 (SFAS 159) is permitted provided the entity also elects to adopt the provisions as of the early adoption date selected for ASC Codification Topic 825 (SFAS 159). The Company has elected not to adopt the provisions of ASC Codification Topic 825 at this time.

In June 2006, FASB issued ASC Codification Topic 740 (FIN 48, “Accounting for Uncertainty in Income Taxes an interpretation of FASB Statement No. 109”), which clarifies the accounting for uncertainty in income taxes recognized in financial statements in accordance with ASC Codification Topic 740 (FASB 109, “Accounting for Income Taxes”). Codification Topic 740 prescribes a recognition threshold and measurement attribute for the financial statement recognition and measurement of a tax position taken or expected to be taken in a tax return. The provisions of Codification Topic 740 were effective for fiscal years beginning after December 15, 2006, with the cumulative effect of the change in accounting principle recorded as an adjustment to opening retained earnings. The adoptions of this pronouncement did not have a material effect on the financial position or results of operations of the Company.

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In December 2007, the FASB issued ASC Codification Topic 805, a revision and replacement of SFAS 141(“SFAS 141R”), “Business Combination,” to increase the relevance, representational faithfulness, and comparability of the information a reporting entity provides in its financial reports about a business combination and its effects. Codification Topic 805 codifies SFAS 141R which replaced SFAS 141, “ Business Combinations ” but, retains the fundamental requirements of SFAS 141 that the acquisition method of accounting be used and an acquirer be identified for all business combinations. Codification Topic 805 expanded the definition of a business and of a business combination and establishes how the acquirer is to: (1) recognize and measure in its financial statements the identifiable assets acquired, the liabilities assumed, and any non-controlling interest in the acquired company; (2) recognize and measure the goodwill acquired in the business combination or a gain from a bargain purchase; and (3) determine what information to disclose to enable users of the financial statements to evaluate the nature and financial effects of the business combination. Codification Topic 805 is applicable to business combinations for which the acquisition date is on or after the beginning of the first annual reporting period beginning on or after December 15, 2008, and is to be applied prospectively. Early adoption is prohibited. Codification Topic 805 impact the Company only if it elects to enter into a business combination subsequent to December 31, 2008.

In December 2007, the FASB issued ASC Codification Topic 810 (SFAS 160, “Noncontrolling Interests in Consolidated Financial Statements – an amendment of ARB No. 51,”) to improve the relevance, comparability, and transparency of the financial information a reporting entity provides in its consolidated financial statements. This amended ARB 51 to establish accounting and reporting standards for noncontrolling interests in subsidiaries and to make certain consolidation procedures consistent with the requirements of ASC Codification Topic 805. It defines a noncontrolling interest in a subsidiary as an ownership interest in the consolidated entity that should be reported as equity in the consolidated financial statements. Codification Topic 810 changes the way the consolidated income statement is presented by requiring consolidated net income to include amounts attributable to the parent and the noncontrolling interest. SFAS 160 establishes a single method of accounting for changes in a parent’s ownership interest in a subsidiary which does not result in deconsolidation. Codification Topic 810 also requires expanded disclosures that clearly identify and distinguish between the interests of the parent and the interests of the noncontrolling owners of a subsidiary. Codification Topic 810 is effective for financial statements issued for fiscal years beginning on or after December 15, 2008, and interim periods within those fiscal years. Early adoption is prohibited. Codification Topic 810 shall be applied prospectively, with the exception of the presentation and disclosure requirements which shall be applied retrospectively for all periods presented. The Company does not believe that the adoption of Codification Topic 810 would have a material effect on its consolidated financial position, results of operations or cash flows.

2. Going Concern

During the years ended December 31, ~~2012~~2014 and ~~2011~~2013, the Company has experienced negative financial results as follows:

	2012			2011
	2014			2013
Net income (loss)	$	304,922		$	(1,280,310	)
Net (loss)	$	(1,089,109	)	$	(606,556	)
Positive (Negative) cash flows from operations		(71649,~~982)~~578	)		(~~111~~114,~~780~~760	)
Accumulated deficit		(1618,~~710~~405,~~298)~~963	)		(17,~~052~~316,~~756~~854	)

De-recognition of accounts payable - the Company determined that as of December 31, 2012 certain provisions of the Texas Civil Practices and Remedy Code apply and that accounts payable vendors have been de-recognized as an operation of law. The effect of the adjustment is that $1,650,919 is recognized as income for the year ended December 31, 2012, and that accounts payable liability is reduced by the same amount.

Management has developed specific current and long-term plans to address its viability as a going concern as follows:

· The Company is attempting to raise funds through debt and/or equity offerings. If successful, these additional funds will be used to provide working capital. · In the long-term, the Company believes that cash flows from growth in its operations will provide the resources for continued operations. · The Company is also pursuing other strategic initiatives including a merger or sale of the Company as opportunities are available.

·	In the long-term, the Company believes that cash flows from growth in its operations will provide the resources for continued operations.

·	The Company is also pursuing other strategic initiatives including a merger or sale of the Company as opportunities are available.

There can be no assurance that the Company will have the ability to implement its business plan and ultimately attain profitability. The Company’s long-term viability as a going concern is dependent upon three key factors, as follows:

· The Company’s ability to obtain adequate sources of debt or equity funding to meet current commitments and fund the continuation of its business operations in the near term. ~~· The ability of the Company to control costs and expand revenues. · The ability of the Company to ultimately achieve adequate profitability and cash flows from operations to sustain its operations.~~

·	The ability of the Company to control costs and expand revenues.

·	The ability of the Company to ultimately achieve adequate profitability and cash flows from operations to sustain its operations.

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3. Hedge Accounts

The Company had no hedging accounts or hedging activity during ~~2012~~2014 or ~~2011~~2013.

4. Property and Equipment

Property and equipment consisted of the following at December 31, ~~2012~~2014 and ~~2011~~2013:

	2012			2011
	2014			2013
Power generating equipment	$	2,048,000		$	32,~~368~~048,~~146~~000
Buildings and improvements		1,~~185~~371,~~925~~083			1,~~186,225~~185925
Machinery and equipment		3031,~~028~~029			~~198~~30,~~241~~028
Less accumulated depreciation		(2,~~052~~016,~~921~~028	)		(~~2883~~2,~~378~~052,921	)
Total property and equipment, net	$	1,~~211~~434,~~032~~083		$	1,~~869~~211,~~234~~032

Depreciation expense for the years ended December 31, ~~2012~~2014 and ~~2011~~2013 was $~~670,155~~-0- and $~~748,121 of which all was recorded as a general and administrative expense~~-0-.

5. Notes Payable

During 2007, the Company issued $456,450 of notes payable as payment for the purchase of certain limited partnership interests. Also during 2007, $265,200 of these notes payable were paid through the issuance of 353,592 shares of the Company’s common stock valued at $.75 per share which was the fair value of the common stock on the date of grant based on the cash price received for the common stock in a private placement offering.

As of December 31, 2007, there are three remaining notes payable of $191,250 due to the former limited partners of TBF-1. These notes bear interest at 12.5% due semi-annually. Principal is due in full in forty-eight months from the execution date of the note. The notes are not collateralized.

On August 20, 2008, the Company entered into a Securities Purchase Agreement with accredited investors for the purchase of the Company’s convertible promissory notes in the aggregate amount of up to $2,000,000 bearing interest at 18% per annum, payable on or before August 19, 2009. The agreement was increased to $3,000,000 and extended to August 19, 2011. On August 1019, ~~2012~~2014 the note was extended to August 19, ~~2013~~2015. The Company has received $3,~~030~~131,~~140~~668 and $23,~~962~~126,~~615~~068 as of December 31, ~~2012~~2014 and ~~2011~~2013 respectively.

The Security Purchase Agreement contains provisions that if qualified financing is not secured by the maturity date, the Company will be required to issue warrants to the note holders resulting in a valuation of $5,000,000 providing that the strike price is $0.75. In addition, the note holder has the right, but not the obligation, to convert all or a portion of the principal and accrued interest outstanding under its note into shares of common stock.

We have evaluated these features of our convertible promissory notes and determined that they meet the definition of embedded derivative as defined by ASC Codification Topic 815 (SFAS 133, “Accounting for Derivatives and Hedging Activities,”) and have recorded derivative liabilities of $-0- as of December 31, ~~2012~~2014 and $-0- as of December 31, ~~2011~~2013.

6. Income Taxes

Deferred income taxes reflect the net tax effects of temporary differences between the carrying amounts of assets and liabilities for financial reporting purposes and the amounts used for income tax purposes. Significant components of the Company’s deferred tax assets and liabilities at December 31, ~~2012~~2014 and ~~2011~~2013 were as follows:

	2012			2011
	2014			2013
Deferred tax assets:
Receivable from affiliate	$	121,041		$	121,041
Net operating loss carry-forwards		~~663~~1,~~661~~127,002			~~614~~754,~~501~~644
Total deferred tax assets		~~784~~1,~~702~~248,043			~~735~~875,~~542~~685
Valuation allowance		(~~784~~1,~~702)~~248,043	)		(~~735542~~875,685	)
Net deferred tax asset	$	-		$	-

3729

~~The~~Table ~~difference between the income tax provision (benefit) in the accompanying statement~~ of ~~operations and the amount that would result if the U.S. Federal statutory income tax rate of 34% were applied for the year-ended December 31, 2012 and 2011, are as follows:~~Contents

	2012						2011
	Amount			%			Amount			%
Benefit for income tax at federal
statutory rate	$	(470,130	)		(34.0	)	$	(435,306	)		(34.0	)
Income attributable to limited partners		37,534			4.0			42,485			4.0
Stock based compensation								0			0.0
Settlement expense								0			0.0
Increase in valuation allowance		56,000			1.2			56,000			1.2
Other		376,596			28.8			336,821			28.8
	$	-			0.0		$	-			0.0

The difference between the income tax provision (benefit) in the accompanying statement of operations and the amount that would result if the U.S. Federal statutory income tax rate of 34% were applied for the year-ended December 31, 2014 and 2013, are as follows:

As of December 31, 2012, for U.S. federal income tax reporting purposes, the Company has approximately $12,250,000 of unused net operating losses (“NOL's”) available for carryforward to future years. The benefit from carryforward of such NOL's will expire during various years through 2029. Because United States tax laws limit the time during which NOL carryforwards may be applied against future taxable income, the Company may be unable to take full advantage of its NOL for federal income tax purposes should the Company generate taxable income. Further, the benefit from utilization of NOL carryforwards could be subject to limitations due to material ownership changes that may or may not occur in the Company. Based on such limitations, the Company has significant NOL’s for which realization of tax benefits is uncertain.

	2014						2013
	Amount			%			Amount			%

Benefit for income tax at federal statutory rate	$	(424,334	)		(34.0	)	$	(493,636	)		(34.0	)
Income attributable to limited partners		-0-			4.0			37,534			4.0
Stock based compensation								0			0.0
Settlement expense								0			0.0
Increase in valuation allowance		372,358			1.2			56,000			1.2
Other		51,976			28.8			400,102			28.8

	$	-			0.0		$	-			0.0

6As of December 31, 2014, for U. ~~Stockholders~~S. federal income tax reporting purposes, the Company has approximately $14,600,000 of unused net operating losses (“NOL's”) available for carryforward to future years. The benefit from carryforward of such NOL's will expire during various years through 2029. Because United States tax laws limit the time during which NOL carryforwards may be applied against future taxable income, the Company may be unable to take full advantage of its NOL for federal income tax purposes should the Company generate taxable income. Further, the benefit from utilization of NOL carryforwards could be subject to limitations due to material ownership changes that may or may not occur in the Company. Based on such limitations, the Company has significant NOL’s ~~Equity~~for which realization of tax benefits is uncertain.

~~The Company entered into an investment banking contract with M1 Energy Capital Securities, LLC (“M1 Energy”) of Chicago, Illinois to raise capital under a Regulation D Private Placement Offering~~7. Stockholders’ M1 Energy raised $3,500,000 for TBF-1 and $3,500,000 for TBF-2. These offerings were to sell up to 3,500 Membership Units (“Units”) to accredited investors at $1,000 per unit. The total cost paid to M1 Energy of $777,239 was recorded as a reduction in the minority interest liability. M1 Energy also raised $3,926,355 through December 31, 2007 for a Private Placement for Biofuels Power Corp. As compensation for this service as of December 31, 2007, M1 Energy was paid $225,000 in cash and was issued 247,816 shares of common stock with a value of $309,770 or $1.25 per share which was the fair value of the common stock on the date of grant based on the cash price received for the common stock in a private placement offering. .Equity

The Company entered into an investment banking contract with M1 Energy Capital Securities, LLC (“M1 Energy”) of Chicago, Illinois to raise capital under a Regulation D Private Placement Offering. M1 Energy raised $3,500,000 for TBF-1 and $3,500,000 for TBF-2. These offerings were to sell up to 3,500 Membership Units (“Units”) to accredited investors at $1,000 per unit. The total cost paid to M1 Energy of $777,239 was recorded as a reduction in the minority interest liability. M1 Energy also raised $3,926,355 through December 31, 2007 for a Private Placement for Biofuels Power Corp. As compensation for this service as of December 31, 2007, M1 Energy was paid $225,000 in cash and was issued 247,816 shares of common stock with a value of $309,770 or $1.25 per share which was the fair value of the common stock on the date of grant based on the cash price received for the common stock in a private placement offering.

Under the terms of the Partnership agreements, the partners are entitled to receive 90% of net cash flow from operations until they receive cumulative cash distributions of $14 million. Thereafter, the partners are entitled to receive 15% of the net cash flow from operations until the Company exercises the buy-out rights specified in the agreements.

During the period from formation of the Partnerships through 2007, market prices of feedstocks used in the production of the biodiesel fuel used to power the Company’s power generation facilities rose dramatically, making the Company’s projected operations less profitable than originally intended. In response to the adverse market conditions for biodiesel feedstocks, in December 2006 the Company made an exchange offer (the “December 2006 Exchange Offer”) by which all limited partners of the Partnerships were given the opportunity to exchange Units of limited partner interests in the Partnerships for shares of the Company’s common stock equivalent in value to the cash amount paid by such limited partners for the original purchase of their respective Units. The basis of the December 2006 Exchange Offer was 1,500 shares of Company common stock for each tendered Unit, the equivalent of $0.67 per share. As of December 31, 2006, limited partners in TBF-1 had tendered 700 Units, and limited partners in TBF-2 had tendered 580 Units, resulting in the Company being obligated to issue 1,920,000 shares of its common stock of which 870,000 shares were issued as of December 31, 2006 and 1,050,000 issued in 2007. Since the fair value of the common stock is $0.75 per share, based on the cash price received for the common stock in a current private placement, the Company has recorded the value of the excess shares issued upon conversion of the limited partnership interests of $160,000 as settlement expense in general and administrative expense in the accompanying statement of operations for the year ended December 31, 2006.

On March 15, 2007 the Company made a second exchange offer (the “March 15, 2007 Exchange Offer”) for Units of TBF-1 and TBF-2. The basis of the March 15, 2007 Exchange Offer was to exchange one hundred Units of $100,000 original issuance value for 1,500 shares of the Company’s common stock per unit, the equivalent of $0.67 per share (or ratable portion thereof) or to exchange such 100 units for a cash payment of $102,500 (or ratable portion thereof). As a result, the Company was required to pay $512,500 for the exchange of 500 partnership units. During the year ended December 31, 2007, limited partners in TBF-1 converted 2,045 partnership units at 1,500 shares per unit, and 755 partnership units at 1,133 shares per unit resulting in the Company issuing 2,918,160 shares to limited partners in TBF-1.

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In August of 2007, the Company made a third exchange offer (the “August 2007 Exchange Offer”) for all outstanding Units of TBF-2. The basis of the August 2007 Exchange Offer was, following receipt by the limited partner of a distribution by TBF-1 of current allocable income, as follows: a cash payment of $100 from the Company plus, at the election of the tendering limited partner, either (A), receipt of 1,133.33 shares of the Company’s common stock, valued at $0.75 per share, which was subsequently changed to 1,267 shares per partnership unit or (B) a promissory note made by the Company with a principal value of $850, payable over four years with 12.5% annual interest. In the case of option (B), the Company has, with payee partner consent, the ability to repay the principal in either cash or registered shares of Company common stock, provided that the Company’s common stock is at the time of payment trading on a public exchange or bulletin board quotation system and has achieved certain trading volume requirements. During the year ended December 31, 2007 limited partners in TBF-2 converted 1,370 partnership units at 1,500 shares per unit, and 850 partnership units at 1,267 shares per unit resulting in the Company issuing 3,131,661 shares to limited partners in TBF-2.

Since the fair value of the common stock is $0.75 per share, based on the cash price received for the common stock in the current private placement, the Company has recorded the value of the excess shares issued upon conversion of the limited partnership interests of $322,988 as settlement expense in general and administrative expense in the accompanying statement of operations for the year ended December 31, 2007.

As a result of the December 2006 Exchange Offer, the March 15, 2007 Exchange Offer, and the August 2007 Exchange Offer, the Company as of December 31, 2007 owns 3,500 Units of TBF-1 and 2,950 Units of TBF-2, representing 100% and 84% of the outstanding Units of TBF-1 and TBF-2, respectively.

During November 2007, the Company issued 300,000 shares of its common stock to employees of the Company, 950,000 shares were issued to officers and directors of the Company (of which 60,000 shares were subsequently forfeited) and 144,630 shares were issued to consultants for services performed. The shares issued to employees, officers and directors vest at 50% upon issuance and 5% per month thereafter. These shares were valued at $1.25 per share which was the fair value of the common stock on the date of grant based on the cash price received for the common stock in a private placement offering. As a result, the Company recorded $1,073,288 in selling, general and administrative expenses and $595,000 in deferred compensation related to the issuance of this common stock during 2007. During 2008, the remaining balance of $595,000 in deferred compensation was recorded in selling, general and administrative expenses.

398. Commitments and Contingencies

7. Commitments and Contingencies

Operating Lease

During the fourth quarter 2010 the corporate offices relocated to shared offices spaces on a month to month basis without a lease obligation.

Litigation

The Company does not have any litigation at this time.

Fulcrum Power Agreement

In January 2007, the Company entered into a three year Energy Management Agreement with Fulcrum Power Services, L.P. (“Fulcrum”) whereby Fulcrum is to perform as the Qualified Scheduling Entity for the Company’s power generating facility. Per the agreement, the Company iswas required to pay Fulcrum $6,000 per month for the first year of the agreement with a 5% escalation in the fee for each year thereafter. ~~This agreement was terminated in 2009.~~

89. Related Party Transactions

During the year ended December 31, 2007, the Company advanced $407,501 to Texoga and SRC, which are both former affiliates. These advances were recorded as receivable from affiliate. As of December 31, 2007, the Company has reserved a cumulative total of $664,227 for advances during 2007 and 2006 to Texoga and SRC as an allowance for doubtful accounts due to the uncertainty of collection.

During the year ended December 31, 2007, the Company paid certain affiliated companies approximately $306,000 for labor and equipment used in the build out of its electric generator facilities. In addition, the Company paid approximately $177,000 to an affiliate for the purchase of feedstock.

On August 28, 2008, the Company received $400,000 loan proceeds from one of its shareholders as part of the $2.5 million loan commitment for the purposes of providing capital expenditures and working capital.

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On October 13, 2008, the Company received $200,000 loan proceeds from one of its shareholders as part of the $2.5 million loan commitment for the purposes of providing capital expenditures and working capital.

On October 1, 2008, the Company’s Chief Executive Officer, Fred O’Connor advanced the Company $12,500 in the form of a note payable. The Company repaid the loan during October 2008.

During 2009 the Company received an additional $299,500 from shareholders as part of loan commitment that was renewed and extended for the purposes of providing capital expenditures and working capital.

During 2010 the Company received an additional $20,465 from shareholders as part of loan commitment that was renewed and extended for the purposes of providing capital expenditures and working capital.

During 2011 the Company received an additional $130,150 from shareholders as part of loan commitment that was renewed and extended for the purposes of providing capital expenditures and working capital.

During 2012 the Company received an additional $67,525 from shareholders as part of loan commitment that was renewed and extended for the purposes of providing capital expenditures and working capital.

~~9. Subsequent~~During ~~Events~~2013 the Company received an additional $95,928 from shareholders as part of loan commitment that was renewed and extended for the purposes of providing capital expenditures and working capital.

On March 26, 2012 the Company announced that it has signed a letter of intent with RMBI International to perform a feasibility study related to the construction of a small scale, modular gas-to-liquids (“GTL”) facility located at the company’s Houston Clean Energy Park (“GTL Plant”)10. ~~The~~ Subsequent technology under consideration for the feasibility study is not new or untested but rather links conventional equipment in a unique way. The feasibility study is nearly complete at a cost of approximately $1 million. A joint venture will be formed with the Company receiving a carried 25% interest in exchange for the long term use of site and certain generation equipment should the project be completed.Events

~~The~~In ~~current~~January ~~low~~2015, ~~cost~~we oftook ~~natural~~delivery ~~gas~~of ~~and abundant supplies produced from unconventional shale resources enhances~~ the ~~opportunity~~syngas torefinery ~~profitably~~(autothermal ~~convert~~reformer) ~~natural~~contributed ~~gas~~by toKrupp ~~higher~~at ~~value~~our ~~liquid~~HCEP ~~fuels~~site. It ~~The~~is ~~focus~~estimated ofthat ~~the~~this ~~feasibility~~refinery ~~study~~ will betake onover ~~smaller~~120 ~~units~~days ~~capable~~to ~~of converting 5–10 million cubic feet per day of natural gas into approximately 500–1,000 bbls per day of syncrude~~recommission. This Aequipment ~~plant~~represents ~~capacity expansion on~~ the ~~company’s~~key ~~Houston~~piece ~~Clean Energy Park may be initiated on successful completion~~ of ~~the~~our ~~initial~~ GTL ~~Plant. The~~pilot ~~GTL~~plant ~~Plant~~expected ~~concept~~to ~~under consideration would also~~ be ~~capable~~operational ofduring ~~exporting power into the Texas ERCOT grid~~2015.

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

NOT APPLICABLE

ITEM 9A — CONTROLS AND PROCEDURES

Controls and Procedures

We maintain disclosure controls and procedures that are designed to ensure that the information we are required to disclose in our reports filed or submitted under the Securities Exchange Act of 1934 is recorded, processed, summarized and reported, within the time periods specified in the Securities and Exchange Commission’s rules and forms. Our disclosure controls and procedures include, without limitation, controls and procedures designed to ensure that information is accumulated and communicated to management, including our chief executive officer and our chief financial officer, to allow timely decisions regarding required disclosure.

In designing and evaluating our disclosure controls and procedures, management recognized that disclosure controls and procedures, no matter how well conceived and operated, can provide only reasonable, not absolute, assurance that the objectives of the disclosure controls and procedures are met. Additionally, in designing disclosure controls and procedures, our management necessarily was required to apply its judgment in evaluating the cost-benefit relationship of possible disclosure controls and procedures. While the design of our disclosure controls and procedures is adequate for our current needs and anticipated future conditions, and there can be no assurance that our current design will succeed in achieving its stated goals under all possible future conditions. Accordingly we may be required to modify our disclosure controls and procedures in the future.

Our management, with the participation of our Chief Executive Officer and Chief Financial Officer, evaluated the effectiveness of our disclosure controls and procedures as of December 31, ~~2011~~2014. Based on this evaluation, our Chief Executive Officer and our Chief Financial Officer concluded the design of our system of disclosure controls and procedures was adequate as of those dates to ensure that material information relating to our Company would be made known to them and that our system of disclosure controls and procedures was operating to provide a reasonable level of assurance that information required to be disclosed in our reports would be recorded, processed, summarized and reported in a timely manner. These conclusions were based on the identification of the following material weaknesses:

· We did not properly segregate duties and restrict access to accounting systems and data, spreadsheets used for critical calculations were not properly controlled, agreements and contracts were not always promptly provided to the accounting function; and ~~· We do not have a comprehensive set of policies and procedures, related to corporate governance, accounting , human resources, and other significant matters.~~

·	We do not have a comprehensive set of policies and procedures, related to corporate governance, accounting , human resources, and other significant matters.

We added or are initiating the following additional controls to the Company’s internal control over financial reporting, which we expect will improve such internal control subsequent to the date of the assessment and earlier assessments that also concluded internal controls were not effective. These changes are:

· We have retained a qualified independent consultant to serve as our Chief Financial Officer and to supervise our accounting staff in matters relating to the identification and implementation of proper accounting procedures and provide guidance on financial reporting issues that apply to the Company; · We performed additional analysis and other procedures in order to identify weaknesses in order to develop an adequate system of disclosure and financial controls, · We are continuing to restructure certain departmental responsibilities as they relate to the financial reporting function,

·	We performed additional analysis and other procedures in order to identify weaknesses in order to develop an adequate system of disclosure and financial controls,

·	We are continuing to restructure certain departmental responsibilities as they relate to the financial reporting function,

As a result of these changes, management believes that all material weaknesses have been remediated.

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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 Exchange Act Rule 13a-15(f). Our system of internal control over financial reporting is designed to provide reasonable assurance to our management and board of directors regarding the preparation and fair presentation of published financial statements and the reliability of financial reporting. Because of their inherent limitations, internal controls over financial reporting may not prevent or detect misstatements. Therefore, even those systems determined to be effective can provide only reasonable assurance with respect to financial statement preparation and presentation.

Our management assessed the effectiveness of our internal control over financial reporting as of December 31, ~~2009~~2014. In making this assessment, management used the criteria set forth by the Committee of Sponsoring Organizations of the Treadway Commission (“COSO”) in Internal Control - Integrated Framework. Based on that assessment, we believe that as of December 31, ~~2011~~2014, our internal control over financial reporting is effective.

This annual report does not include an attestation report of our registered public accounting firm regarding internal control over financial reporting. Management’s report was not subject to attestation by our registered public accounting firm pursuant to temporary SEC rules that permit us to provide only management’s report in this annual report on Form 10-K.

Beginning with our Annual Report on Form 10-K for the year ending December 31, ~~2009~~2014, management’s report on internal control over financial reporting must contain a statement that our independent registered public accountants have issued an attestation report on management’s assessment of such internal controls and conclusion on the operating effectiveness of those controls, unless the SEC extends the compliance date for such auditor attestation.

Changes in Internal Control Over Financial Reporting

There was no change in our internal control over financial reporting that occurred during our last fiscal year that materially affected, or is likely to materially affect, our internal control over financial reporting. Our auditor has not notified us that any material weakness exists with respect to our internal financial controls.

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PART III

ITEM 10 — DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE

Our Board of Directors presently consists of three directors who are elected to serve for one-year terms at our annual meeting of stockholders. The following table identifies our executive officers and directors and specifies their respective ages and positions.

Name	~~Age~~	~~Position~~Age	~~Term Expires~~	Position	Term Expires
Eric Gadd	57	Interim COO	2013 Annual Meeting
Sam H. Lindsey, Jr		69		Interim CFO
Sam H. Lindsey, Jr	67	Interim CFO
Alan Schaffner		54		Independent Director	2015 Annual Meeting
Alan Schaffner	52	Independent Director	2013 Annual Meeting
Steven McGuire		59		Managing Director, Director	2015 Annual Meeting
Richard DeGarmo	58	Independent Director	2013 Annual Meeting

Eric Gadd was appointed interim COO on September 22, 2009. Mr. Gadd has over 30 years domestic and international experience in power, natural gas, and renewable energy and has been involved in the power plant development and operations around the world. Prior to his involvement with Biofuels Power Corporation, Mr. Gadd founded Awelon, LLC in 2006 as a consulting practice focused on renewable and alternative energy. Awelon provided executive experience in developing business strategies to grow early stage energy businesses. From 1995-2005, Mr. Gadd held several executive positions in operating subsidiaries of Enron Corp., including CEO of Enron Wind Corp, Vice President of Enron Transportation Services, and Vice President of Enron Europe, Ltd., and served on the board of directors of Enron Renewable Energy. Prior to 1995, Mr. Gadd held various positions at Enron Corp. and Constellation Energy. Mr. Gadd is a graduate of Virginia Tech (BS 1977) and John Hopkins University (MDA 1987).

Sam H. Lindsey, Jr. has served as part-time Chief Financial Officer of our company since March 2008. Mr. Lindsey is a 1971 accounting major graduate of the University of Houston with a BBA. Mr. Lindsey passed the CPA exam in 1973 and has been in public accounting and industry since that time. During his time in public accounting, Mr. Lindsey served a managing partner of his accounting firm and acquired extensive experience in tax, audit, accounting services and management advisory services. Since leaving public practice, Mr. Lindsey has served as CFO for four reporting companies and a large privately held oilfield service company.

Alan Schaffner, Esq. was appointed to a newly created seat on our Board of Directors in October 2007. Mr. Schaffner has been self-employed as an independent trader at the Chicago Board of Trade for 20 years. He has extensive expertise in the agricultural futures and options markets and specializes in relational derivative strategies and risk mitigation. Mr. Schaffner is a 1982 graduate of the University of Wisconsin where he earned a degree in accounting, and a 1986 graduate of the Chicago Kent College of Law where he earned a juris doctor degree. Mr. Schaffner is a certified public accountant and a licensed attorney in Illinois.

~~Richard~~Steven ~~DeGarmo~~S. McGuire, was appointed todirector ~~a newly created seat~~ on ~~our~~March ~~Board~~13, of2014 replacing ~~Directors~~Richard ~~in October 2007~~DeGarmo. Mr. ~~DeGarmo~~McGuire ~~was~~is ~~appointed~~the ~~chief~~president ~~executive officer~~ of ~~SRC~~Texoga, inserves ~~February~~as ~~2008,~~Managing ~~previously~~Director ~~served~~ as ~~chief~~well ~~technical~~as ~~officer~~Project ofManager ~~SRC~~for ~~from~~the ~~November~~Houston ~~2006~~Clean ~~through~~Energy ~~January~~Park ~~2008,~~project. ~~and~~Mr. ~~previously~~McGuire served ~~for two years~~ as ~~SRC~~the Company’s chief executive officer. ~~Mr. DeGarmo is a professional process engineer with 25 years of international experience in design, construction~~ and ~~operation~~was offormerly ~~process plants~~Chairman, ~~training~~CEO ofor ~~personnel,~~President ~~business development, filing~~ of ~~patents,~~three ~~permitting,~~energy ~~computer modeling~~ and ~~financial~~technology ~~planning.~~companies ~~Before~~that ~~joining~~had ~~SRC~~operations in ~~January~~three ~~2005,~~countries ~~Mr. DeGarmo served for five years as vice president of Global Resource Recovery Organization, Inc.~~ and ~~was~~over ~~responsible~~200 ~~for developing process solutions for the disposal of organic wastes, biosolids, residual chemicals, and industrial and agricultural waste~~employees. Mr. ~~DeGarmo~~McGuire is a ~~dual~~1977 ~~degree~~ graduate of ~~Ohio~~the ~~State~~ University ~~where~~of heIllinois, ~~earned~~Champaign-Urbana ~~a bachelors degree in agricultural sciences~~ (~~1977~~B.S. Physics) and ais ~~Masters~~an ~~degree~~active inmember ~~agricultural~~of ~~engineering~~the ~~(1981).~~Society ~~Mr.~~of ~~DeGarmo~~Petroleum isEngineers aand ~~registered~~the ~~professional~~Society ~~engineer~~of inProfessional ~~Texas~~Well Log Analysts.

Key Consultants

~~Steven~~Robert S.Wilson ~~McGuire,~~served as part-time CFO from the ~~president~~inception of ~~Texoga~~the Company until March 2008, now serves as aVice ~~part-time~~President, ~~consultant~~Finance. Mr. toWilson ~~our~~who ~~company~~serves as ~~well~~the asCFO ~~Project~~and ~~Manager~~Operations Principal for ~~the~~several ~~Houston~~broker ~~Clean~~dealer ~~Energy~~and ~~Park~~investment ~~project.~~banking Mrfirms. His ~~McGuire~~duties ~~served~~include ascompliance with NASD, SEC and NYSE rules and regulations, the ~~Company’s~~design ~~chief~~and ~~executive~~implementation ~~officer~~of accounting and ~~was~~operations ~~formerly~~control ~~Chairman~~procedures, ~~CEO~~representing orfirms ~~President~~as ofan ~~three~~expert ~~energy~~witness and ~~technology~~with ~~companies~~NASD ~~that~~examinations. He ~~had~~currently ~~operations~~serves inas ~~three~~a ~~countries~~director and ~~over~~audit ~~200~~committee ~~employees~~chairman for American Security Resources, Inc. and American Enterprise Development Corporation and as a consultant with The Professional Directors Institute. Mr. ~~McGuire~~Wilson is a ~~1977~~CPA ~~graduate~~and has over fifteen years of experience as the ~~University~~owner of ~~Illinois~~a certified public accounting firm, ~~Champaign-Urbana~~was (Bpreviously a member of the NASD board of Arbitrators and has several NASD and NYSE licenses.S Mr. ~~Physics)~~Wilson ~~and~~has ispreviously anserved ~~active~~as ~~member~~operations compliance manager of the ~~Society~~AIM Management Group, Vice President Compliance/Internal Audit of ~~Petroleum~~the ~~Engineers~~Kemper Securities Group and ~~the~~an ~~Society~~auditor with Price Waterhouse. Mr. Wilson is a 1977 graduate of ~~Professional~~Houston ~~Well~~Baptist ~~Log~~University ~~Analysts~~and pursued additional studies at Georgetown University.

Robert Wilson served as part-time CFO from the inception of the Company until March 2008, now serves as Vice President, Finance. Mr. Wilson who serves as the CFO and Operations Principal for several broker dealer and investment banking firms. His duties include compliance with FINRA, SEC and NYSE rules and regulations, the design and implementation of accounting and operations control procedures, representing firms as an expert witness and with FINRA examinations. He has served as a director and audit committee chairman for American Security Resources, Inc. and American Enterprise Development Corporation and as a consultant with The Professional Directors Institute. Mr. Wilson is a CPA and has over fifteen years of experience as the owner of a certified public accounting firm, was previously a member of the NASD board of Arbitrators and has several NASD and NYSE licenses. Mr. Wilson has previously served as operations compliance manager of the AIM Management Group, Vice President Compliance/Internal Audit of the Kemper Securities Group and an auditor with Price Waterhouse. Mr. Wilson is a 1977 graduate of Houston Baptist University and pursued additional studies at Georgetown University.

Board Committees

The Board of Directors has created an Audit Committee that presently consists of Messrs. Schaffner and ~~DeGarmo~~McGuire. Mr. Schaffner serves as chairman of the Audit Committee. All members have a basic understanding of finance and accounting, and are able to read and understand fundamental financial statements. The board has determined that all members of our Audit Committee would meet the independence requirements of the American Stock Exchange if such standards applied to our company. The Board of Directors has also determined that based on education and work history, Mr. Schaffner meets the definition of an “Audit Committee Financial Expert” as established by the Securities and Exchange Commission. The audit committee's responsibilities include:

· appointing, approving the compensation of, and assessing the independence of our independent auditor; · overseeing the work of our independent auditor and approving the release of reports from our independent auditor; · reviewing and discussing with management and our independent auditor our annual and quarterly financial statements and related disclosures; · monitoring our internal control over financial reporting, disclosure controls and procedures, and code of business conduct and ethics; · discussing our risk management policies; · establishing policies regarding hiring employees from our independent auditor and procedures for the receipt and retention of accounting related complaints and concerns; · meeting independently with our independent auditor and management; and · preparing the audit committee report required by SEC rules to be included in our proxy statements.

·	overseeing the work of our independent auditor and approving the release of reports from our independent auditor;

·	reviewing and discussing with management and our independent auditor our annual and quarterly financial statements and related disclosures;

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·	monitoring our internal control over financial reporting, disclosure controls and procedures, and code of business conduct and ethics;

·	discussing our risk management policies;

·	establishing policies regarding hiring employees from our independent auditor and procedures for the receipt and retention of accounting related complaints and concerns;

·	meeting independently with our independent auditor and management; and

·	preparing the audit committee report required by SEC rules to be included in our proxy statements.

All audit services and all non-audit services, except de minimis non-audit services, must be approved in advance by the Audit Committee.

44The Board of Directors has created a Compensation Committee that presently consists of Messrs. Schaffner and McGuire. Mr. McGuire serves as chairman of the Compensation Committee. The Board of Directors has determined that all members of the Compensation Committee meet the independence requirements of the American Stock Exchange if such standards applied to our company. The Compensation Committee's responsibilities include:

~~The~~· ~~Board~~annually ofreviewing ~~Directors~~and ~~has~~approving ~~created~~corporate agoals ~~Compensation Committee that presently consists of Messrs. Schaffner~~ and ~~DeGarmo.~~objectives ~~Mr.~~relevant ~~DeGarmo~~to ~~serves~~compensation ~~as chairman~~ of the Compensation Committee. The Board of Directors has determined that all members of the Compensation Committee meet the independence requirements of the American Stock Exchange if such standards applied to our ~~company.~~chief ~~The~~executive ~~Compensation Committee's responsibilities include:~~officer;

· ~~annually reviewing and approving corporate goals and objectives relevant to compensation of our chief executive officer; ·~~ determining the compensation of our chief executive officer; · reviewing and approving, or making recommendations to our Board of Directors with respect to, the compensation of our other executive officers; · overseeing an evaluation of our senior executives; · overseeing and administering our cash and equity incentive plans; and · reviewing and making recommendations to our board with respect to director compensation.

·	reviewing and approving, or making recommendations to our Board of Directors with respect to, the compensation of our other executive officers;

·	overseeing an evaluation of our senior executives;

·	overseeing and administering our cash and equity incentive plans; and

·	reviewing and making recommendations to our board with respect to director compensation.

The Board of Directors does not have a separate nominating committee, and has determined that it is appropriate for the entire board to serve that function for the time being. Accordingly, Mr. O’Connor will participate in decisions respecting director nominees until an independent nominating committee is established. With respect to director nominees, the Board of Directors will consider nominees recommended by stockholders that are submitted in accordance with our By-Laws.

Corporate Governance

Our Board of Directors believes that sound governance practices and policies provide an important framework to assist them in fulfilling their duty to stockholders. Our Board of Directors is working to adopt and implement many "best practices" in the area of corporate governance, including separate committees for the areas of audit and compensation, careful annual review of the independence of our Audit and Compensation Committee members, maintenance of a majority of independent directors, and written expectations of management and directors, among other things.

Potential Conflicts of Interest

Our officers and directors are not full time employees of our company and are actively involved in other business pursuits. Accordingly, they may be subject to a variety of conflicts of interest. Since our officers and directors are not required to devote any specific amount of time to our business, they will experience conflicts in allocating their time among their various business interests.

Our officers and directors intend to comply with the requirements of Texas law, and believe they can avoid most potential conflicts of interest. If our officers and directors are subjected to an irreconcilable conflict of interest, they may elect to submit the issue for a vote of the disinterested stockholders, but they are not required to do so.

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Code of Business Conduct and Ethics

The Board of Directors has adopted a Code of Business Conduct and Ethics, which has been distributed to all directors, officers, and employees and will be given to new employees at the time of hire. The Code of Business Conduct and Ethics contains a number of provisions that apply principally to our President, Chief Financial Officer and other key accounting and financial personnel. A copy of our Code of Business Conduct and Ethics can be found under the "Investor Information" section of our website at www.biofuelspower.com. We intend to disclose any amendments or waivers of our Code of Business Conduct and Ethics on our website.

Indemnification of Officers and Directors

Our Articles of Incorporation allows us to indemnify our officers and directors to the fullest extent permitted by Texas law. The indemnification provisions are sufficiently broad to provide protection against monetary damages for breach or alleged breach of their duties as officers or directors, other than in cases of fraud or other willful misconduct. Our Articles of Incorporation also provide that, subject to specific exclusions required under Texas law, our directors will not have any personal liability to our company or our stockholders for monetary damages arising from a breach of fiduciary duty. Our bylaws require us to indemnify our officers and directors to the maximum extent permitted by Texas law. In addition, our bylaws require us to advance expenses to our officers and directors as incurred in connection with proceedings against them for which they may be indemnified. The SEC believes the indemnification of directors, officers and control persons for liabilities arising under the Securities Act is against public policy as expressed in the Securities Act and is therefore unenforceable.

ITEM 11 — EXECUTIVE COMPENSATION

Employment Agreements

Sam H. Lindsey, Jr., our interim CFO, is not a full-time employee and does not have a written employment agreement. Mr. Lindsey provides consulting services on a per diem basis

The following table provides summary information on the compensation paid to our interim CEO and interim Vice President Finance and interim CFO during the year ended December 31, ~~2012~~2013.

Summary Compensation Table
Name	~~Position~~	~~Year~~Position	~~Salary~~Year		Salary		~~Bonus~~		Bonus	~~Vested stock awards~~	Vested stock awards		~~All other compensation~~	All other compensation	Total compensation
Eric Gadd	Interim COO	2012	$	-0-				—		$	—			—	$	-0-
Steven McGuire		Managing Director	2014		$	-0-			—		$	—		—	$	-0-
Robert Wilson	~~Interim VP Finance~~	~~2012~~Interim VP Finance	$2014	~~-0-~~	$	-0-		—	—	$	—$	—		—	$	-0-
Sam Lindsey	~~Interim CFO~~	~~2012~~Interim CFO	$2014	~~22,500~~	$	22,500		—	—	$	—$	—		—	$	22,500

Equity-based Compensation During 2012 and 2011

We did not issue any stock options or other equity-based compensation to any of our officers or directors during the year ended December 31, ~~2012~~2014. On November 1, 2007, we issued a total of 1,250,000 shares of common stock to our directors, officers, principal consultants and employees. All of stock grants were valued at $1.25 per share for accounting purposes, an amount that represents our best estimate of the current fair market value of our shares. Under the terms of the stock grants, 50% of the grant shares vested immediately and the remaining 50% vest ratably at the rate of 5% per month over a period of 10 months from the date of grant. The following table identifies the principal recipients of the stock grants and summarizes the number and value of grant shares that have vested at March 31, 2008 and the number and value of grant shares that will vest over the next five months:

		Total Grant				Vested Portion				Future Vesting
Name	Position	Shares		Value		Shares		Value		Shares		Value
Fred O’Connor	Interim CEO		300,000	$	375,000		225,000	$	281,250		75,000	$	93,750
Robert Wilson	Interim VP		100,000	$	125,000		75,000	$	93,750		25,000	$	31,250
Alan Schaffner	Director		100,000	$	125,000		75,000	$	93,750		25,000	$	31,250
Richard DeGarmo	Director(2)		100,000	$	125,000		75,000	$	93,750		25,000	$	31,250
Robert A. Webb	Legal counsel		100,000	$	125,000		70,000	$	87,500	Balance forfeit (1)
J. Michael McGee	Consultant		100,000	$	125,000		70,000	$	87,500	Balance forfeit (1)
Steven McGuire	Manager		100,000	$	125,000		75,000	$	93,750		25,000	$	31,250
Other employees and consultants			350,000	$	437,500		262,500	$	328,125		87,500	$	109,375

(1)

Effective March 1, 2008, Messrs. Webb and McGee resigned from our board of directors and in connection therewith, 30,000 unvested grant shares owned by each of them were forfeited.

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2011 Executive Compensation Plan

This section contains a prospective discussion of the material elements of compensation that will be awarded to, earned by or paid to our three most highly compensated individuals on a go-forward basis. These individuals, who have not yet been retained by us, are referred to as the “Named Executive Officers.”

Compensation Decision-Making

The Compensation Committee Our Compensation Committee exercises the Board of Directors’ authority concerning compensation of the executive management team, non-employee directors and the administration of our stock-based incentive compensation plans. The Compensation Committee will typically meet in separate sessions independently of board meetings. The Compensation Committee will typically schedule telephone meetings as necessary to fulfill its duties. The Chairman will typically establish meeting agendas after consultation with other committee members and our CEO.

Role of Contracts Establishing Compensation When we identify individuals to assume the posts of Chief Executive Officer, Chief Financial Officer and Chief Operating Officer, we are likely to negotiate formal employment agreements that have terms of three to four years and contain express provisions relating to annual salaries, bonuses, equity incentives and other non-cash compensation. Our Compensation Committee will bear primary responsibility for negotiating the terms of such agreements and passing on the reasonableness thereof.

Role of Executives in Establishing Compensation We believe that our CEO and other members of management will regularly discuss our compensation issues with Compensation Committee members. In general, the Compensation Committee will have the sole authority to establish salary, bonus and equity incentives for our CEO in consultation with other members of the management team. Subject to Compensation Committee review, modification and approval, we believe our CEO will typically make recommendations respecting bonuses and equity incentive awards for the other members of the executive management team.

Other Compensation Policies With the assistance of the Compensation Committee and our management team, we developed a number of policies and practices that we plan to implement during 2008. Consistent with our compensation philosophies described below, our goal will be to provide executive officers with a compensation program that is competitive with other opportunities that were available to them.

We do not have a pre-established policy or target for the allocation of incentive compensation between cash bonuses and equity incentive compensation. The Compensation Committee will review surveys and other information considered relevant to determine the appropriate level and mix of incentive compensation for each executive officer and make a final decision in consultation with the executive officer. The portion of an executive’s total compensation that is contingent upon the Company’s performance will generally tend to increase commensurate with the executive’s position within the Company. This approach is designed to provide more upside potential and downside risk for those senior positions.

For 2012, we will endeavor to ensure that a substantial amount of each Named Executive Officer’s total compensation will be performance-based, linked to the Company’s operating performance, and over the executive’s tenure, derived its value from the market price of the Company’s common stock.

Our benefit programs are generally egalitarian. Our Named Executive Officers will not receive perquisites other than a monthly car allowance and participation without cost in our standard employee benefit programs, including medical and hospitalization insurance and group life insurance. We will attempt to ensure that both cash and equity components of total compensation are tax deductible, to the maximum extent possible.

Compensation Program

Compensation Program Objectives and Philosophy Our compensation philosophy is to maintain competitive pay practices that will help us attract, retain and reward the highest performers who are capable of leading us in achieving our strategic business objectives. To meet these goals, we use base salaries which are typically determined by employment contracts, performance-based bonuses and equity-based incentive awards, as appropriate, to reward and reinforce the value added contributions and attainment of performance objectives that enable us to meet our goals and create stockholder value. A significant element of our executive compensation policy is and will continue to be equity-based in order to emphasize the link between executive compensation and the creation of stockholder value as measured by the equity markets.

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We do not use external benchmarking data or comparable peer groups to establish competitive total compensation pay practices. We evaluate employees’ compensation on an annual basis and make changes accordingly. We target the overall pay structures to provide a reasonable level of assurance that we will be able to retain the services of our principal executive officers.

Compensation Program Design Our compensation program is designed to achieve our objectives of attracting, retaining and motivating employees and rewarding them for achievement that we believe will bring us success and create stockholder value. These programs are designed to be competitive with other employment opportunities that are available to our executives. A significant portion of the compensation for our Named Executive Officers includes equity awards that have extended vesting periods. The purpose of these awards is to serve as both a retention and incentive mechanism that will encourage recipients to remain with our Company and create value for both the award recipient and our stockholders.

Elements of Compensation

Compensation arrangements for the Named Executive Officers under our fiscal 2010 compensation program will typically include four components: (a) a base salary; (b) a cash bonus program; (c) the grant of equity incentives in the form of non-qualified stock options; and (d) other compensation and employee benefits generally available to all of our employees.

2007 Stock Incentive Plan

The Compensation Committee will administer the plan; decide which employees will receive incentive awards; make determinations with respect to the type of award to be granted; and make determinations with respect to the number of shares covered by the award. The Compensation Committee will also determine the exercise prices, expiration dates and other features of awards. The Compensation Committee will be authorized to interpret the terms of the plan and to adopt any administrative procedures it deems necessary. All decisions of the Compensation Committee will be binding on all parties. We will indemnify each member of the Compensation Committee for good faith actions taken in connection with the administration of the plan.

All of the options and restricted shares are subject to vesting requirements and the company has the right to cancel or repurchase at cost all unvested stock options or restricted shares at the time the recipient's employment or consulting relationship with the company is terminated.

Director Compensation

We expect our Board members to be actively involved in various aspects of our business ranging from relatively narrow Board oversight functions to providing hands-on guidance to our executives with respect to matters within their personal experience and expertise. We believe that the active involvement of all Board members in our principal business and policy decisions will increase the Board’s understanding of our needs and improve the overall quality of our management decisions.

Only independent directors will be compensated separately for service as Board members. While each of our directors received restricted stock grants in November 2007 as described above, none of our directors received any cash compensation for services rendered in their capacity as directors during the year ended December 31, ~~2011~~2013 or ~~2010~~2012. Each of our independent directors will receive the following compensation for the year ended December 31, ~~2012~~2013:

•· A basic annual retainer of $10,000 for service as a Board member; • A supplemental retainer of $5,000 for service as Chairman of the Audit Committee; • A supplemental annual retainer of $2,500 for service as a committee member; and • Reimbursement for all reasonable travel, meals and lodging costs incurred on our behalf.

·	A supplemental retainer of $5,000 for service as Chairman of the Audit Committee;

·	A supplemental annual retainer of $2,500 for service as a committee member; and

·	Reimbursement for all reasonable travel, meals and lodging costs incurred on our behalf.

ITEM 12 — SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED MATTERS

We had 31,442,760 shares of common stock issued and outstanding on the date of this annual report on Form 10-K. We have no outstanding convertible securities and no warrants or options that are presently exercisable or will become exercisable within 60 days. The following table sets forth information with respect to the beneficial ownership of our common stock for each of our executive officers and directors; all of our executive officers and directors as a group; and any other beneficial owner of more than 5% of our outstanding common stock

Except as indicated by footnotes, and subject to applicable community property laws, each person identified in the table possesses sole voting and investment power with respect to all common stock held by that person. The address of each named beneficial owner, unless indicated otherwise by footnote, is 20202 Hwy. 59N, Suite 210, Humble, Texas 77338.39

	Shares Beneficially Owned
	Number		Percent
David S. Holland, Sr. (1)		3,077,500		10.1	%
Alan Schaffner		1,161,668		3.8	%
Fred O’Connor		400,000		1.3	%
Robert Wilson		255,808		0.8	%
Richard DeGarmo		100,000		0.3	%
Directors and officers as a group		1,917,476		6.2	%

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~~(1)~~Except ~~David~~as S.indicated ~~Holland~~by footnotes, ~~Sr.~~and issubject ato ~~retired~~applicable ~~Pennzoil~~community ~~executive~~property ~~who~~laws, ~~provided~~each ~~substantial~~person ~~equity~~identified ~~financing~~in ~~for~~the ~~Texoga~~table inpossesses ~~its~~sole ~~early~~voting ~~stages~~ and ~~ultimately~~investment ~~became~~power ~~the~~with ~~largest~~respect ~~stockholder~~to ofall common stock held by that ~~company~~person. ~~Mr.~~The ~~Holland~~address ~~passed~~of ~~away~~each onnamed ~~January~~beneficial 5owner, ~~2013,,~~unless ~~and~~indicated ~~his~~otherwise ~~interest~~by footnote, is ~~now~~20202 ~~held~~Highway by59 ~~his~~North, ~~estate~~Suite 210, Humble, TX 77338.

	Shares Beneficially Owned
	Number		Percent
David S. Holland, Sr. (1)		3,077,500		8.9	%
Alan Schaffner		1,161,668		3.3	%
Robert Wilson		255,808		0.7	%
Directors and officers as a group		1,417,476		4.0	%

(1)

David S. Holland, Sr. is a retired Pennzoil executive who provided substantial equity financing for Texoga in its early stages and ultimately became the largest stockholder of that company. Mr. Holland became deceased on January 5, 2013 and his interest is now held by his estate.

There are no agreements, arrangements or understandings that will result in a change in control at any time in the foreseeable future.

48Section 16(a) beneficial ownership reporting compliance

Based solely on our review of the reports on Forms 3, 4, and 5 that were filed by our officers during the year ended December 31, 2006, we have determined that John L. Petersen, Sally A. Fonner, Rachel A. Fefer and Mark R. Dolan each failed to file a Form 3 to report their initial beneficial ownership of our shares. Our founders do not intend to file Form 4 to report their distributions of gift shares until the entire gift share distribution is completed. At the date of this report on Form 10-K, our founders have agreed to give a combined total of 224,000 gift shares to 448 family members, friends and business associates selected by them.

Except as set forth above, we are not aware of any director, officer or beneficial owner of more than 10% of any class of our equity securities that failed to file the forms required by Section 16(a) on a timely basis.

ITEM 13 — CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS AND DIRECTOR INDEPENDENCE

In November 2006, we agreed to become the general partner of and assume legal and operational responsibility for TBP-I and TBP-II. Our appointment as successor general partner of the two partnerships was submitted for the written consent of the limited partners and subsequently approved by the requisite 2/3 majority of the holders of limited partner interests on December 8, 2006 and January 12, 2007, respectively. Amended certificates of limited partnership to reflect our substitution as general partner were filed on January 14, 2007. In connection with the assignment of Texoga’s general partner interest to us all contracts necessary for the operation of the Oak Ridge North and Montgomery County facilities were assigned to us and Texoga has no further interest in those contracts. While we assumed all of Texoga’s rights and obligations as general partner of TBP-I and TBP-II, we did not issue any securities or pay any consideration to Texoga in connection with the assignments. As general partner of TBP-I and TBP-II, Texoga acted as the general contractor in connection with the construction of the Oak Ridge North and Montgomery County facilities. During 2007, we paid Texoga approximately $306,000 for construction services, labor and equipment used in connection with the installation of our Montgomery County facility. We believe the price and other material terms of our transactions with Texoga were comparable to or more favorable than the price and terms we could have negotiated with an unaffiliated third party.

In December 2006, we offered to exchange shares of our common stock for limited partner interests in the partnerships. In connection with the exchange offering, the partnership interests were valued at their $1,000 per unit cost to the limited partners and our common stock was valued at $0.67 per share. Since December 2006, we have issued 4,444,500 shares of our common stock to purchase 2,963 TBP-I units; 2,925,000 shares of our common stock to purchase 1,950 TBP-II units; and 353,592 shares of common stock upon conversion of $265,200 of notes we issued to purchase 312 TBP-I units. At the date of this annual report on Form 10-K, we have acquired all 3,500 units of limited partner interest in TBP-I and dissolved the partnership. We have also acquired 2,950 units of limited partnership interest in TBP-II which represents 84.2% of the total outstanding units.

In January 2007, we entered into a lease sharing arrangement with Texoga and SRC that ~~obligates~~obligated Texoga to contribute $18,940 per month to the cost of the leased space that ~~houses~~housed the executive offices for all three companies and ~~obligates~~obligated SRC to contribute an additional $14,680 per month as its share of the costs. In connection with the sublease, we pledged an $856,000 certificate of deposit as collateral security for the future rental obligations. During the year ended December 31, 2007, we received $58,040 from SRC, and the unpaid balances were carried as advances to Texoga and SRC. Since Texoga and SRC are both related parties and the collection of the unpaid balances is uncertain, we have fully impaired $345,400 of unpaid rent reimbursements from Texoga and SRC in our financial statements for the year ended December 31, 2007. We were able to negotiate a sublease of the office space that eliminated our future rental obligations and resulted in the release of the associated security deposit to us in 2008.

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During 2007 we asked SRC to make additional plant improvements to increase the efficiency of our operations. In connection therewith, we advanced approximately $62,000 to SRC to pay the cost of the required changes. Since SRC is a related party and collection of this advance is uncertain, we have fully impaired these advances to SRC in our financial statements for the year ended December 31, 2007.

Robert Wilson is an independent contractor who served as the interim CFO and now serves as VP-Finance of our company. Mr. Wilson is also a principal of M1-Energy Capital Securities, LLC, an NASD broker dealer that raised $7,000,000 in capital for TBP-I and TBP-II, and received $700,000 in cash commissions in connection therewith. In connection with our partnership exchange offerings and our sales of common stock for cash, M-1 received aggregate cash compensation of $225,000, together with 392,446 shares of our common stock, including 55,808 shares that were subsequently assigned to Mr. Wilson.

M1 Energy Risk Management LLC is a commodity advisory and brokerage firm that creates and manages customized commodities hedging programs. In connection with the commodity hedging activities described herein, M-1 Energy Risk Management received $107,750 in fees during 2007. While Mr. Wilson has no direct or indirect interest in M1 Energy Risk Management, the owners of that company are co-owners with Mr. Wilson of M1-Energy Capital Securities, LLC.

Director Independence

The Board of Directors has determined that ~~two~~one of our ~~three~~two directors would meet the independence requirements of the American Stock Exchange if such standards applied to our company. In the judgment of the board, Mr. ~~O’Connor~~McGuire does not meet such independence standards. In reaching its conclusions, the board considered all relevant facts and circumstances with respect to any direct or indirect relationships between the company and each of the directors, including those discussed under the caption "Certain Relationships and Related Transactions." The board determined that any relationships that exist or existed in the past between the company and each of the independent directors were immaterial on the basis of the information set forth in the above-referenced sections.

ITEM 14. — PRINCIPAL ACCOUNTING FEES AND SERVICES

Audit and Audit-Related Fees The aggregate fees billed to our company during 2012 by Clay Thomas, PC for audit fees and services to interim financial statements and filing of various documents with the SEC were $46,500.

ITEM 15. — EXHIBITS, FINANCIAL STATEMENT SCHEDULES AND REPORTS ON FORM 8-K

(a)(1) The following is a list of the financial statements filed as part of this report on Form 10-K.

Report of Independent Registered Public Accountant for the years ended December 31, 2012 and 2011	27
Balance Sheet as of December 31, 2012 and 2011	28
Statement of Operations for the years ended December 31, 2012 and 2011	29
Statement of Changes in Stockholders’ Equity for the years ended December 31, 2012 and 2011	30
Statement of Cash Flow for the years ended December 31, 2012 and 2011	31
Notes to Financial Statements	32

Report of Independent Registered Public Accountant for the years ended December 31, 2014 and 2013

Balance Sheet as of December 31, 2014 and 2013

Statement of Operations for the years ended December 31, 2014 and 2013

Statement of Changes in Stockholders’ Equity for the years ended December 31, 2014 and 2013

Statement of Cash Flow for the years ended December 31, 2014 and 2013

Notes to Financial Statements

(a)(2) The following is a list of the financial statement schedules filed as part of this report on Form 10-K.

None

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(a)(3) The following is a list of the Exhibits filed as part of this report on Form 10-K:

Exhibit
Number	~~Description~~	Description
3.1	~~Articles of Incorporation of Aegis Products Inc. (currently Biofuels Power Corporation) dated January 11, 2004~~	*Articles of Incorporation of Aegis Products Inc. (currently Biofuels Power Corporation) dated January 11, 2004	*
3.2	~~First Amendment to the Articles of Incorporation of Aegis Products Inc. (currently Biofuels Power Corporation) dated December 1, 2006~~	*First Amendment to the Articles of Incorporation of Aegis Products Inc. (currently Biofuels Power Corporation) dated December 1, 2006	*
3.3	~~Curative Amendment to the Articles of Incorporation of Biofuels Power Corp. dated November 12, 2007~~	*Curative Amendment to the Articles of Incorporation of Biofuels Power Corp. dated November 12, 2007	*
3.4	~~By-laws of Biofuels Power Corporation~~	*By-laws of Biofuels Power Corporation	*
4.1	~~Form of Common Stock Certificate~~	*Form of Common Stock Certificate	*
4.2	~~Form of 12.5% Senior Convertible Debenture Due 2011~~	*Form of 12.5% Senior Convertible Debenture Due 2011	*
10.1	~~2007 Stock Incentive Plan~~	*2007 Stock Incentive Plan	*
10.2	~~Ground Lease for 1/2-half acre parcel in Oak Ridge North Texas~~	*Ground Lease for 1/2-half acre parcel in Oak Ridge North Texas	*
10.3	~~Ground Lease for 1.5 acre parcel in Montgomery County Texas~~	*Ground Lease for 1.5 acre parcel in Montgomery County Texas	*
10.4	~~Master Real Estate Lease for executive offices located at 10003 Woodloch Forest Drive, Suite 900, The Woodlands, Texas, 77380~~	*Master Real Estate Lease for executive offices located at 10003 Woodloch Forest Drive, Suite 900, The Woodlands, Texas, 77380	*
10.5	~~Rent Sharing Agreement for executive offices located at 10003 Woodloch Forest Drive, Suite 900, The Woodlands, Texas, 77380~~	*Rent Sharing Agreement for executive offices located at 10003 Woodloch Forest Drive, Suite 900, The Woodlands, Texas, 77380	*
10.6	~~Limited Partnership Agreement of Texoga Biofuels Partners 2006-II, as amended~~	*Limited Partnership Agreement of Texoga Biofuels Partners 2006-II, as amended	*
10.7	~~Power Marketing Agreement with Fulcrum Power Services, LP,~~	*Power Marketing Agreement with Fulcrum Power Services, LP,	*
10.8	~~Interconnect Agreement With Centerpoint Energy for Oak Ridge North facility~~	*Interconnect Agreement With Centerpoint Energy for Oak Ridge North facility	*
10.9	~~Interconnect Agreement With Entergy for Montgomery County facility~~	*Interconnect Agreement With Entergy for Montgomery County facility	*
14.1	~~Code of Business Conduct and Ethics~~	*Code of Business Conduct and Ethics	*
31.1	~~Certification of Chief Executive Officer Pursuant to Rule 13a-14(a)~~	~~Exhibit~~Certification ~~31.1~~of Chief Executive Officer Pursuant to Rule 13a-14(a)	Exhibit 31.1
31.2	~~Certification of Chief Financial Officer Pursuant to Rule 13a-14(a)~~	~~Exhibit~~Certification ~~31.2~~of Chief Financial Officer Pursuant to Rule 13a-14(a)	Exhibit 31.2
32.1	~~Statement of Chief Executive Officer Pursuant to U.S.C. Title 18, Section 1350~~	~~Exhibit~~Statement 32of Chief Executive Officer Pursuant to U.1S.C. Title 18, Section 1350	Exhibit 32.1
32.2	~~Statement of Chief Financial Officer Pursuant to U.S.C. Title 18, Section 1350~~	~~Exhibit~~Statement 32of Chief Financial Officer Pursuant to U.2S.C. Title 18, Section 1350	Exhibit 32.2
101.INS		XBRL Instance Document
101.SCH		XBRL Taxonomy Extension Schema Document
101.CAL		XBRL Taxonomy Extension Calculation Linkbase Document
101.DEF		XBRL Taxonomy Extension Definition Linkbase Document
101.LAB		XBRL Taxonomy Extension Label Linkbase Document
101.PRE		XBRL Taxonomy Extension Presentation Linkbase Document

* Incorporated by reference to Form 10-SB Registration Statement filed January 11, 2008.

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SIGNATURES

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

BIOFUELS POWER CORPORATION

By : /s/ ~~Rich~~Steve ~~DeGarmo~~ McGuire Steve McGuire, Managing Director Date: April 15, 2015

Rich DeGarmo, Managing Director

Date April 22, 2013

Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities and on the dates indicated.

By: /s/ Alan Schafner Alan Schafner	Director	Date April 22, 2013
By: /s/ Alan Schafner		Director	Date May 1, 2015
By: /s/ Rich DeGarmo Rich DeGarmo	Director	Date April 22, 2013
Alan Schafner
By: /s/ Sam H. Lindsey, Jr. Sam H. Lindsey, Jr.	Chief Financial Officer (Principal Financial Officer and Principal Accounting Officer)	Date April 22, 2013
By: /s/ Steve McGuire		Director	Date May 1, 2015
Steve McGuire
By: /s/ Sam H. Lindsey, Jr.		Chief Financial Officer	Date May 1, 2015
Sam H. Lindsey, Jr.		(Principal Financial Officer and Principal Accounting Officer)

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