10-K 1 cpwr_form10k.htm OCEAN THERMAL ENERGY CORP. FORM 10K Blueprint
 

 
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
 _________________
FORM 10-K
  _________________
 
☒ ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the fiscal year ended December 31, 2017
or
☐ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the transition period from _____________ to ___________________
 
Commission File No. 033-19411-C
 
OCEAN THERMAL ENERGY CORPORATION
(Exact name of registrant as specified in its charter)
 
Nevada
20-5081381
(State or other jurisdiction of
incorporation or organization)
(I.R.S. Employer
Identification No.)
 
800 South Queen Street, Lancaster, PA 17603
(Address of principal executive offices, including Zip Code)
 
717-299-1344
(Registrant’s telephone number, including area code)
 
 
 
Securities Registered pursuant to Section 12(b) of the Act: None
 
Securities Registered pursuant to Section 12(g) of the Exchange Act: None
 
Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.   Yes ☐   No ☒
 
Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or 15(d) of the Act.   Yes ☐   No ☒
 
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.  Yes ☒   No ☐
 
Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Website, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes ☒  No ☐
 
Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K (§229.405 of this chapter) 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.
 
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company" in Rule 12b-2 of the Exchange Act.
 
Large accelerated filer
Accelerated filer
Non-accelerated filer
☐ (Do not check if a smaller reporting company)
Smaller reporting company
 
 
Emerging growth company
 
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Act). Yes ☐ No ☒
 
As of November 20, 2017, the aggregate market value of the voting and non-voting common equity held by non-affiliates of the registrant was $20,049,635 based on the closing price of the registrant’s common stock as reported by OTCMarkets.com on such date of $0.20 per share. The registrant has elected to use November 20, 2017 as the calculation date as, on June 30, 2017 (the last business day of the registrant’s most recently completed second fiscal quarter), the registrant lacked an established public trading market necessary to make an accurate calculation. November 20, 2017 was the first such day that more than limited or sporadic quotations existed on the registrant’s common equity.
 
As of March 20, 2018, there were 122,672,247 shares of the registrant’s common stock outstanding, par value $0.001.
 
DOCUMENTS INCORPORATED BY REFERENCE: None
 

 
 
TABLE OF CONTENTS
PART I

ITEM 1. BUSINESS.
ITEM 1A. RISK FACTORS.
10
ITEM 1B. UNRESOLVED STAFF COMMENTS.
ITEM 2. PROPERTIES.
16
ITEM 3. LEGAL PROCEEDINGS.
ITEM 4. MINE SAFETY DISCLOSURES.
16
PART II

ITEM 5. MARKET FOR REGISTRANTS COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES.
ITEM 6. SELECTED FINANCIAL DATA.
18
ITEM 7. MANAGEMENTS DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS.
18
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK.
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA.
21
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE.
ITEM 9A. CONTROLS AND PROCEDURES.
ITEM 9B. OTHER INFORMATION
PART III

ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE.
ITEM 11. EXECUTIVE COMPENSATION
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS
26
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, DIRECTOR INDEPENDENCE.
ITEM 14. PRINCIPAL ACCOUNTING FEES AND SERVICES.
PART IV
ITEM 15. EXHIBITS, FINANCIAL STATEMENT SCHEDULES.
 
 
 
 
Throughout this report, unless otherwise designated, the terms “we,” “us,” “our,” “the Company” and “our company” refer to Ocean Thermal Energy Corporation, a Nevada corporation. All amounts in this report are in U.S. Dollars, unless otherwise indicated.
 
FORWARD-LOOKING STATEMENTS
 
This Annual Report on Form 10-K contains “forward-looking statements,” as that term is defined under the Private Securities Litigation Reform Act of 1995. The use of words such as “anticipates,” “estimates,” “expects,” “intends,” “plans” and “believes,” among others, generally identify forward-looking statements. These forward-looking statements are based on our management's expectations and assumptions about future events as of the date of this Annual Report on Form 10-K, which are inherently subject to uncertainties, risks and changes in circumstances that are difficult to predict. Forward-looking statements include statements about our expectations, beliefs or intentions regarding our product offerings, business, financial condition, results of operations, strategies or prospects. You can identify forward-looking statements by the fact that these statements do not relate strictly to historical or current matters. Rather, forward-looking statements relate to anticipated or expected events, activities, trends or results as of the date they are made. Because forward-looking statements relate to matters that have not yet occurred, these statements are inherently subject to risks and uncertainties that could cause our actual results to differ materially from any future results expressed or implied by the forward-looking statements. Many factors could cause our actual activities or results to differ materially from the activities and results anticipated in forward-looking statements. These forward-looking statements are only predictions and reflect our views as of the date they are made with respect to future events and financial performance. We undertake no obligation to update, and we do not have a policy of updating or revising, these forward-looking statements.
 
 
 
 
PART I
 
ITEM 1. BUSINESS.
 
Overview
 
OCEES International Inc. (“OCEES”) was formed under the laws of Hawaii on January 21, 1998. Ocean Thermal Energy Corporation (“OTE Delaware”) was a Delaware corporation formed on October 18, 2010. In 2011, OCEES and OTE Delaware entered into a share exchange agreement. The transaction was treated as a merger of entities under common control as 100% of the stockholders of OCEES exchanged their shares for 100% of the outstanding shares of OTE Delaware.
 
OTE Delaware used its proprietary technology to develop, build, own, and operate renewable energy systems, primarily in the Eastern and Western Caribbean Islands.
 
On December 17, 2013, Broadband Network Affiliates, Inc. (“BBNA”), a Nevada Corporation, changed its state domicile and became a Delaware Corporation. On December 23, 2013, BBNA entered into a merger agreement with OTE Delaware, which was effective December 31, 2013. Upon completion of the merger, BBNA changed its name to Ocean Thermal Energy Corporation (“OTE”) and the former OTE Delaware ceased to exist. The transaction was treated as a reverse merger and recapitalization by OTE Delaware.
 
The Company previously operated under the corporate name of TetriDyn Solutions, Inc. (“TetriDyn”). On March 10, 2017, TetriDyn entered into an Agreement and Plan of Merger (the “Merger Agreement”) with OTE. On May 9, 2017, TetriDyn consummated the acquisition of all outstanding equity interests of OTE pursuant to the terms of the Merger Agreement, with a newly-created Delaware corporation that is wholly-owned by TetriDyn (“TetriDyn Merger Sub”), merging with and into OTE (the “Merger”) and OTE continuing as the surviving corporation and a wholly-owned subsidiary of TetriDyn. Effective upon the consummation of the Merger (the “Closing”), the OTE Stock issued and outstanding or existing immediately prior to the Closing of the Merger was converted at the Closing into the right to receive newly issued shares of TetriDyn common stock. As a result of the Merger, TetriDyn succeeded to the business and operations of OTE. In connection with the consummation of the Merger and upon the consent of the holders of a majority of the outstanding common shares, TetriDyn filed with the Nevada Secretary of State an amendment to its articles of incorporation changing its name to “Ocean Thermal Energy Corporation”.
 
Our Business
 
The Company develops projects for renewable power generation, desalinated water production, and air conditioning using proprietary intellectual property designed and developed by its own experienced oceanographers, engineers, and marine scientists. Plants using its technologies are designed to extract energy from the temperature difference between warm surface ocean water and cold deep seawater at a depth of approximately 3,000 feet. We believe these technologies provide practical solutions to mankind’s fundamental needs for sustainable, affordable energy; desalinated water for domestic, agricultural, and aquaculture uses; and cooling, all without the use of fossil fuels.
 
Ocean Thermal Electrical Conversion, known in the industry as “OTEC”, power plants are designed to produce electricity. In addition, some of the seawater running through an OTEC plant can be desalinated efficiently, producing fresh water for agriculture and human consumption.
 
Seawater Air Conditioning, known in its industry as SWAC, plants are designed to use cold water from ocean depths to provide air conditioning for large commercial buildings or other facilities. This same technology can also use deep cold water from lakes, known as Lake Water Air Conditioning or LWAC.
 
Both OTEC and SWAC systems can be engineered to produce desalinated water for potable, agricultural, and fish farming/aquaculture.
 
Many applications of technologies based on ocean temperature differences between surface and deep seawater have been developed at the Natural Energy Laboratory of Hawaii Authority, or NELHA, test facility (http://nelha.hawaii.gov), including applications for desalinated seawater, fish-farming, and agriculture. We believe our proprietary advances to existing technologies developed by others in the industry enhance their commercialization for the plants we proposed to develop.
 
The Company has recruited a scientific and engineering team that includes oceanographers, engineers, and marine scientists who have worked for a variety of organizations since the 1970s on several systems based on extracting the energy from the temperature differences between surface and deep seawater, including projects by NELHA, the Argonne National Laboratory (http://www.anl.gov), and others. Note: All URL addresses in this Information Statement are inactive textual references only. Our executive team members have complementary experience in leading engineering and technical companies and projects from start-up to commercialization.
 
In addition, we expect to use OTE’s technology in the development of OTEC EcoVillage, which should add significant value to our existing line of business. We will facilitate the development of sustainable living communities by creating ecologically sustainable “OTEC EcoVillage” powered by 100% fossil-fuel free electricity. In the development, buildings will be cooled by energy efficient and chemical free systems, and water will be produced for drinking, aquaculture, and agriculture onsite. The OTEC EcoVillage project consists, in part, of an OTEC plant which will provide all power and water to about 400 residences, a hotel, and shopping center, as well as models of sustainable agriculture, food production, and other economic developments. Each sale of luxury EcoVillage residences will support the development of environmentally responsible affordable communities in tropical and subtropical regions of the world (Affordable Communities), currently in development. OTEC EcoVillage will be the first development in the world offering a net-zero carbon footprint. This will be OTE’s pilot project, launched to prove the viability of OTEC technology to provide affordable renewable energy for entire communities. The Company believes this $700 million project could be highly profitable and generate significant value for its shareholders. The U.S. Virgin Islands’ Public Service Commission has granted OTE regulatory approval for an OTEC plant, and OTE has identified the specific plots of land for the site. The first draft of the Master Plan for the entire development has been completed.
 
 Our Vision
 
Our vision is to bring these technologies to tropical and subtropical regions of the world where about 3 billion people live. Our market includes 68 countries, 29 territories with suitable sea depth, shore configuration, and market need, we plan to be the first company in the world to design and build a commercial scale OTEC plant and, to that end, has several projects in the planning stages. Our initial markets and potential projects include several U.S. Department of Defense bases situated in the Asia Pacific and other regions where energy independence is crucial. Currently, we have projects in various planning and development stages in the Caribbean, the South Pacific, Asia, Zanzibar, Guam and other island locations.
 
 
1
 
 
Our Technology
 
OTEC is a self-sustaining energy source, with no supplemental power required to generate continuous (24/7) electricity. It works by converting heat from the sun, which has warmed ocean surface water, into electric power, and then completing the process by cooling the plant with cold water from deep in the ocean. The cold water can also be used for very efficient air conditioning and desalinated to produce fresh water. OTEC has worked in test settings where there exists a natural temperature gradient of 20 degrees Celsius or greater in the ocean. We believe OTEC can deliver sustainable electricity in tropical and subtropical regions of the world at rates approximately 20-40% lower than typical costs for electricity produced by fossil fuels in those markets.
 
Further, we believe that a small, commercial OTEC plant could offer competitive returns even in a market where the cost of electricity is as low as $0.30 per kilowatt-hour, or kWh. For example, the Inter-American Development Bank, an international bank providing development financing in Latin America and the Caribbean, reports that energy prices for hydrocarbon-generated power during 2010-2012 for 15 Caribbean countries averaged $0.33 per kWh, with a high of $0.43 per kWh in Antigua and Barbados. For the U.S. Virgin Islands, Water and Power Authority of the Virgin Islands reported that as of February 1, 2017 the average price for electricity for commercial customers was nearly $0.40 per kWh. We believe that we have an opportunity to offer base-load energy (the amount of energy required to meet minimum requirements) pricing that is better than our customer’s next best alternative in the markets where electricity costs are $0.30 or more per kWh.
 
Technology advancements have significantly brought the capital costs of OTEC down to make it competitive compared to traditional energy sources in the OTEC markets. Technology improvements including larger diameter seawater pipes manufactured with improved materials, increased pumping capabilities from OTEC depths, better understanding of material requirements in deep ocean environment, more experience in deep water pipeline and cable installation techniques, and more accurate sea bottom mapping technology which is required for platform positioning and pipe installation. The cold-water pipes at a demonstration site in Hawaii have been in continuous operation for more than 20 years and the technology has improved significantly since the Hawaiian installation.
 
We estimate that a small OTEC plant that delivers 13 million watts (megawatts or MW) per hour for 30 years would currently cost approximately $350 million. This is the plant size that we typically propose for our initial target markets to meet 20% or more of their current demand for electricity and a large portion of their need for fresh drinking water and agricultural water. OTEC has been proven in test settings at NELHA, where a Department of Energy-sponsored OTEC plant operated successfully throughout the 1990s to produce continuous, affordable electricity from the sea without the use of fossil fuels. Spin-off technologies of desalination and seawater cooling, developed from the OTEC plant at NELHA, have also become economically and technical feasible.
 
Finally, we believe the decreasing supply and increasing cost of fossil-fuel-based energy has intensified the search for renewable alternatives. We further believe that renewable energy sources, although traditionally more expensive than comparable fossil-fuel plants, have many advantages, including increased national energy security, decreased carbon emissions, and compliance with renewable energy mandates and air quality regulations. We believe these market forces will continue and potentially increase. In remote islands where shipping costs and limited economies of scale substantially increase fossil-fuel-based energy, renewable energy sources may be attractive. Many islands contain strategic military bases with high-energy demands that we believe would greatly benefit from a less expensive, reliable source of energy that is produced locally, such as OTEC.
 
SWAC is a process that uses cold water from locations such as the ocean or deep lakes to provide the cooling capacity to replace traditional electrical chillers in an air conditioning system. SWAC applications can reduce the energy consumption of a traditional air-conditioning system by as much as 90%. Even when the capital cost amortization of building a typically sized SWAC system providing 9,800 tons of cooling ($140-$150 million) are taken into account, SWAC can save the customer approximately 25-40% when compared to conventional systems—we estimate savings can be as high as 50% in locations where air temperatures and electricity costs are high. Cooling systems using seawater or groundwater for large commercial structures are in use at numerous locations developed and operated by others worldwide, including Heathrow Airport, UK; Finland (Google Data Center); Cornell University, NY; Stockholm, Sweden; and the City of Toronto, Canada.
 
 
2
 
 
How Our Technology Works
 
OTEC uses the natural temperature difference between cooler deep ocean water at a depth of approximately 3,000 feet and warmer shallow or surface water to create energy. An OTEC plant project involves installing about 6.0 feet diameter, deep-ocean intake pipes (which can readily be purchased), together with surface water pipes, to bring seawater onshore. OTEC uses a heat pump cycle to generate power. In this application, an array of heat exchangers transfer the energy from the warm ocean surface water as an energy source to vaporize a liquid in a closed loop, driving a turbine, which in turn drives a generator to produce electricity. The cold deep ocean water provides the required temperature to condense vapor back into a liquid, thus completing the thermodynamic cycle, which is constantly and continuously repeated. The working fluid is typically ammonia, as it has a low boiling point. Its high hydrogen density makes ammonia a very promising green energy storage and distribution media. Among practical fuels, ammonia has the highest hydrogen density, including hydrogen itself, in either its low temperature, or cryogenic, and compressed forms. Moreover, since the ammonia molecule is free of carbon atoms (unlike many other practical fuels), combustion of ammonia does not result in any carbon dioxide emissions. The fact that ammonia is already a widely produced and used commodity with well-established distribution and handling procedures allows for its use as an alternative fuel. This same general principle is used in steam turbines, internal combustion engines, and, in reverse, refrigerators. Rather than using heat energy from the burning of fossil fuels, OTEC power draws on temperature differences of the ocean caused by the sun’s warming of the ocean’s surface, providing an unlimited and free source of energy.
 
OTEC and SWAC infrastructure offers a modular design that facilitates adding components to satisfy customer requirements and access to a sufficient supply of cold water. These components include reverse-osmosis desalination plants to produce drinkable water, bottling plants to commercialize the drinkable water, and off-take solutions for aquaculture uses (such as fish farms), which benefit from the enhanced nutrient content of deep ocean water. A further advantage of a modular design is that, depending on the patterns of electricity demand and output of the OTEC plant, a desalination plant can be run using the excess electricity capacity.
 
OnShore OTEC Plant
 
Currently, OTEC requires a minimum temperature difference of approximately 20 degrees Celsius to operate, with each degree greater than this increasing output by approximately 10% to 15%. OTEC has potential applications in tropical and subtropical zones. OTEC is particularly well suited for tropical islands and coastal areas with proximate access to both deep water and warm surface water. These communities are typically subject to high and fluctuating energy costs ranging from $0.28-$0.75 per kWh, as they rely on importing fossil fuels for power generation. Data from the National Renewable Energy Laboratory of the U.S. Department of Energy website indicated that at least 68 countries and 29 territories around the globe appear to meet these criteria.
 
The world’s largest OTEC power plant to date is operational at the NELHA facility in Hawaii and is connected to the electrical grid. It provides base-load electricity produced by OTEC to about 150 homes. Around the world, a couple of other successful developmental and experimental plants have been built, and the U.S. National Oceanic and Atmospheric Administration, or NOAA, has stated that: “The qualitative analysis of the technical readiness of OTEC by experts at this workshop suggest that a <10 MWe floating, closed-cycle OTEC facility is technically feasible using current design, manufacturing, deployment techniques and materials.” We believe that we have sufficient skill and knowledge to now commercialize 5-MW to 30-MW land-based OTEC plants, using off-the-shelf components, including the cold-water piping.
  
SWAC (or LWAC) is a significantly more cost-effective and environmentally friendly way to implement air-conditioning using cold water sourced from lakes or, analogous with OTEC, deep ocean water, rather than from an electric chiller. Comparing Federal Energy Management Program engineering efficiency requirements of approximately 0.94 kilowatts of electricity per ton of cooling capacity with our own engineering estimates of 0.09 kilowatts of electricity per ton of cooling capacity, as calculated by DCO Energy, our engineering, procurement, and construction partner, we estimate that SWAC systems can reduce electricity consumption by up to 80-90% when compared to conventional systems. Therefore, OTE believes such energy reductions may make SWAC systems well-suited for large structures, such as office complexes, medical centers, resorts, data centers, airports, and shopping malls. We believe that other SWAC plants we may develop will likely achieve similar efficiencies. There are examples of proven successful SWAC/LWAC systems in use, including a large 79,000-ton system used to cool buildings in the downtown area of the City of Toronto, Canada; Google’s data center in Finland operates a SWAC system that uses waters from the Baltic Sea to keep servers cool; and a system with more than 18,000 tons of cooling is in operation at Cornell University, Ithaca, New York.
 
 
3
 
 
OTEC Versus Other Energy Sources
 
The construction costs of power plants using any technology are much higher in remote locations, such as tropical islands, than on the mainland of the United States, principally due to the need to transport materials, components, and other construction materials, supplies, and labor not available locally. There are also considerations that make those other technologies less attractive in those areas. We believe the consistency of OTEC over its life provides clear advantages over other generation technology in the tropical and subtropical markets, because its base-load power (available at all times and not subject to fluctuations throughout the day) is an important asset to the small transmission grid, which is typical in these regions.
 
Combined-cycle natural gas plants typically need to be capable of generating several hundred MWs to attain the lower cost per kW installed values to make the plant economically feasible. Tropical locations do not have large enough grids and market demand to make that plant size reasonable. Further, tropical locations frequently do not have domestic fuel supplies, requiring fuel to be imported. In order to import natural gas, it must be liquefied for shipment and then vaporized at the location. There are initial cost and public safety concerns with such facilities. In addition, gas-fired plants emit undesirable nitrogen oxide, carbon dioxide, and volatile organic compounds.
 
Solar applications continue to increase as the cost and effectiveness of photovoltaic panels improve. However, we estimate that the cost to install solar panels in tropical regions remains high. Beyond the issues with shipping and labor costs that all construction must overcome, the design and building code requirements are tougher in storm-prone areas subject to potential wind damage from hurricanes, earthquakes, and typhoons than are typically encountered in mainland non-tropical installations. Support structures must be more substantial in order to hold the solar panels in place in case of hurricane-force winds. Solar power, like wind power, places substantial stress on an electrical grid. Since the input of both of these sources is subject to weather conditions, they cannot be considered a reliable supply of power, and back-up capacity is necessary. Further, instantaneous changes in output due to sporadic cloud cover create transient power flow to the grid, creating difficulties in maintaining proper voltages and stability. OTEC is a stabilizing source to the grid, providing constant and predictable power, and has no emissions. The ability of OTEC to provide constant, continuous power is a large benefit as compared to any of the other renewable options available.
 
Our estimated price of OTEC-generated power of approximately $0.30 per kWh under current economic conditions, which can be as low as $0.18 net per kWh with maximum efficiency and revenue from water production, is also constant both throughout the year and over a plant’s life. OTEC’s power price, determined almost entirely by the amortization of its initial cost, is a protection against inflation and rising interest rates, which greatly affect coal and oil. Customers in our target markets currently pay from $0.35 to as high as $0.60 per kWh for power from coal and oil-fueled power plants. However, imported fuels are subject to price volatility that has a direct impact on the cost of electricity and adds operating risk during the life of a plant. The fuel handling to allow for the shipping, storage, and local transport is expensive, a potential source of damaging fuel spills, and a basis for environmental concerns. Fossil-fuel plants create pollution, emit carbon dioxide, and are visually unappealing, which is of particular concern in tropical areas renowned for their clear, pristine air and beauty. We project OTEC can save these markets up to 40%, compared to their current electrical costs, and when revenues from fresh drinking water, aquaculture, and agriculture production are considered, the justification is even more compelling.
 
Overview of the Market and the Feasibility of OTEC in Current Market Conditions
 
We believe that OTEC is now an economically, technologically, and environmentally competitive power source, especially for developing or emerging countries in certain tropical and subtropical regions contiguous to oceans. Our natural target markets are communities in countries around the Caribbean, Asia, and the Pacific. These locations are typically characterized by limited infrastructure, high-energy costs, mostly imported or expensively generated electricity, and frequently with significant fresh water and food shortages. These are serious limitations on economic development, which we believe our OTEC technology can address.
  
 
4
 
 
Data presented to the Sustainable Use of Oceans in the Context of the Green Economy and the Eradication of Poverty workshop in Monaco in 2011 by Whitney Blanchard of the Office of Ocean and Coastal Resource Management, National Oceanic and Atmospheric Administration, show that at least 98 nations and territories using an estimated 5 terawatts of potential OTEC net power are candidates for OTEC-power systems. Blanchard specifically notes that Hawaii, Guam, Florida, Puerto Rico, and the U.S. Virgin Islands are suitable for OTEC.
 
Over the past decade, there have been substantial changes that we believe have now made the commercialization of OTEC economically, technologically, and environmentally feasible. First and foremost is the price of oil, which until early 2014 traded at prices ranging from approximately $75 to $120 per barrel, since dropping to $50 per barrel or lower. According to www.oil.com, on January 3, 2018, oil traded at approximately $66.40 per barrel, as quoted at Brent, the leading global price benchmark for Atlantic basin crude oils. Even with current relatively low oil prices, developers of oil-fired power plants must model the economic performance of their plants over a useful life of 20 or more years, so they remain vulnerable to future oil price increases. The U.S. Energy Information Administration predicts increasing oil prices as a result of a combination of higher demand for liquid fuels and lower global crude oil supply in nations not included in Organisation for Economic Co-operation and Development. The U.S. Energy Information Administration predicts Brent crude oil prices will rise to between $76 and $252 per barrel (2013 dollars) in 2040 depending on demand and supply. It is generally accepted within the OTEC community that OTEC approaches competitive pricing when oil exceeds $40 per barrel. With OTEC power, customers can decouple the price of electricity from the price of oil.
 
The International Energy Agency’s 2015 World Energy Outlook expects liquid natural gas export capacity to grow rapidly in the short term, with major new sources of supply coming mostly from Australia and the United States.
 
Liquid natural gas prices have collapsed, in part because demand is turning out weaker than some previously anticipated. Additionally, many rules and regulations are in effect to mitigate the environmental issues associated with liquid natural gas extraction, transportation, and storage, adding significant costs.
 
According to the U.S. Environmental Protection Agency, the electric power sector accounted for 30% of total greenhouse gas emissions by the United States in 2014. Greenhouse gas emissions from electricity have increased by about 12% since 1990 as electricity demand has grown and fossil fuels have remained the dominant source for generations.
 
Fossil-fuel-fired power plants are a significant source of domestic carbon dioxide emissions, the primary cause of global warming. To generate electricity, fossil-fuel-fired power plants use natural gas, petroleum, coal, or any form of solid, liquid, or gaseous fuel derived from such materials.
 
The United States, along with many other countries including the United Kingdom and The Netherlands, have agreed or proposed either to shut down or to substantially reduce all of their coal-burning power plants over the next few years.
 
Scientific American, a respected U.S. scientific journal, recently reported that scientists have determined that both money and lives would be saved if rising fossil-fuel and biofuel emissions that are warming the planet are stopped and power generation is switched to an entirely renewable energy system.
 
Many countries today, including the United States, are concerned with environmental issues caused by fossil-fuel generated power. At the Sustainable Innovation Forum, a business-focused event held in Paris, France, in late 2015, cross-sector participants from business, government, finance, the United Nations, non-governmental organizations, and civil society met to create opportunities to bolster business innovation and bring scale to the emerging green economy.
 
The international concern about the harmful effects of climate change led to the negotiation of the Paris Agreement in December 2015 as the culmination of the 2015 United Nations Climate Change Conference. On October 5, 2016, the threshold for entry into force of the Paris Agreement was achieved, when it was ratified by at least 55 countries that together represent 55% of the global greenhouse emissions. The agreement entered into force 30 days later on November 4, 2016. The agreement provides for members to reduce their carbon output as soon as possible and to do their best to keep global warming to no more than two degrees Celsius, or 3.6 degrees Fahrenheit. In order to achieve the desired results, there would have to be a worldwide reduction in emissions from fossil fuels and a shift to renewable resources.
  
We believe the ongoing concern about environmental issues and the price instability of fossil-fuel prices are motivation for increased commercial interest in OTEC, renewed activity in the commercial sector, and increased interest among communities and agencies that recognize the potential benefits of this technology, including the U.S. Department of Defense and U.S. Department of the Interior territories. In the last four years, several large companies have used their OTEC technology experience to introduce OTEC systems worldwide, supporting the argument that the technology is now at the point where it can be introduced at a commercial level:
 
 
5
 
 
In June 2014, the French companies, Akuo Energy and DCNS (now Naval Energies), were funded to construct and install a number of OTEC plants adding up to 16 MWs of power generation outside the coastline of Martinique in the Caribbean. This is by far the biggest OTEC project announced to date, and the European Union has allocated €72 million (about $82 million at current exchange rates) for this purpose. DCNS (now Naval Energies), is our teaming partner for potential projects in the Caribbean.
 
Since early 2014, we have begun working with several industrialized and developing countries for investigating suitable OTEC sites, infrastructural solutions, and funding opportunities. These include the U.S. Virgin Islands, The Bahamas, Cayman Islands, and other countries.
 
Lockheed Martin has designed a 10-MW OTEC plant and has partnered with the China-based Reignwood Group, stated its intent to build the plant. According to a recent Lockheed Martin press release: “Just one 10-megawatt OTEC plant could provide reliable, clean energy for approximately 10,000 people; replace the burning of 50,000 barrels of oil; and eliminate the release of 80,000 tons of carbon dioxide per year into the atmosphere.”
 
Two non-governmental organizations promoting OTEC have been created in recent years: OTEC Foundation (based in The Netherlands) and OTEC Africa (based in Sweden).
 
In 2014, the world’s first international conference dedicated to OTEC was held in Borås, Sweden. A conference report was published.
 
New technological advances for larger and more robust deep seawater pipes and more efficient and cost-effective heat exchangers, pumps, and other components have, in our opinion, further improved the economics for OTEC.
 
Many countries, including a large number of Caribbean nations, now have renewable energy standards and are looking at ways to reduce their carbon footprint, decouple the price of electricity from the volatile price of oil, and increase energy security. Along with these countries, we are aware that Hawaii, U.S. territories, and the U.S. Department of Defense are looking at OTEC as a possible source of renewable energy and water for drinking, fish farming, and agriculture.
 
The NELHA demonstration OTEC plant in Hawaii is producing 100 kw of sustainable, continuous electricity annually and is powering a neighborhood of 120 homes. A potential next phase for OTEC development at NELHA is being considered by an international consortium under the recently signed Okinawa-Hawaii clean energy agreement.
 
BARDOT Group, a French SME specialized in subsea engineering and equipment manufacturing for offshore energy, has signed a contract for the first commercial OTEC system to be installed in an eco-resort in Maldives.
 
In November 2017, NELHA began soliciting proposals for a 0.1-0.3 megawatt on-shore Ocean Thermal Energy Conversion (OTEC) system, to be operated for ten years. In its RFP, NELHA stated: “Proposer will design, construct, install, own, operate and maintain the OTEC system. The general intent of the Project is increase consumption of renewable energy at NELHA; provide stable energy prices for NELHA; and, advance OTEC technology.” And that the on-shore facility “must emulate a marine site to the maximum extent possible to represent a quantum leap forward in the commercialization of OTEC.” We have responded to the RFP as a bidder alongside Naval Energies, who we anticipate will act as our turn-key Engineering Procurement Contractor (EPC).
 
Global acceptance of man’s influence on climate change may also contribute to a shift in the demand for OTEC. As evidenced by the Paris Agreement reached in December 2015 to combat climate change, 195 nations have expressly recognized that conventional fossil-fuel powered energy technologies affect global climate change and the need to embrace a sustainable future in energy and water. Low-lying coastal countries (sometimes referred to as small island developing states) that tend to share similar sustainable development challenges, including small but growing populations, limited resources, remoteness, susceptibility to natural disasters, vulnerability to external shocks, excessive dependence on international trade, and fragile environments, have embraced this recognition and are keenly aware that they are on the frontline of early impact of sea level rise and are aggressively trying to embrace sustainable-energy alternatives. This is a major driving force for OTEC in primary early markets.
 
Recent international political instability in fossil-fuel-producing regions and oil price volatility have exposed the criticality of energy security and independence for all countries. The need to have a tighter control of domestic energy requirements is a matter of increasing international concern. Continued reliance on other countries (particularly those in oil-producing regions) is not a favorable option any longer. We believe these considerations will continue to drive renewable research and commercialization efforts that benefit technologies with global potential to replace fossil-fuel-based energy systems and benefit from base-load capabilities like OTEC.
  
Our current management team has led the development of the business since 2010 and has established a pipeline of potential projects which include one signed 20-year energy services agreement (‘‘ESA’’), six signed memoranda of understanding (‘‘MoU’’) and a written agreement to support Lockheed Martin Corporation in proposing to the US Navy a Company built SWAC system for a Military Base in the Indian Ocean. The projects under the ESA, Lockheed Agreement and MoUs are to design, build, own and operate OTEC, SWAC, or a combination of both plants in The United States Virgin Islands, Bahamas, an Island in the Indian Ocean and in East Africa. The Public Services Commission (“PSC”) of the US Virgin Islands has approved our application to be a ‘Qualified Facility’ and build a 15MW OTEC plant on the island of St. Croix. In addition to the OTEC plant, we are negotiating additional opportunities to supply potable water to the USVI Government.
 
We are also discussing with Lockheed Martin Corporation, a SWAC project for the US Department of Defense) and both OTEC and SWAC with the US Department of Agriculture (“USDA”). Currently, two projects are in the planning and discussion phase:
 
SWAC plant for a US Navy Base in Diego Garcia, British Indian Ocean Territories
OTEC and SWAC plant for Guam, Micronesia, in the Western Pacific
 
We have provided a detailed study and designs for OTEC and/or SWAC to:
 
Lockheed Martin Corporation for an OTEC system to be built for the US Navy Base in Diego Garcia, We are briefing the project to US Navy at a design charrette meeting in early 2018
The USDA for a combined OTEC/SWAC plant for Guam
The Legislature of the US Virgin Islands for an OTEC plant for the island of St, Croix
 
Having successfully developed this pipeline of opportunities, we believe that it is now appropriate to seek additional funding to further progress and build up our engineering and technical teams, further develop our IP, file patents for several OTEC technical systems, and advance our pipeline of current opportunities to support our growth strategy.
 
 
6
 
Our Competition
 
We compete in the development, construction, and operation of OTEC and SWAC plants with other operators that develop similar facilities powered by other energy sources, primarily oil, natural gas, nuclear energy, and solar power. These traditional energy sources have well-established infrastructures for production, delivery, and supply, with well-known commercial terms. In developing our OTEC and SWAC plants, we will need to satisfy our customers that these technologies are sound and economical, which may be a challenge until and unless we have an established successful operating history. The energy industry is dominated by an array of companies of all sizes that have proven technologies and well-established fuel sources from a number of suppliers.
 
We expect that we will encounter increasing competition for OTEC and SWAC plants. Other firms with greater financial and technical resources are focusing commercialization of these technologies. This includes, for example, Akuo Energy and DCNS (now Naval Energies), which were funded to construct and install a number of OTEC plants adding up to 16 MWs of power generation outside the coastline of Martinique in the Caribbean, and Lockheed Martin, which has recently designed a 10-MW OTEC plant and has partnered with China-based Reignwood Group, which intends to build the plant in Hainan, China.
 
Our competitors may benefit from collaborative relationships with countries, including a large number of Caribbean nations that now have renewable energy standards, and are looking at ways to reduce their carbon footprint, decouple the price of electricity from the volatile price of oil, and increase energy security. Other competitors may have advantageous relationships with authorities such as Hawaii, U.S. territories, and the U.S. Department of Defense, which are looking at OTEC as a possible source of renewable energy and water for drinking, fish farming, and agriculture.
 
We cannot assure that we will be able to compete effectively as the industry grows and becomes more established and as OTEC and SWAC plants become more accepted as viable and economic energy solutions.
 
We believe competition in this industry is and will be based on technical soundness and viability, the economics of plant outputs as compared to other energy sources, developmental reputation and expertise, financial capability, and ability to develop relationships with potential customers. All of these factors are outside our control.
 
Our Operational Strategy and Economic Models
 
We have developed economic models of costs and potential revenue structures that we will seek to implement as we develop OTEC and SWAC projects.
  
OTEC Projects
 
The estimated construction costs for a 20-MW plant are approximately $445 million. The hard costs of approximately $301 million consist of the power system and platform construction and piping, which make up 68% of the total. The remaining 32% consists of other construction costs and the deployment of the cold water pipe. The soft costs of approximately $58 million consist of design, permits and licensing, environmental impact assessment, bathymetry, contractor fees, and insurance.
 
Once operational, the capacity factor, which is the projected percent of time that a power system will be fully operational, considering maintenance, inspections, and estimated unforeseen events, is expected to be 95% annually. This factor is used in our financial calculations, which means the plant will not be generating revenue for 5% of the year. Most fossil-fuel plants have capacity factors around 90%, as a result of the major maintenance for high-temperature boilers, fossil-fuel feed in systems, safety inspections, cleaning, etc. The normal maintenance cycle for the pumps, turbine, and generators used in the OTEC plant is typically every five years. This includes the cleaning of the heat exchangers and installation of new seals.
 
We anticipate that project returns will be comprised of two components: First, as the project developer, we will seek a lump-sum payment as a development fee at the time of closing the project financing for each project. These payments will be allocated toward reimbursement of development costs and perhaps a financial return at the early stage of each project. The development fee will vary, but initially we will seek a fee of approximately 3% of the project cost, payable upon closing project financing. Second, we will retain a percentage of equity in the project, with a goal to retain a minimum of 51% of the equity in any OTEC project in order to participate in operating revenues.
 
We will seek to generate revenue from OTEC plants from contract pricing charged on an energy-only price per kWh or on the basis of a generating capacity payment priced per kW per month and an energy usage price per kWh. In addition to revenue from power generation, in many of the countries of the world where we intend to build OTEC and SWAC plants, water is in short supply. In some locations, water is considered the more important commodity. Depending on the part of the world in which the plant is built, supplying water for drinking, fish farming, and agriculture would significantly increase plant revenue.
 
We cannot assure that we can maintain the revenue points noted above, that any fees received will offset development costs incurred to date, or that any operating plant will generate revenue.
 
SWAC Projects
 
The estimated construction costs are approximately $150 million. The hard costs of approximately $91 million consist of piping and installation, which make up 60% of the total. The remaining 40% consists of the pump house, central utility plant (CUP), mechanical and engineering equipment, design, and other contingency costs. The soft costs of approximately $30 million consist of the CUP license, permits, environmental impact assessment, bathymetry, and insurance.
 
Under our economic model, it will seek to generate revenue at two stages of the project. First, as the project developer, we will seek a lump-sum payment of a development fee equal to approximately 3% of the project cost at the time of closing the project financing for each project. Such payments would provide the Company with income at the early stage of each project. If we are able to negotiate a development fee, we estimate that it will vary but typically will be in the $2,500,000-$3,500,000 range. The second component of project returns is based upon the percentage of equity we will retain in the project.
  
SWAC contract revenue will be based typically on three charges:
 
Fixed Price–this is based upon the capital costs of the project paid over the term of the debt and with the intention of covering the costs of debt.
Operation and Maintenance–this payment covers the cost of the labor and fixed overhead needed to run the SWAC system, as well as any traditional chiller plant operating to fulfill back-up or peak-load requirements.
Chilled Water Payment–this is a variable charge based on the actual chilled water use and chilled water generated both by the SWAC and conventional system at the agreed upon conversion factors of kW/ton and current electricity costs in U.S. dollars per kWh.
 
We will seek to structure project financing with the goal of retaining 100% of the equity in any SWAC project. We cannot assure that we will recover project development costs or realize a financial return over the life of the project.
 
7
 
Our Project Timeline
 
We have not developed, designed, constructed, and placed into operation any OTEC or SWAC plants. However, based on our planning process and early development experience to date, we estimate that it will take approximately two to four years or more, depending on local conditions, including regulatory and permitting requirements, to take a project from a preliminary memorandum of understanding with a potential power or other product purchaser to completion and commencement of operation.
 
Our Strategic Relationships
 
We have strategic relationships with each of the following parties for potential plant construction and the funding of projects.
 
DCO Energy, LLC, Mays Landing, New Jersey, is an American energy development company specializing in the development, engineering, construction, start-up, commissioning, operation, maintenance and management, as well as, ownership of central energy centers, renewable energy projects, and combined heat, chilling, and power-production facilities. DCO Energy was formed in 2000 and has independently developed and/or operated energy producing facilities of approximately 275 MW of electric, 400 MMBtu/hr of heat recovery, 1,500 MMBtu/hr of boiler capacity, and 130,000 tons of chilled water capacity, totaling over $1 billion of assets. DCO Energy provides financing, engineering and design, construction management, start-up and commissioning resources, and long-term operating and maintenance services for its own projects as well as third-party clients.
 
Naval Energies (f/k/a DCNS) Paris, France, is a French naval defense company and one of Europe’s largest ship builders. It employs 12,500 people and generates annual revenues of around $3.9 billion. In 2009, Naval Energies set up an incubator dedicated to marine renewable energies and has stated its intention to be a leader in this market, which includes marine turbines, floating wind turbines, OTEC, and tidal stream turbines.
 
Kongsberg Devotek AS, Kongsberg, Norway, is a product development and engineering company operating in the maritime, defense, automotive, oil and gas, and industrial sectors. Kongsberg Devotek has particular skills in the design and manufacture of offshore and subsea structures and infrastructure, which include development and installation of seabed piping. Further, Kongsberg Devotek has extensive experience in working with the maritime industry, including propulsion systems, deck machinery, loading and off-loading units, and control and guiding systems. We plan to continue discussions with Kongsberg Devotek in 2018.
 
Our Construction and Components
 
Once we have designed the system, we will review the design with its engineering, procurement, and construction partner to maximize the chances that the project can be delivered according to plan and on budget. We expect our construction contracts to be at a fixed price and to include penalties if the construction timetable is missed. We may, but are not obligated to, engage DCO Energy to construct our plants or serve as our Owners Engineer.
 
In our systems, the two most important components are heat exchangers and deep-water intake pipes. Although there are multiple providers of each of these components, the supply of the best components comes from just a few companies globally. We expect to source our deep-water intake pipes from Pipelife of Norway, the only company we know of that makes pipes of sufficient quality, strength, and diameter (2.5 meters) to support our planned OTEC plants. However, we expect that we could work around a lack of supply from Pipelife by using multiple smaller pipes that are widely available on the market, although this would increase our construction costs.
  
We will also need the highest quality, large heat exchangers for our systems; heat exchangers represent a large percentage of the projected costs of our OTEC and SWAC systems and also account for a significant portion of the design complexity inherent in commercial OTEC and SWAC designs. Our relationship with Alfa Laval for heat exchangers provides the Company with the size and quality heat exchangers that it expects to need, although we believe there are several other companies that could provide the Company with adequate supply of these devices meeting our specifications if we need to source from them.
 
Other major components, such as ammonia turbines, generators, and pumps, are manufactured by several multinational companies, including General Electric and Siemens.
  
Our Operations
 
For OTEC electricity-generating facilities, we intend to enter into 20- to 30-year PPAs, pursuant to which the project would supply fixed-price, baseload electricity to satisfy the minimum demand of the purchaser’s customers. This PPA structure allows customers to plan and budget their energy costs over the life of the contract. For our SWAC systems, we intend to enter into 20-to 30-year ESAs to supply minimum quantities of chilled water for use in a customer’s air conditioning system.
 
We anticipate that operations of OTEC and SWAC plants will be subcontracted to third parties that will take responsibility for ensuring the efficient operation of the plants. These arrangements may reduce our exposure to operational risk, although they may reduce our financial return if actual operating costs are less than the subcontract payments. We cannot assure that any OTEC and SWAC plants will permit the PPAs and ESAs to yield minimum target internal rates of return. Our first projects are likely to have lower returns than subsequent projects. Variances in internal rates of return may occur due to a range of factors, including availability and structure of project financing and localized issues such as taxes, some of which may be outside of our control.
 
We expect our OTEC contract pricing will either be charged on an energy-only price per kWh or on the basis of a capacity payment priced per kW per month and an energy usage price per kWh. We cannot assure that this pricing will enable the Company to recoup its funding costs and capital repayments and allow it to earn a profit.
 
 
8
 
 
Marketing Strategies
 
Our marketing and sales efforts are managed and directed by our chairman and chief executive officer, Jeremy P. Feakins, who has 35 years’ experience of senior-level sales in both commercial and governmental markets. Our marketing campaign has focused on explaining to potential customers the economic, environmental, and other benefits of OTEC and SWAC through personal contacts, industry interactions, and our website.
 
Our target markets are comprised of large institutional customers that typically include governments, utilities, large resorts, hospitals, educational institutions, and municipalities. We market to them directly through personal meetings and contact by our chief executive officer and other key members of our team. We also make extensive use of centers of influence either to heigrhten awareness of our products in the minds of key customers’ decision-makers or to secure face-to-face meetings and preliminary agreements with our customers and our chief executive officer.
 
Sales cycles in our business are extremely long and complex and often involve multiple meetings with governmental, regulatory, electric utility, and corporate entities. Therefore, we cannot predict when or if any of the projects we currently have under development will progress to the signed contract or operational phase and generate revenue. We do not expect sales to be seasonal or cyclical.
 
Material Regulation
 
Our business and products are subject to material regulation. However, because we contemplate offering our products and services in different countries, the specific nature of the regulation will be wholly dependent on the nation where the project will be located. The precise nature of the regulatory requirements for each project is wholly dependent on the specific location, and the national, state, and local regulations apply at that location.
 
In all cases, we expect the level of regulation will be material and will require significant permitting and ongoing compliance during the life of the project. The most significant regulations will likely be environmental and will include mitigating possible adverse effects during both the construction and operational phases of the project.
 
However, we believe that the limited plant site disturbance of both SWAC and OTEC projects, together with the significantly lower emissions that result from these projects as compared to fossil-fuel electrical generation, will make compliance with all such regulation manageable in the normal course.
 
The second most significant regulations will likely involve coordination with existing infrastructure. We believe compliance with this type of regulation is a routine civil engineering coordination process that exists for all new buildings and infrastructure projects of all types. Again, we believe that the design of both SWAC and OTEC projects can readily be modified to avoid interference with existing infrastructure in most cases.
 
Facilities
 
Our principal executive offices are located at 800 South Queen Street, Lancaster, Pennsylvania 17603. Our telephone number at that address is (717) 299-1344.
  
Intellectual Property
 
We use, or intend to employ in the performance of our material contracts, intellectual property rights in relation to the design and development of OTEC plants. Our intellectual property rights can be categorized broadly as proprietary know-how, technical databases and trade secrets, comprising concept designs, plant design, and economic models. Additionally, we have applied to register the trademark TOO DEEP® at the U.S. Patent and Trademark Office for the provision of desalinated deep ocean water for consumption. The trademark has been granted, subject to using it in commerce.
 
We may apply for patents for components of our intellectual property for OTEC and SWAC systems, including novel or new methodologies for cold-water piping, heat exchanges, and computer-aided design programs. We cannot assure that any patents we seek will be granted.
 
Our intellectual property has been developed by our employees and is protected under employee agreements confirming that the rights in the inventions and developments made by the employees are our property. Confidential information is protected by nondisclosure agreements we entered into with prospective partners or other third parties with which we do business.
 
We have not received any notification from third parties that our processes or designs infringe any third-party rights, and we are not aware of any valid and enforceable third-party intellectual property rights that infringe our intellectual property rights. Currently, there is no patent for any company for OTEC technology.
 
Employees
 
We currently have 10 employees and/or consultants, consisting of one officer, three engineers and technicians, two marketing, and three general and administrative employees. There are no collective-bargaining agreements with our employees, and we have not experienced work interruptions or strikes. We believe our relationship with employees is good and we provide health and life insurance for all employees.
 
 
9
 
 
ITEM 1A. RISK FACTORS.
 
Investing in our common stock involves a high degree of risk. You should carefully consider the risks described below, as well as the other information in this annual report, including our financial statements and the related notes and “Management’s Discussion and Analysis of Financial Condition and Results of Operations,” before deciding whether to invest in our common stock. The occurrence of any of the events or developments described below could harm our business, financial condition, operating results, and growth prospects. In such an event, the market price of our common stock could decline, and you may lose all or part of your investment. Additional risks and uncertainties not presently known to us or that we currently deem immaterial also may impair our business operations.
 
Risks Related to Our Financial Condition
 
The auditors’ report for the years ended December 31, 2017 and 2016, contains an explanatory paragraph about our ability to continue as a going concern.
 
The report of our auditors on our consolidated financial statements for the years ended December 31, 2017 and 2016, as well as for prior years, contains an explanatory paragraph raising substantial doubt about our ability to continue as a going concern. We had a net loss of $14,591,675 and $6,108,117 respectively, and cash used in operations of $1,469,169 and $2,057,879, respectively, and has a working capital deficiency of $10,716,255 and $7,865,177 and an accumulated deficit of $67,703,218 and $53,111,543, respectively at December 31, 2017 and December 31, 2016. This raises substantial doubt about our ability to continue as a going concern. Unless we raise additional capital by December 31, 2018, we will be unable to continue as a going concern. Our ability to continue as a going concern beyond December 31, 2018, is dependent on our ability to raise additional capital through the sale of debt or equity securities or stockholder loans and to implement our business plan during the next 12 months. The financial statements do not include any adjustments that might be necessary if we are unable to continue as a going concern. Management believes that actions presently being taken to obtain additional funding through implementing our strategic plans, broadly based marketing strategy, and sales incentives to expand operations will provide the opportunity for us to continue as a going concern.
 
We have no current project that will generate revenues in the near future.
  
None of our several projects is to the development stage at which it will generate revenues in the near future. Our project development cycles are relatively long, extending over several years as we identify a potential project site, complete negotiations with third parties, complete permitting, obtain financing, complete construction, and place a plant into service. We expect to receive a development fee of approximately 3% of the project cost from our projects, payable upon the close of project financing. Operating revenues from projects are expected to be received when the plant has been built and placed into operation. We are currently focusing on developing a U.S. Virgin Island project, but even if we develop it successfully, it will not generate revenues until several years in the future. Until we receive revenues from this or another project, we will be dependent on raising funds from external sources.
 
We will require substantial amounts of additional capital from external sources.
 
We do not have any current source of revenues or sufficient cash or other liquid resources to fund our planned activities until we receive development fees from new contracts. Accordingly, as in the past, we will need substantial amounts of capital from external sources to fund day-to-day operations and project development. We have no arrangements or commitment for such capital. We plan to continue our practice of seeking external capital through the sale of debt or equity, although we cannot assure that such efforts will be successful. Any new investments will dilute the interest of the current stockholders. Further, new investors may require preferential financial returns, security, voting rights, or other preferences that will be superior to the rights of the holders of common stock. Alternatively, as project development advances, we may be required to sell all or a portion of our interest in one or more projects, which could reduce our retained financial interest and potential return.
 
Risks Related to Our Business
  
Our efforts to develop OTEC and SWAC plants are subject to many financial, technical, managerial, and sales risks that may make us unsuccessful.
 
We incur substantial costs that we may not recover developing a new project that we may not build, operate, or sell. The identification of suitable locations, the investigation of the applicable regulatory and economic framework, the identification of potential purchasers, the completion of preliminary engineering and planning, and the funding of related administrative and support costs ordinarily require several years to complete before we determine to further develop or abandon a project. Each of these steps is fraught with risks and uncertainties, such as:
 
limited market due to low demand, existing competitive energy sources, low power costs, or the absence of a single or few large potential output purchasers;
a regulatory scheme suggesting that the development and operation of a plant would be subject to excessively stringent utility regulations, burdensome zoning or permitting practices and requirements, unusually stringent environmental requirements, or similar factors;
shortage of suitable onshore locations, lack of available cold water with near-shore accessibility, sea wave and current conditions, and exposure to hurricanes, typhoons, earthquakes, or similar extreme events;
the unavailability of favorable tax or other incentives or excessively stringent applicable incentive requirements;
 
the high cost and potential regulatory difficulties in integrating into new markets;
the possibility that new markets may be limited or unstable or exposed to competition from other sources of existing or potentially new energy sources;
difficulties in negotiating power purchase agreements (PPAs) with potential customers, including in some instances, the necessity to assist in the formation of a power purchasing group; and
educating the market as well as investors regarding the reliability and economical and environmental benefits of ocean thermal technologies.
 
We cannot assure that we will be able to overcome these risks as we initiate the development of a project. We may incur substantial costs in advancing a project through the early stages, only to conclude eventually that the project is not economically or technically feasible, in which case we may be unable to recover the costs that we have then incurred. When we elect to proceed with a project, we may continue to incur substantial costs and be unable to complete the development, sell the project, or otherwise recover our investment. Even when a project is developed, constructed, and placed in operation, we cannot assure that we will be able to operate at a profit sufficient to recover our total investment.
 
10
 
 
We are dependent on the performance of counterparties to our agreements.
 
Our projects are and will be complex, with a number of agreements among several parties that purchase plant outputs; provide financing; complete design, construction, and other services; design and perform regulatory compliance; and fulfill other requirements. The failure of any participant in one of our projects due to its own management, financial, operating, or other deficiencies, all of which may be outside our control, can materially and adversely affect our operations and financial results. In circumstances in which we are not the prime developer of a large-scale project involving many large components in addition to our OTEC, SWAC, or other components, we would have little ability to address problems resulting from performance failures by others or implement project-wide remedial measures. The foregoing is illustrated in our Baha Mar project, which is now on hold because of contract performance and financing disputes by others and may never resume.
 
Ongoing world economic, currency-exchange, energy-price, and political circumstances adversely affect our project development activities.
 
Recent and ongoing world events outside of our control or influence adversely affect our development activities. Economic uncertainties have resulted in the unpredictable availability of credit, debt, and equity financing; volatile interest rates; currency exchange-rate fluctuations that add risk to international projects; restrictions on the availability of borrowing; concerns respecting inflation and deflation; economic turmoil resulting from unpredictable political events and tensions in international relations; substantial reductions in hydrocarbon energy prices and the impact of such declines on the cost of energy generally; shifts in the economic feasibility of competitive energy sources; and similar factors. These adverse factors frequently have a particularly intense effect on emerging markets and developing countries, which we believe provide the greatest opportunity for our development of our projects. The possibility that principal energy prices will continue at current or even higher levels, which could reduce the projected cost at which power could be generated by hydrocarbon-fueled power plants and could make our relatively higher cost plants less competitive. These emerging and developing markets are particularly vulnerable to the negative impacts of these adverse circumstances. The economic feasibility of alternative energy, including the process we develop and propose to operate, as compared to hydrocarbon energy is adversely affected as the prices for hydrocarbon fuels decline. Accordingly, possible continuing low hydrocarbon prices may retard the potential increase in the economic feasibility of alternative energy. Our ability to develop and operate alternative energy plants and our ability to generate revenue will be adversely affected by continuing, relatively soft hydrocarbon energy prices. Further, alternative energy development may be adversely affected by uncertainty in hydrocarbon prices or public expectations that hydrocarbon prices may decline again.
 
We require substantial amounts of capital for all phases of our proposed activities.
 
We require substantial amounts of capital to fund efforts to identify, research, preliminarily engineer, permit, and design our projects and negotiate PPAs for them. These costs may not be recovered, because we may not elect to complete the development of the project or because the development and operation of the project are not successful. We will rely on external capital to fund all of our operations, and we cannot assure that such capital will be available. Our efforts to access capital markets will be limited, particularly at the outset, because we have not yet developed and placed into operation our first plant. Accordingly, we expect that we will have to provide the potential for a significant economic return for the initial capital we obtain, which will likely dilute the interests of our existing stockholders. We expect that each project that we are able to fully develop, construct, and place into operation will require several stages and levels of debt and equity financing. For example, we expect that a 17.2-megawatt (MW) OTEC plant may require total capital expenditures of approximately $445 million, consisting of $365 million in project debt financing and $80 million in equity. We cannot assure that we will be able to obtain such financing, and if obtained, such financing may be on terms that we will retain only a minority financial interest in the completed project and its operations. Our inability to obtain required financing for any activity or project could have a material adverse effect on our activities and operations.
 
We are reliant on our key executives and personnel.
 
Our business, development, and prospects are highly dependent upon the continued services and performance of our directors and other key personnel, on whom we rely for experience, technical skills, and commercial relationships. We believe that the loss of services of any existing key executives, for any reason, or failure to attract and retain necessary personnel, could have a material adverse impact on our business, development, financial condition, results of operations, and prospects. Although we have entered into employment agreements with our key executives, we may not be able to retain such key executives. We do not maintain key-man life insurance on any of our executive employees.
 
Regulations and policies governing energy projects, power generation, desalinated water sales, and other aspects of our OTEC and SWAC plants may adversely affect our ability to develop projects, and any changes in the applicable regulatory schemes may adversely affect projects that we are constructing or have constructed and are operating.
  
In identifying possible plant locations and undertaking preliminary development, an important factor in the overall economic feasibility of a project will be the governing regulatory regime. Such regulation includes the way the local jurisdiction regulates the power, cooling energy, or water output from a plant. Any change in that regulatory scheme after we determine to develop a plant based on existing circumstances could have a material adverse effect on our proposed operations. Generally, we will seek to structure plant output sales agreements as privately negotiated contracts not subject to utility or similar regulation, but we cannot assure that we will be able to do so. Some PPAs that we may seek to enter into may be subject to public utility commission approval, which may not be obtained or may be delayed. In some jurisdictions, the sale of output from a plant may be subject to public service commission or regulation by a similar authority as a public utility, even though we attempt to negotiate a private purchaser agreement for that output. In these circumstances, we may encounter delays in obtaining any required approval, approval may be conditioned on specified prices or other operating conditions, or the existence of the regulatory framework may delay or limit our ability to seek price increases.
 
 
11
 
 
The financial model for our proposed projects has not been tested and may not be successful.
 
We are proposing a financial model for the development of individual projects that includes development financing provided by us, construction financing provided by equity investors in the specific projects, and project debt financing; the payment of a development fee to us at the time of construction; and continuing equity participation by us throughout the plant’s operation. We have not used this model in the financing or completion of any plant, and we cannot assure that the financial model and, therefore, the anticipated financial return to us will be acceptable to those that might provide the requisite external capital. We may need to revise extensively our financing structure for each project, and we cannot assure that any restructured proposal would not substantially reduce our financial return or increase our risk. The financial, investment, and credit community are generally unfamiliar with OTEC and SWAC projects, which will adversely affect our financing efforts. We have no existing relationships with potential sources of debt or equity capital, and any financing sources that we may develop may be inadequate to support the anticipated capital needs of our business. Our efforts to obtain financing may be adversely affected by the fact that our projects will likely be located in developing or emerging markets. Our inability to obtain financing may force us to abandon projects in which we have invested substantial costs, which we may be unable to recover. The process of identifying new sources of debt and equity financing and agreeing on all relevant business and legal terms could be lengthy and could require us to limit the rate at which we can develop projects or reduce our financial return.
 
We may be exposed to political and legal risks in the developing or emerging markets in which we propose to locate plants.
 
Many of the emerging and developing markets that may be suitable for a potential OTEC or SWAC plants are located in emerging or developing countries that may have developing and untested regulatory and legal environments for large-scale, international, commercial enterprises. Further, political instability, regime change, or other political factors may increase uncertainty and instability, which in turn may adversely affect our ability to secure necessary regulatory approvals and obtain required project financing, which increases related costs and reduces our financial return. Any changes in applicable laws and regulations, including any governmental incentives, environmental requirements or restrictions, safety requirements, and similar matters, may change, and the risk or likelihood of such a change could adversely affect the availability and cost of financing. Further, in some jurisdictions, applicable legal requirements may not have been fully tested and are still being developed in the face of modern international commercial transactions and environmental requirements, which may lead to changes in interpretation or application that may be adverse to us. Our expectations regarding the size of the potential OTEC and SWAC markets and the number of possible suitable locations may not be accurate.
 
 
Our business plan and models are based on our identification of potential suitable locations for OTEC or SWAC plants based on a preliminary evaluation of public information respecting demographic data, current power-generation costs, and local seafloor contours and seawater temperatures, which may be inaccurate. Any material inaccuracy could substantially reduce the total market available to us for plant development.
 
We may be unable to arrange or complete future construction projects on time, within expected budgets, or without interruption due to materials availability and disruptions in supply, labor, or other factors. If any project reaches the point at which we undertake construction, such construction may be subject to actual prices higher than the amount budgeted, the limited or delayed availability of components or materials, shortages or interruptions of labor or materials, or similar circumstances. In the case we have insufficient budget flexibility to pay increased construction costs, corresponding delays could result to construction completion and the commencement of operations.
 
Emerging markets are often associated with high growth rates that may not be sustainable and may be accompanied by periods of high inflation. Rising inflation or related government monetary and economic policies in certain project jurisdictions may affect our ability to obtain external financing and reduce our ability to implement our expansion strategy. We can give no assurances that a local government will not implement general or project-specific measures to tighten external financing standards, or that if any such measure is implemented, it will not adversely affect our future operating results and profitability.
  
We are subject to changing attitudes about environmental risks.
 
Our projects may face opposition from environmental groups that may oppose our development, construction, or operation of OTEC or SWAC plants. Each project is expected to have different environmental issues, especially as many of our projects are based in different settings having a wide range of environmental standards. We intend to solicit input from environmental organizations and activists early in our design process in relation to our projects in an effort to consider appropriately these organizations’ recommendations in order to mitigate subsequent conflict or opposition, but we cannot assure that such outreach will be effective in all cases, and if it is not, opposition to our projects could increase our cost and adversely affect the results of our operations.
 
We may be unable to find land suitable for our projects.
 
Each project site requires land of differing characteristics to permit the cost-effective construction of OTEC or SWAC plants, and suitable land may not always be available. Even if available, such land may be difficult to obtain in a timely or cost-effective manner. For example, we would prefer to place OTEC power systems and facilities as close to the ocean as possible. We hope to mitigate this risk by using land owned by local governments, rather than private individuals or entities, as targeting local governments with favorable energy policies or mandates should reduce land rights risks. Our inability to secure appropriate land at a reasonable cost may render certain of our future projects economically unfeasible.
 
We have a limited number of suppliers for certain materials, which could increase our costs or delay completion of projects.
 
In our systems, the two most important components are heat exchangers and deep-water intake pipes. Although there are multiple providers of each of these components, the supply of the best components comes from just a few companies globally. Should these resources become unavailable for any reason or too costly, we would be required to seek alternative suppliers. The products from such suppliers could be of a lower quality or more costly, in any event requiring us to expend additional monies or time to complete our projects as planned. This could result in financial penalties or other costs to us.
 
There may be greater cost in building OTEC plants that generate over 10 MWs of electricity.
 
In order to successfully obtain debt financing for OTEC facilities, we must find engineering, procurement, and construction contractors willing to enter into fixed-price contracts at a pricing that is economically viable for us. Based on our preliminary discussions, we believe that engineering, procurement, and construction contractors may be willing to consider fixed-price arrangements for up to 10-MW OTEC facilities, but we have not yet discussed performance risk guarantees for OTEC plants greater than 10 MW. The cost of construction for larger OTEC power systems may vary considerably. Such variances could include increased costs for construction, design, and component procurement. As we gain more experience, we may improve upon efficiencies and accuracy in pricing. Failure to procure engineering, procurement, and construction contractors willing to perform fixed-price contracts on facilities that produce more than 10 MWs may have a material adverse effect on our operations.
 
 
12
 
 
Technological advances may render our technologies, products, and services obsolete.
 
We operate in a fast-moving sector in which new forms of power generation and new energy sources are continuously being researched. New technologies may be able to provide power, coolant, desalinated seawater, or other outputs at a lower cost, including amortization of capital costs, or with less environmental impact. We will remain subject to these risks for the useful life of our projects, which could extend for 20 to 30 years or more. Any such technological improvements could render our projects obsolete.
 
We may not successfully manage growth.
 
We intend to continue to develop the projects in our project pipeline and to construct and operate plants as we deem warranted and as we are able to finance. This is an ambitious growth strategy. Our growth and future success will depend on the successful completion of the expansion strategies and the sufficiency of demand for our energy products. The execution of our expansion strategies may also place a strain on our managerial, operational, and financial reserves. Should we fail to effectively implement such expansion strategies or should there be insufficient demand for our products and services, our business operations, financial performance, and prospects would be adversely affected.
 
There will likely be a single or limited number of power purchasers from each plant, so we will be dependent on their economic viability and stability and continued operations.
  
We expect that any plant that we operate will provide power, cooling, desalinated water, or other products to a few or a limited number of key power purchasers that will use the power for specific commercial enterprises, such as resorts, manufacturing or processing plants, or similar large-scale operations. Accordingly, our ability to sell power and other outputs will be dependent on the economic viability of these purchasers. If one or more key purchasers were to fail, we would be required to obtain alternative purchasers for our power and other outputs, and there may be no or a limited number of such alternative purchasers in the merging and developing markets where we anticipate our plants may be located. Accordingly, a failure of an output purchaser may result in the failure of our power plant project. We do not anticipate that we will be able to obtain insurance to protect us against such a loss on acceptable terms. Further, our project output purchasers may not comply with contractual payment obligations or may otherwise fail to perform their contracts, and they may have greater economic bargaining power and negotiating leverage as we seek to enforce our contractual rights. To the extent that any of our project power purchasers are, or are controlled by, governmental entities, our projects may also be subject to legislative, administrative, or other political action or policies that impair their contractual performance. Any failure of any key power purchasers to meet their contractual obligations for any reason could have a material adverse effect on our business and operations.
 
Operational problems, natural events or catastrophes, casualty loss, or other events may impair the commercial operation of our projects.
 
Our ability to meet our delivery obligations under power-generation contracts, as well as our ability to meet economic projections, will depend on our ability to maintain the efficient working order of our plants. Severe weather, natural disasters, accidents, failure of significant equipment components, inability to obtain replacement parts, failure of power transmission facilities, or other catastrophes or occurrences could materially interrupt our activities and consequently reduce our economic return. Since all of our plants will be located on the shore within close proximity to deep ocean or lake water, our plants will be subject to extraordinary natural occurrences, such as wave surges from hurricanes or typhoons, tsunamis, earthquakes, and other events, over which we will have absolutely no control. We cannot assure that we can obtain sufficient insurance to protect us from all risks resulting from such catastrophes. Further, we cannot assure that any design features or operating policies that we may use will mitigate the risks to which our plants may be exposed. Any threatened or actual events could expose us to plant shutdowns, substantial repairs, interruptions of operations, damages to our power purchasers, and similar events that could require us to incur substantial costs and significantly impair our revenues and results of operations.
 
We may be adversely affected by climate change.
 
Climate change may result in changes in ocean currents and water temperatures that could have a material adverse effect on our results of operations. These changes may require additional capital costs or impair the efficiency of our operations. Because of the size and cost of major components of our power plants, we typically will not inventory spare components, so that any substantial damage may require that we await the custom manufacture and delivery of such items, which may involve substantial delays. Significant changes may render any plant inefficient and uneconomical.
 
Our projects will be subject to substantial regulation.
 
Our projects likely will be significant commercial or industrial enterprises in each of their locations and, as such, will be subject to numerous environmental, health and safety, antidiscrimination, and similar laws and regulations in each of the jurisdictions governing our locations. These laws and regulations will require our projects to obtain and maintain permits and approvals; complete environmental impact assessments or statements prior to construction; and review processes and operations to implement environmental, health and safety, antidiscrimination, and other programs and procedures to control risks associated with our operations.
 
Our in-water facilities and operations may be deemed to threaten living coral, sea plants and animals, shoreline contours, and similar items. In some circumstances, we may encounter environmental problems that we may unable to overcome, which may force us to relocate our facilities, at considerable additional costs.
 
If our projects do not comply with applicable laws, regulations, or permit conditions, or if there are endangered or threatened species fatalities on our projects, we may be required to pay penalties or fines or curtail or cease operations of the affected projects. In addition, violations of environmental and other laws, including certain violations of laws protecting wetlands, shorelines and land, and sea plant and animal life, may result in civil fines, criminal sanctions, or injunctions.
 
Some environmental laws impose liability on current and previous owners and operators of real property for the cost of removal or remediation of hazardous substances, without regard to whether the owner or operator knew of, or was responsible for, the release of such hazardous substance. In some jurisdictions, private plaintiffs may also bring claims arising from the presence of hazardous substances or their unlawful release or exposure. We will likely be unable to purchase insurance against these risks at all or on acceptable terms.
  
Environmental health and safety laws, regulations, and permit requirements applicable to any specific project at the time of construction may change or become more stringent during the life of the operation. Any such changes could require that our projects incur substantial additional costs, alter their operations, or limit or curtail their operations in order to comply, which would have a material adverse effect on our operations. We may not be able to pass on any additional costs that we incur to our power purchasers, particularly in those cases in which we sell power pursuant to a long-term, fixed-price agreement. The OTEC and SWAC industry may be subject to increased regulatory oversight.
 
 
13
 
 
As the OTEC and SWAC industries develop, new regulatory schemes may be adopted by one or more jurisdictions in which we develop or operate plants in order to address actual or perceived threats or problems. In addition to more stringent environmental, safety, and other regulations that may be applicable to us generally under the current regulatory scheme, whole new areas of regulation may be adopted, which could have a material adverse effect on our results of operations. New regulations may specifically regulate, for example, the price at which power that is generated from different seawater temperatures may be sold, even to private purchasers. We may have plants in various locations subject to different governing jurisdictions, so the complexity of this developing and expanding regulatory pattern may be particularly cumbersome and expensive.
 
Insurance to cover anticipated risks may become more expensive.
 
There are no known commercial OTEC and SWAC plants in operation, so the nature and cost of insurance is difficult to predict. Insurance costs may substantially exceed the costs forecast during the planning process or budgeted during actual operations. We cannot assure that adequate insurance coverage will be available to protect us against all risks or that any related costs will be economical. Accordingly, if we are unable or cannot afford to purchase insurance against specific risks, our projects may be fully exposed to those risks, which also could have a material adverse effect on the viability of any affected plant.
 
Risks Related to Our International Operations
 
Certain risks of loss arise from our need to conduct transactions in foreign currencies.
 
Our business activities outside the United States and its territories may be conducted in foreign currencies. In the future, our capital costs and financial results may be affected by fluctuations in exchange rates between the applicable currency and the dollar. Other currencies used by us may not be convertible at satisfactory rates. In addition, the official conversion rates between a particular foreign currency and the U.S. dollar may not accurately reflect the relative value of goods and services available or required in other countries. Further, inflation may lead to the devaluation of such other currencies.
 
Foreign governmental entities may have the authority to alter the terms of our rights or agreements if we do not comply with the terms and obligations indicated in such agreements.
 
Pursuant to the laws in some jurisdictions in which we may develop or operate plants, foreign governmental entities may have the authority to alter the terms of our contractual or financial rights or override the terms of privately negotiated agreements. In extreme circumstances, some foreign governments have taken the extreme step of confiscating private property on the assertion that such action is necessary in the public interest of such country. If this were to occur, we may not be compensated fairly or at all. We cannot assure that we have complied, and will comply, with all the terms and obligations imposed on us under all foreign laws to which one or more of our operations and assets may be subject.
 
Our operations will require our compliance with the Foreign Corrupt Practices Act.
 
We must conduct our activities in or related to foreign companies in compliance with the U.S. Foreign Corrupt Practices Act, or FCPA, and similar anti-bribery laws that generally prohibit companies and their intermediaries from making improper payments to foreign government officials for the purpose of obtaining or retaining business. Enforcement officials interpret the FCPA’s prohibition on improper payments to government officials to apply to officials of state-owned enterprises, including state-owned enterprises with which we may develop or operate projects or to which we may sell plant outputs. While our employees and agents are required to acknowledge and comply with these laws, we cannot assure that our internal policies and procedures will always protect us from violations of these laws, despite our commitment to legal compliance and corporate ethics. The occurrence or allegation of these types of risks may adversely affect our business, performance, prospects, value, financial condition, reputation, and results of operations.
 
Our competitors may not be subject to laws similar to the FCPA, which may give them an advantage in negotiating with underdeveloped countries and the government agencies.
  
Our competitors outside the United States may not be subject to anti-bribery or corruption laws as encompassing or stringent as the U.S. laws to which we are subject, which may place us at a competitive disadvantage.
 
We may encounter difficulties repatriating income from foreign jurisdictions.
 
As we develop and place plants into operation, we intend to enter into only revenue-generating agreements in which we are paid in U.S. dollars directly to our U.S. banks or through countries in which repatriation of the funds to our U.S. accounts is unrestricted. However, situations could arise in which we agree to accept payment in foreign jurisdictions and for which restrictions make it difficult or costly to transfer these funds to our U.S. accounts. In this event, we could incur costs and expenses from our U.S. assets for which we cannot recover income directly. This could require us to obtain additional working capital from other sources, which may not be readily available, resulting in increased costs and decreased profits, if any.
   
Risks Related to Our Common Stock
 
Our common stock is thinly traded, and there is no guarantee of the prices at which the shares will trade.
 
Trading of our common stock is conducted on the OTCQB Marketplace operated by the OTC Markets Group, Inc., or “OTCQB,” under the ticker symbol “CPWR.” Not being listed for trading on an established securities exchange has an adverse effect on the liquidity of our common stock, not only in terms of the number of shares that can be bought and sold at a given price, but also through delays in the timing of transactions and reduction in security analysts’ and the media’s coverage of the Company. This may result in lower prices for your common stock than might otherwise be obtained and could also result in a larger spread between the bid and asked prices for our common stock. Historically, our common stock has been thinly traded, and there is no guarantee of the prices at which the shares will trade, or of the ability of stockholders to sell their shares without having an adverse effect on market prices. 
 
We have never paid dividends on our common stock and we do not anticipate paying any dividends in the foreseeable future.
 
We have not paid dividends on our common stock to date, and we may not be in a position to pay dividends in the foreseeable future. Our ability to pay dividends depends on our ability to successfully develop our OTEC business and generate revenue from future operations. Further, our initial earnings, if any, will likely be retained to finance our growth. Any future dividends will depend upon our earnings, our then-existing financial requirements and other factors and will be at the discretion of our board of directors (the “Board of Directors”).
 
 
14
 
 
Because our common stock is a “penny stock,” it may be difficult to sell shares of our common stock at times and prices that are acceptable.
 
Our common stock is a “penny stock.” Broker-dealers who sell penny stocks must provide purchasers of these stocks with a standardized risk disclosure document prepared by the SEC. This document provides information about penny stocks and the nature and level of risks involved in investing in the penny stock market. A broker must also give a purchaser, orally or in writing, bid and offer quotations and information regarding broker and salesperson compensation, make a written determination that the penny stock is a suitable investment for the purchaser, and obtain the purchaser’s written agreement to the purchase. The penny stock rules may make it difficult for you to sell your shares of our common stock. Because of these rules, many brokers choose not to participate in penny stock transactions and there is less trading in penny stocks. Accordingly, you may not always be able to resell shares of our common stock publicly at times and prices that you feel are appropriate.
 
In addition to the “penny stock” rules described above, the Financial Industry Regulatory Authority (known as “FINRA”) has adopted rules that require that in recommending an investment to a customer, a broker-dealer must have reasonable grounds for believing that the investment is suitable for that customer. Prior to recommending speculative low priced securities to their non-institutional customers, broker-dealers must make reasonable efforts to obtain information about the customer’s financial status, tax status, investment objectives and other information. Under interpretations of these rules, FINRA believes that there is a high probability that speculative low priced securities will not be suitable for at least some customers. FINRA requirements make it more difficult for broker-dealers to recommend that their customers buy our common shares, which may limit your ability to buy and sell our stock and have an adverse effect on the market for our shares.
 
Our management concluded that our internal control over financial reporting was not effective as of December 31, 2017. Compliance with public company regulatory requirements, including those relating to our internal control over financial reporting, have and will likely continue to result in significant expenses and, if we are unable to maintain effective internal control over financial reporting in the future, investors may lose confidence in the accuracy and completeness of our financial reports and the market price of our common stock may be negatively affected.
  
As a public reporting company, we are subject to the Sarbanes-Oxley Act of 2002, or Sarbanes-Oxley, as well as to the information and reporting requirements of the Securities Exchange Act of 1934, as amended, or the Exchange Act, and other federal securities laws. As a result, we incur significant legal, accounting, and other expenses, including costs associated with our public company reporting requirements and corporate governance requirements. As an example of public reporting company requirements, we evaluate the effectiveness of disclosure controls and procedures and of our internal control over financing reporting in order to allow management to report on such controls.
 
Our management concluded that our internal control over financial reporting was not effective as of December 31, 2017 due to a failure to maintain an effective control environment, failure of segregation of duties, failure of entity-level controls and our sole executive’s access to cash.
 
If significant deficiencies or other material weaknesses are identified in our internal control over financial reporting that we cannot remediate in a timely manner, investors and others may lose confidence in the reliability of our financial statements and the trading price of our common stock and ability to obtain any necessary equity or debt financing could suffer. This would likely have an adverse effect on the trading price of our common stock and our ability to secure any necessary additional equity or debt financing.
 
 
15
 
 
ITEM 1B. UNRESOLVED STAFF COMMENTS.
 
Not applicable.
 
ITEM 2. PROPERTIES.
 
Our principal corporate offices located at 800 South Queen Street, Lancaster, PA contain approximately 28,000 square feet, and are leased from Queen Street Development Partners, LLP at $10,000 per month. Our lease is renewed annually.
 
 
ITEM 3. LEGAL PROCEEDINGS.
 
From time to time, we are involved in legal proceedings and regulatory proceedings arising from operations. We establish reserves for specific liabilities in connection with legal actions that management deems to be probable and estimable.
 
                In late 2016, we entered into a binding agreement with an investor group from Memphis, Tennessee to invest a substantial amount of capital into our company (the “Memphis Investors”). As part of the agreement, we were restricted from making changes to our capital structure and, consequently, suffered significant financial damages when the investors did not honor their commitment and defaulted on the agreement. On May 16, 2017, we filed a civil suit in the United States District Court in the Western District of Tennessee. On March 12, 2018, the Company reached a settlement of the claims at issue in Ocean Thermal Energy Corp. v. Robert Coe et al., Case No. 2:17-cv-02343SHL-cgc, before the United States District Court for the Western District of Tennessee. The settlement requires the defendants to make a payment of $1,075,000 within 30 days and each side to pay its own legal costs.
 
ITEM 4. MINE SAFETY DISCLOSURES.
 
Not applicable.
 
 
16
 
 
PART II
 
ITEM 5. MARKET FOR REGISTRANT’S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES.
 
Our common stock trades on the OTCQB Marketplace operated by the OTC Markets Group, Inc., or “OTCQB,” under the ticker symbol “CPWR.” The following table sets forth the range of high and low closing bid quotes of our common stock per quarter as reported by the OTCQB for the past two fiscal years ended December 31, 2017 and 2016, respectively, and subsequent fiscal quarter ended March 31, 2018 (through March 20, 2018). All quoted prices reflect inter-dealer prices without retail mark-up, mark-down or commission, adjusted to account for past stock splits, and may not necessarily represent actual transactions:
 
 
 
Low
 
 
High
 
Year Ended December 31, 2018 
 
 
 
 
 
 
     First Quarter (through March 20, 2018)
 $0.12 
 $0.52 
 
    
    
Year Ended December 31, 2017
    
    
     Fourth Quarter
 $0.17 
 $2.25 
     Third Quarter
 $1.00 
 $7.00 
     Second Quarter
 $3.00 
 $12.25 
     First Quarter
 $1.70 
 $17.50 
 
    
    
Year Ended December 31, 2016
    
    
     Fourth Quarter
 $1.025 
 $7.50 
     Third Quarter
 $6.25 
 $7.50 
     Second Quarter
 $5.00 
 $7.50 
     First Quarter
 $7.40 
 $12.50 
 
    
    
 
On December 29, 2017, the closing price per share of our common stock as quoted on the OTCQB was $0.32.
 
Holders
 
As of March 20, 2018, there were approximately 1,508 stockholders.
 
Dividends
 
We have not paid, nor declared, any cash dividends since our inception and do not intend to declare or pay any such dividends in the foreseeable future. Our ability to pay cash dividends is subject to limitations imposed by state law.
 
 
17
 
 
ITEM 6. SELECTED FINANCIAL DATA.
 
Not applicable to a “smaller reporting company” as defined in Item 10(f)(1) of SEC Regulation S-K.
 
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS.
 
You should read the following discussion and analysis of our financial condition and operating results together with our financial statements and related notes included elsewhere in this report. This discussion and analysis and other parts of this report contain forward-looking statements based upon current beliefs, plans and expectations that involve risks, uncertainties and assumptions. Our actual results may differ materially from those anticipated in these forward-looking statements as a result of various factors, including those set forth under “Risk Factors” or in other parts of this report. The last day of our fiscal year is December 31. Our fiscal quarters end on March 31, June 30, September 30, and December 31, and our current fiscal year ended on December 31, 2017.
 
 
Overview
 
We develop projects for renewable power generation, desalinated water production, and air conditioning using our proprietary technologies designed to extract energy from the temperature differences between warm surface water and cold deep water. In addition, our projects provide ancillary products such as potable/bottle water and high-profit aquaculture, mariculture, and agriculture opportunities.
 
We currently have no source of revenue, so as we continue to incur costs we are dependent on external funding in order to continue. We cannot assure that such funding will be available or, if available, can be obtained on acceptable or favorable terms.
 
Our operating expenses consist principally of expenses associated with the development of our projects until we determine that a particular project is feasible. Salaries and wages consist primarily of employee salaries and wages, payroll taxes, and health insurance. Our professional fees are related to consulting, engineering, legal, investor relations, outside accounting, and auditing expenses. General and administrative expenses include travel, insurance, rent, marketing, and miscellaneous office expenses. The interest expense includes interest and discounts related to our loans and notes payable.
 
Description of Expenses
 
General and administrative expenses consist primarily of salaries and related costs for accounting, administration, finance, human resources, and information systems. Professional fees expenses consist primarily of fees related to legal, outside accounting, auditing, and investor relations services.
 
 
18
 
 
Results of Operations
 
Comparison of the years Ended December 31, 2017 and 2016
 
Revenues and Costs of Revenue 
 
We had no revenue for the years ended December 31, 2017 or 2016.
 
We had no cost of revenue for the years ended December 31, 2017 and 2016.
 
Although the net changes and percent changes for our revenues and our cost of revenue for 2017 and 2016 are summarized above, these trends should not be viewed as a definitive indication of our future results.
 
Operating Expenses and Other Expenses
 
During the year ended December 31, 2017, we had salaries and wages of $2,044,882 as compared to $1,237,438 during the same period for 2016. This 65.3% increase of $807,444 was primarily due to employee bonuses of $920,399 that were recorded as salaries, but paid in common stock calculated at the fair value on date of commitment.
 
During the year ended December 31, 2017, we had professional fees of $1,669,202 as compared $1,505,586, during the same period for 2016. This is a 10.9% increase as compared to the prior year.
 
General and administrative expenses of $2,169,577 during the year ended December 31, 2017, as compared to $442,394 during the year ended December 31, 2016, is a 390.4% increase when compared to the prior year. This increase of $1,727,183 is due primarily to fees paid to marketing consulting firms for $1,575,767. In addition, we incurred a debt placement fee of $514,286. These were recorded as general expenses, but paid in common stock calculated at fair value on date of commitment.
 
During the year ended December 31, 2017, we re-priced 14,692,500 warrants and 100,000 options to $0.00 and exercised the warrants and options and issued 14,792,500 shares of common stock. These warrants had a fair value of $6,769,562, which we recognized as an expense in operations.
 
The above factors resulted in an operating loss of $12,702,221, during the year ended December 31, 2017, as compared to $3,429,702 during the same period of 2016, an increase of $9,272,519, or 270.4%. Had our expenses not included a write-off of $6,769,562 related to the exercising of warrant and options during year ended December 31, 2017 and our debt placement and consulting fees of $2,090,052, our loss from operations would have been $3,842,607 for that period as compared to $3,429,702 for the same period in 2016, an increase of 12%.
 
Our interest and debt discount expenses of $659,709 for the year ended December 31, 2017, as compared to $2,678,415 forr the year ended December 31, 2016, was decreased by 75.4% due to reduced amortization of debt discount. In the year of 2016, we expensed $1,644,957 for the amortization of notes payable discount. In 2017, we expensed $1,105,203 as a loss on the settlement of debt and $124,542 as a change in the fair value of a liability.
 
Liquidity and Capital Resources
 
At December 31, 2017, our principal source of liquidity consisted of $425,015 of cash, as compared to $7,495 of cash at December 31, 2016. In addition, our stockholders’ deficiency was $10,509,554 at December 31, 2017, compared to stockholders’ deficit of $8,664,237 at December 31, 2016, an increase in the deficiency of $1,845,317. Our operating loss and retained earnings for the year was impacted greatly by the $6,769,562 warrant expense we incurred when we repriced 14,692,500 warrants and 100,000 options at $0.00.
 
Our operations used net cash of $1,469,169 during the year ended December 31, 2017, as compared to using net cash of $2,057,879 during the year ended December 31, 2016. Major changes between the years 2017 and 2016 were the decrease in the amortization of debt discount of $1,599,997, a decrease of $195,286 in the value of capital assets that were written off because of impairment, an increase the fair value of stock issued for services of $1,884,674, an increase of $920,399 in the fair value of stock issued for employee bonuses, an increase in warrant expense of $6,769,562 incurred when warrants were exercised at zero value, and an increase in accounts payable and accrued expenses of $476,405.
 
Investing activities for the year ended December 31, 2017 and 2016, used cash of $140,613 and $119,722 respectively. Of the amount of cash used, $49,773 reflects the cash paid to TetriDyn Solutions at the time of the merger with Ocean Thermal Energy Corporation. The remaining amount was an increase in our assets under construction.
 
Financing activities provided cash of $2,027,302 for our operations during the year ended December 31, 2017, due to the proceeds we received from issuing common stock for exercised warrants of $748,535, notes payable to related party of $844,178, and notes payable to unrelated parties $490,000.
 
 
19
 
 
Our Capital Resources and Anticipated Requirements
 
As noted above, at December 31, 2017, we had negative working capital (current assets minus current liabilities) of $10,716,255. We are now focusing our efforts on promoting and marketing the OTE technology by developing and executing contracts. We are exploring external funding alternatives, as our current cash is insufficient to fund operations for the next 12 months. Upon the consummation of the merger with TetriDyn Solutions, Inc., which was consummated on May 9, 2017, we now have access to the public markets.
 
In December 2017, the Company entered into a Note and Warrant Purchase Agreement pursuant to which we issued a series of unsecured promissory notes (the “Notes”) to accredited investors, in the aggregate principal amount of $490,000 as of December 31, 2017. The Notes accrue interest at a rate of 10% per annum payable on a quarterly basis and are not convertible into shares of capital stock of the Company. The Notes are payable within five business days after receipt of funds from L2 Capital under the Equity Purchase Agreement equal to 20% of the total funds received by the Company from L2 payable on a pro rata basis to all holders of the Notes. The Company may prepay the Notes in whole or in part without penalty or premium on or before the maturity date of July 30, 2019. In connection with the issuance of the Notes, for each Note purchased the Noteholder will receive a warrant exercised as follows:
 
$10,000 note with a warrant to purchase 2,000 shares
$20,000 note with a warrant to purchase 5,000 shares
$25,000 note with a warrant to purchase 6,500 shares
$30,000 note with a warrant to purchase 8,000 shares
$40,000 note with a warrant to purchase 10,000 shares
$50,000 note with a warrant to purchase 14,000 shares
 
The exercise price per share of the Warrants is equal to Eighty-Five Percent (85%) of the closing price of the Company’s common stock on the day immediately preceding the exercise of the relevant Warrant, subject to adjustment as provided in the Warrant. The Warrant includes a cashless net exercise provision whereby the holder can elect to receive shares equal to the value of the Warrant minus the fair market value of shares being surrendered to pay the exercise. As of December 31, 2017, the balance outstanding was $490,000, the accrued interest was $613, and we had issued Warrants to purchase 134,000 shares of common stock. We determined that the warrants had a fair value of $41,044 based on the Black-Scholes option-pricing model. The fair value was recorded as a discount on the notes payable and is being amortized over the life of the notes payable. On January 16, 2018, 28,000 warrants were exercised at an average value of $0.2805 per share for a total of $7,854. On February 27, 2018, 2,000 warrants were exercised at an average value of $0.1785 per share for a total of $357.
 
On December 11, 2017, the Company entered into an equity purchase agreement with L2 Capital, LLC for up to $15,000,000. On January 5, 2018, we issued 1,714,285 shares of common stock valued at $514,286 as a commitment fee in connection with the agreement. The shares to be issued pursuant to this agreement were covered by a Form S-1 Registration Statement approved the Securities and Exchange Commission (SEC) and effective on January 29, 2018. As of the date of this filing, no “put” options were exercised. 
 
On February 15, 2018, the Company entered into an agreement with L2 Capital, LLC (L2), a Kansas limited liability company, for a loan of up to $565,555, together with interest at the rate of eight percent (8%) per annum (with the understanding that the initial six months of such interest of each tranche funded shall be guaranteed), at maturity or upon acceleration or otherwise, as set forth herein (the “Note”). The consideration to the Company for this Note is up to $500,000.00 due to the prorated original issuance discount of up to $55,555 (the “OID”) and a $10,000.00 credit for L2’s transactional expenses. As of the date of this filing, we have received two tranches totaling $204,444, which were allocated as follows: Original Issuance Discount - $19,444; L2’s Transaction Fee - $10,000; Broker-Dealer’s Fee - $14,000; Net Proceeds to Company - $161,000.
 
We are pursuing the acquisition of a leading international engineering and technology company in our industry. The company designs and manufactures patented accessories to provide better stability, protection, and securitization of floating offshore structures such as those we have designed for use with our OTEC and Desal systems. On February 8, 2018, we made an offer to acquire the company, which has been accepted and we are currently in the due diligence stage and securing the funding for the acquisition. 
 
We have no significant contractual obligations or commercial commitments not reflected on our balance sheet as of this date
  
Critical Accounting policies
 
We have identified the policies outlined below as critical to our business operations and an understanding of our results of operations. The list is not intended to be a comprehensive list of all of our accounting policies. In many cases, the accounting treatment of a particular transaction is specifically dictated by accounting principles generally accepted in the United States, with no need for management’s judgment in their application. The impact and any associated risks related to these policies on our business operations is discussed throughout Management’s Discussion and Analysis of Financial Condition and Results of Operations when such policies affect our reported and expected financial results. For a detailed discussion on the application of these and other accounting policies, see the notes to our December 31, 2017 consolidated financial statements. Note that our preparation of the consolidated financial statements requires us to make estimates and assumptions that affect the reported amount of assets and liabilities, disclosure of contingent assets and liabilities at the date of our consolidated financial statements, and the reported amounts of revenue and expenses during the reporting period. We cannot assure that actual results will not differ from those estimates.
 
Revenue Recognition
 
We will recognize revenue on arrangements in accordance with FASB ASC Topic 605, “Revenue Recognition.” In all cases, revenue is recognized only when the price is fixed and determinable, persuasive evidence of an arrangement exists, the service is performed, and collectability of the resulting receivable is reasonably assured.
 
Income Taxes
 
We use the liability method of accounting for income taxes. Under the liability method, deferred tax assets and liabilities are determined based on temporary differences between financial reporting and tax bases of assets and liabilities and on the amount of operating loss carry-forwards and are measured using the enacted tax rates and laws that will be in effect when the temporary differences and carry-forwards are expected to reverse. An allowance against deferred tax assets is recorded when it is more likely than not that such tax benefits will not be realized.
 
 
20
 
 
Recent Accounting Pronouncements    
 
In August 2016, the FASB issued ASU 2016-15, Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments. Historically, there has been diversity in practice in how certain cash receipts/payments are presented and classified in the statement of cash flows under Topic 230. The purpose of the Update is to reduce the existing diversity in practice by clarifying the presentation of certain types of transactions. The amendments in this Update are effective for public business entities for fiscal years beginning after December 15, 2017, and interim periods within those fiscal years. Early adoption is permitted. The Company notes that this guidance applies to its reporting requirements and will implement the new guidance accordingly.
 
We have reviewed all recently issued, but not yet adopted, accounting standards in order to determine their effects, if any, on our consolidated results of operations, financial position, and cash flows. Based on that review, we believe that none of these pronouncements will have a significant effect on current or future earnings or operations.
 
Off-Balance Sheet Arrangements
 
We do not have any off-balance sheet arrangements, financings, or other relationships with unconsolidated entities or other persons, also known as “special purpose entities.”
 
Capitalization Policy
 
Furniture, vehicles, equipment, and software are recorded at cost and include major expenditures, which increase productivity or substantially increase useful lives. Maintenance, repairs, and minor replacements are charged to expenses when incurred. When furniture, vehicles, and equipment are sold or otherwise disposed of, the asset and related accumulated depreciation are removed from this account, and any gain or loss is included in the statement of operations. The cost of furniture, vehicles, equipment, and software is depreciated over the estimated useful lives of the related assets.
 
Assets under construction represent costs incurred by us for our renewable energy systems currently in process. We capitalize costs incurred once the project has met the project feasibility stage. Costs include environmental engineering, permits, government approval costs, and site engineering costs. We currently have two projects in the development stage and one project in the construction phase. We capitalize direct interest costs associated with the projects.
 
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK.
 
Not applicable to a “smaller reporting company” as defined in Item 10(f)(1) of SEC Regulation S-K.
 
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA.
 
Our consolidated financial statements, including the Report of Independent Registered Public Accounting Firm on our consolidated financial statements, are included beginning on page F-1 of this report, which are incorporated herein by reference.
 
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE.
 
None.
 
 
21
 
ITEM 9A. CONTROLS AND PROCEDURES.
 
Evaluation of Disclosure Controls and Procedures
 
We maintain disclosure controls and procedures that are designed to ensure that information required to be disclosed by us, in the reports that we file or submit to the SEC under the Securities Exchange Act of 1934, as amended (the “Exchange Act”), is recorded, processed, summarized, and reported within the periods specified by the SEC’s rules and forms and that information is
accumulated and communicated to our management, including our principal executive and principal financial officer (whom we refer to in this periodic report as our Certifying Officer), as appropriate to allow timely decisions regarding required disclosure. Our management is responsible for establishing and maintaining adequate internal control over financial reporting. Our management evaluated, with the participation of our Certifying Officer, the effectiveness of our disclosure controls and procedures (as defined in Rule 13a-15(e) under the Exchange Act) as of December 31, 2017 pursuant to Rule 13a-15(b) under the Exchange Act. Based upon that evaluation, our Certifying Officer concluded that, as of December 31, 2017, our disclosure controls and procedures were not effective to provide reasonable assurance because certain deficiencies involving internal controls constituted material weaknesses, as discussed below. The material weaknesses identified did not result in the restatement of any previously reported financial statements or any other related financial disclosure, and management does not believe that the material weaknesses had any effect on the accuracy of our financial statements for the current reporting period.
 
Limitations on Effectiveness of Controls
 
A system of controls, however well designed and operated, can provide only reasonable, and not absolute, assurance that the system will meet its objectives. The design of a control system is based, in part, upon the benefits of the control system relative to its costs. Control systems can be circumvented by the individual acts of some persons, by collusion of two or more people, or by management override of the control. In addition, over time, controls may become inadequate because of changes in conditions, or the degree of compliance with the policies or procedures may deteriorate. In addition, the design of any control system is based in part upon assumptions about the likelihood of future events.
 
Changes in Internal Control over Financial Reporting
 
There were no changes in our internal control over financial reporting that occurred during the fourth quarter of fiscal year 2017 that materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.
 
Management’s Annual Report on Internal Control over Financial Reporting
 
Our management is responsible for establishing and maintaining adequate internal control over financial reporting as defined in Rule 13a-15(f) under the Exchange Act. We have assessed the effectiveness of those internal controls as of December 31, 2017, using the Committee of Sponsoring Organizations of the Treadway Commission (“COSO”) Internal Control—Integrated Framework (2013) as a basis for our assessment.
 
Because of inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Therefore, even those systems determined to be effective can provide only reasonable assurance respecting financial statement preparation and presentation. Further, the design of a control system must reflect the fact that there are resource constraints, and the benefits of controls must be considered relative to their costs.
 
A material weakness in internal controls is a deficiency in internal control, or combination of control deficiencies, that adversely affects our ability to initiate, authorize, record, process, or report external financial data reliably in accordance with accounting principles generally accepted in the United States of America such that there is more than a remote likelihood that a material misstatement of our annual or interim financial statements that is more than inconsequential will not be prevented or detected.
 
Based on our evaluation of internal control over financial reporting, our management concluded that our internal control over financial reporting was not effective as of December 31, 2017.
 
As of December 31, 2017, management identified the following material weaknesses:
 
Control Environment - We did not maintain an effective control environment for internal control over financial reporting.
 
Segregation of Duties - As a result of limited resources and staff, we did not maintain proper segregation of incompatible duties. The effect of the lack of segregation of duties potentially affects multiple processes and procedures.
  
Entity Level Controls - We failed to maintain certain entity-level controls as defined by the 2013 framework issued by COSO. Specifically, our lack of staff does not allow us to effectively maintain a sufficient number of adequately trained personnel necessary to anticipate and identify risks critical to financial reporting. There is a risk that a material misstatement of the financial statements could be caused, or at least not be detected in a timely manner, due to lack of adequate staff with such expertise.
 
Access to Cash - One executive had the ability to transfer from our bank accounts.
 
             These weaknesses are continuing. Management and the board of directors are aware of these weaknesses that result because of limited resources and staff. Management has begun the process of formally documenting our key processes as a starting point for improved internal control over financial reporting. Efforts to fully implement the processes we have designed have been put on hold due to limited resources, but we anticipate a renewed focus on this effort in the near future. Due to our limited financial and managerial resources, we cannot assure when we will be able to implement effective internal controls over financial reporting.
 
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 rules of the Securities and Exchange Commission that permit us to provide only management’s report in this annual report.
 
 
22
 
 
Inherent limitations on effectiveness of controls
 
Internal control over financial reporting has inherent limitations which include but is not limited to the use of independent professionals for advice and guidance, interpretation of existing and/or changing rules and principles, segregation of management duties, scale of organization, and personnel factors. Internal control over financial reporting is a process, which involves human diligence and compliance and is subject to lapses in judgment and breakdowns resulting from human failures. Internal control over financial reporting also can be circumvented by collusion or improper management override. Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements on a timely basis, however these inherent limitations are known features of the financial reporting process and it is possible to design into the process safeguards to reduce, though not eliminate, this risk. Therefore, even those systems determined to be effective can provide only reasonable assurance with respect to financial statement preparation and presentation. Projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.
 
ITEM 9B. OTHER INFORMATION
 
None.
PART III
 
ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE.
 
The following table sets forth the names, ages, and positions of our executive officers and directors as of March 20, 2018. There are no arrangements, agreements or understandings between non-management security holders and management under which non-management security holders may directly or indirectly participate in or influence the management of our affairs. There are no arrangements or understandings between any director and any other person pursuant to which any director or executive officer was or is to be selected as a director or executive officer, as applicable. There currently are no legal proceedings, and during the past ten years there have been no legal proceedings that are material to the evaluation of the ability or integrity of any of our directors.
 
Name
Age
Position
Jeremy P. Feakins
64
Chairman of the Board, Chief Executive Officer, Chief Financial Officer and Secretary/Treasurer
Peter H. Wolfson
53
Director
Antoinette K. Hempstead
53
Director
 
 Jeremy P. Feakins has served as our chief executive officer, chief financial officer, and secretary/treasurer since March 2015. Mr. Feakins has over 35 years of experience as an entrepreneur and investor, having founded two technology-based companies. Between 1990 and 2006, Mr. Feakins was the chairman and chief executive officer of Medical Technology & Innovations, Inc. (MTI), a developer and manufacturer of a microprocessor-based, vision-screening device and other medical devices located in Lancaster, PA. In 1996, he managed the public listing of MTI on the over-the-counter markets and subsequently structured the sale of the rights to MTI’s vision-screening product to a major international eyewear company. Between 1998 and 2006, he was a managing member of Growth Capital Resources LLC, a venture capital company located in Lancaster, PA, where he successfully managed the public listings for four small companies on the over-the-counter market. Between 2005 and 2008, he served as executive vice chairman and member of the board of directors of Caspian International Oil Corporation (OTC: COIC), an oil exploration and services company located in Houston, TX and Almaty, KZ, where he managed its public listing. Since 2008, Mr. Feakins has been the chairman and managing partner of the JPF Venture Fund 1, LP, an early-stage venture capital company located in Lancaster, PA, focused on companies involved with humanitarian and/or sustainability projects. Since 2014, Mr. Feakins has been chairman and chief executive officer of JPF Venture Group, Inc. JPF Venture Group, Inc., provides strategic and operational business assistance to start-up, early-stage, and middle-market high-growth businesses and is a principal stockholder of our stock. Mr. Feakins graduated from the Defence College of Logistics and Personnel Administration, Shrivenham, UK, and served seven years in the British Royal Navy. He is a member of the Institute of Directors in the United Kingdom and the British American Business Council in the United States. Based on his background in the technology industry and his financial and management background, the Board of Directors has concluded that Mr. Feakins is qualified to serve as a member of our Board of Directors.
 
 
23
 
 
Peter Wolfson has served as one of our directors since March 2015. Mr. Wolfson is also the founder, president, and chief executive officer of Hans Construction, a developer and builder of upscale homes located in Lancaster, PA. Mr. Wolfson is a qualified commercial pilot at a major U.S.-owned international airline company and has over 30 years’ experience in the aviation business. He also has 10 years’ experience as a financial consultant with a subsidiary of Mass Mutual, developing financial strategies and tax planning. Based on his financial background, the Board of Directors has concluded that Mr. Wolfson is qualified to serve as a member of our Board of Directors.
 
Antoinette Knapp Hempstead was appointed as a Director in February 2017. Prior to that, Ms. Hempstead served as our Chief Executive Officer and President from April 2013 until March 2015 and as our Deputy Chief Executive Officer and Vice President since August 2002. Ms. Hempstead has over 30 years’ experience in management, software management, software development, and finance. Ms. Hempstead has also served as adjunct faculty for University of Idaho where she taught Computer Science courses. Ms. Hempstead has a Master’s degree in Computer Science from the University of Idaho and a Bachelor’s of Science Degree in Applied Mathematics from the University of Idaho. Ms. Hempstead provides to our Board of Directors experience in software development and project management, as well as experience in financial statement preparation and regulatory reporting. Based on her technical background, the Board of Directors has concluded that Ms. Hempstead is qualified to serve as a member of our Board of Directors.
 
Director Independence and Board of Directors’ Committees
 
Other than Peter Wolfson, none of our directors is considered to be an independent member of our Board of Directors under the rules of Nasdaq.
 
Our board as a whole has acted as our audit committee, compensation committee, and nominating committee.
 
Committees and Terms
 
The Board of Directors has not established any committees.
 
Code of Ethics
 
We have adopted a code of ethics that applies to all of our employees, including our executive officers, a copy of which is included as an exhibit to this report.
 
Corporate Governance Matters
 
We have not adopted any material changes to the procedures by which security holders may recommend nominees to our board of directors.
  
 
24
 
 
ITEM 11. EXECUTIVE COMPENSATION
 
The following table sets forth, for the fiscal years ended December 31, 2017 and 2016, the dollar value of all cash and noncash compensation earned by any person that was our principal executive officer, or PEO, during the preceding fiscal year.
 
Summary Executive Compensation Table:
 
Name and principal position
Year ended
December 31
 
Salary ($)
 
 
Bonus ($)
 
 
Stock Awards ($)
 
 
Option Awards ($)
 
 
Non-Equity Incentive Plan Compensation ($)
 
 
Nonqualified Deferred Compensation Earnings ($)
 
 
All Other Compensation ($)
 
 
Total ($)
 
Jeremy Feakins (1)
2017
 381,110
  0 
  581,571 
  0 
  0 
  0 
  0 
 962,681
 Jeremy Feakins
2016
 247,917
  0 
 0
  0 
  0 
  0 
  0 
 247,917
 
The table above does not include prerequisites and other personal benefits in amounts less than 10% of the total annual salary and other compensation.
  
(1)
Jeremy Feakins is the Company’s Principal Executive Officer, Principal Financial Officer and a Director.
 
 
Narrative Disclosure to Summary Compensation Table
 
                On January 1, 2011, Ocean Thermal energy Corporation entered into a five-year employment agreement with an individual to serve as our chief executive officer. The employment agreement provides for successive one-year term renewals unless it is expressly cancelled by either party 100 days prior to the end of the term. Under the agreement, the chief executive officer will receive an annual salary of $350,000, a car allowance of $12,000, and Company-paid health insurance. The agreement also provides for bonuses equal to one times annual salary plus 500,000 shares of common stock for each additional project that generates $25 million or more revenue to us. The chief executive officer is entitled to receive severance pay in the lesser amount of three years’ salary or 100% of the remaining salary if the remaining term is less than three years. As of December 31, 2017, we issued 258,476 shares of common stock, with a fair value of $581,571, to compensate the chief executive officer for his performance.
 
                On June 29, 2017, the Board of Directors approved extending the employment agreements for the chief executive officer for an additional five (5) years. The salary and other compensation shall be increased to account for inflation since the original employment agreements were executed and became effective June 30, 2017.
 
Outstanding Equity Awards at Fiscal Year-End
 
No stock option awards were exercisable or unexercisable as of December 31, 2017, for any executive officer.
 
Director Compensation
 
Mr. Feakins, who is our chief executive officer, received no compensation for his service as a director. The compensation received by Mr. Feakins as an officer is presented in “Executive Compensation – Summary Compensation Table.”
 
For the year ending December 31, 2017, no compensation was awarded to, earned by or paid to our main non-employee directors.
 
 
25
 
 
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS.
 
The following table sets forth certain information regarding the beneficial ownership of our outstanding Common Stock, as of March 20, 2018, by: (i) each of our directors, (ii) each of our named executive officers (as defined by Item 402(a)(3) of Regulation S-K promulgated under the Exchange Act), (iii) all of our directors and named executive officers as a group, and (iv) each person known to us to beneficially own more than 5% of our outstanding Common Stock.
 
Beneficial ownership has been determined in accordance with Rule 13d-3 under the Exchange Act. The percentages in the table have been calculated on the basis of treating as outstanding for a particular person, all shares of our common stock outstanding on that date and all shares of our common stock issuable to that holder in the event of exercise of outstanding options, warrants, rights or conversion privileges owned by that person at that date which are exercisable within sixty (60) days of that date. Except as otherwise indicated, the persons listed below have sole voting and investment power with respect to all shares of our Common Stock owned by them, except to the extent that power may be shared with a spouse. The Company does not know of any arrangements the operation of which may at a subsequent date result in a change of control of the Company.
 
Name and Address of Person or Group (1)
Number of Shares of Common Stock Beneficially Owned
Percent of Common Stock Beneficially Owned
 
 
 
5% or Greater Stockholders
 
 
Steve Oney (2)
7,648,000
6.2%
 
 
 
Directors and Executive Officers
 
 
Jeremy P. Feakins (3)
17,836,236
13.9%
Antoinette Hempstead (4)
115,151
*
Peter H. Wolfson (5)
2,088,981
  1.7%
Executive Officers and Directors as a Group (3 persons):
20,040,368
15.5%
 
   * Less than 1%
 
(1)
800 South Queen Street, Lancaster, PA 17603, is the address for all stockholders in the table. Applicable percentages are based on 122,672,247 shares of our common stock outstanding on March 20, 2018, and are calculated as required by rules promulgated by the SEC.   
(2)
Consists of 7,648,000 shares of common stock owned of record by Steve Oney.
(3)
Consists of (i) 8,097,211 shares of common stock owned of record by Jeremy P. Feakins, (ii) 4,320,131 shares of common stock owned of record by JPF Venture Group, Inc., which is an investment entity that is majority-owned and controlled by Jeremy P. Feakins, and, as such, is deemed to be beneficially owned by Mr. Feakins, and (iii) 5,418,894 shares of common stock issuable to JPF Venture Group, Inc. on the conversion of (a) a $50,000 promissory note dated November 2015, convertible at $0.01384 per share into 3,612,596 shares of common stock (the “November 2015 Note”); and (b) a $25,000 promissory note dated December 2016, convertible at $0.01384 per share into 1,806,298 shares of common stock (the “December 2016 Note” and together with the November 2015 Note, the “Notes”). All calculations in this footnote are based on conversion of the principal only.
(4)
Consists of (i) 452 shares of common stock owned of record by Antoinette Hempstead and (ii) 114,699 shares of common stock owned of record by A.R. Hempstead Revocable Trust which is owned and controlled by Ms. Hempstead and, as such, is deemed to be the beneficial owner of record.  Ms. Hempstead is a member of the Board of Directors of the Company.
(5)
Consists of (i) 1,185,833 shares of common stock owned of record by Peter H. Wolfson and (ii) 903,148 shares of common stock issuable to Mr. Wolfson on the conversion of a $12,500 promissory note dated October 2016, convertible at $0.01384 per share into shares of common stock (the “October 2016 Note”). Mr. Wolfson is a member of the Board of Directors of the Company.
 
 
26
 
 
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS AND DIRECTOR INDEPENDENCE.
 
Related-Party Loans
 
On February 16, 2017, the due date of the Jeremy P. Feakins & Associates, LLC, an investment entity that is majority-owned by Jeremy Feakins, the Company’s director, chief executive officer, and chief financial officer note payable in the amount of $2,265,000 issued on January 31, 2015, was extended to December 31, 2018. On August 15, 2017, $618,500 of the note payable was converted into 618,500 shares of common stock. In addition, they converted accrued interest in the amount of $207,731 for 207,731 shares of common stock. The remaining balance on the note payable as of December 31, 2017 is $1,137,500 and the accrued interest is $399,692.
 
On March 6, 2018, the due date of the related party note payable in the amount of $1,000,000 issued on February 3, 2012, was extended to December 31, 2018.
 
On March 9, 2017, we issued a promissory note payable of $200,000 to a related party in which our chief executive officer is an officer and director. The note bears interest of 10% and is due and payable within 90 days after demand. The balance outstanding on December 31, 2017, is $177,000.
 
On March 31, 2017, we made a repayment of note payable to a related party in the amount of $25,000.
 
On May 8, 2017, JPF Venture Group, Inc. (“JPF”), an investment entity that is majority-owned by Jeremy Feakins, the Company’s director, chief executive officer, and chief financial officer transferred 148,588 shares of common stock for $111,440 to the Company to fulfill an over commitment of “D” warrants.
 
On June 5, 2017, a note holder elected to convert a $25,000 convertible note payable for 1,806,298 shares of common stock ($0.014 per share).
 
On September 8, 2017, JPF Venture Group, Inc. (“JPF”), an investment entity that is majority-owned by Jeremy Feakins, the Company’s director, chief executive officer, and chief financial officer, elected to convert $50,000 in notes payable for 3,612,596 shares of common stock at a conversion rate of $0.014. In addition, accrued interest in the amount of $6,342 was converted to 458,198 shares.
 
On November 6, 2017, the Company entered into an agreement with a promissory note with JPF Venture Group, Inc. (“JPF”), an investment entity that is majority-owned by Jeremy Feakins, the Company’s director, chief executive officer, and chief financial officer, to loan the Company up to $2,000,000. The terms of the note are as follows: (i) interest is payable at 10% per annum; (ii) all unpaid principal and all accrued and unpaid interest shall be due and payable at the earliest of (a) resolution of the Memphis litigation; (b) June 30, 2018; or (c) when the company is otherwise able to pay. As of December 31, 2017, the outstanding balance was $641,568 and the accrued interest was $14,372.
 
On November 8, 2017, Jeremy P. Feakins & Associates, LLC, an investment entity that is majority-owned by Jeremy Feakins, the Company’s director, chief executive officer, and chief financial officer, a Series B note holder, elected to convert $50,000 in notes payable for 50,000 shares of common stock at a conversion rate of $1.00. In addition, they converted accrued interest in the amount of $16,263 for 16,263 shares
 
As part of the merger between Ocean Thermal Energy Corporation and TetriDyn Solutions, Inc. (“TDYS”) on May 8, 2017, the Company assumed the loans made to “TDYS” by JPF Venture Group, Inc., an investment entity that is majority owned by Jeremy Feakins, the Company’s director, chief executive officer, and chief financial officer. As of December 31, 2017, the outstanding balance of all loans was $581,880.
 
On December 28, 2017, we entered into a Note and Warrant Purchase Agreement pursuant to which we issued a series of unsecured promissory notes (the “Notes”) to accredited investors, in the aggregate principal amount of $535,000 as of January 8, 2018. The Notes accrue interest at a rate of 10% per annum payable on a quarterly basis and are not convertible into shares of capital stock of the Company (See Page 18 for details).
 
The Note dated February 16, 2017 to Jeremy P. Feakins & Associates, LLC, an investment entity that is majority-owned by Jeremy Feakins, the Company’s director, chief executive officer, and chief financial officer was reduced by $15,000 for the payment of principal on January 4, 2018, reducing the outstanding balance to $1,122,500.
  
Related-Party Transactions
 
For the year ended December 31, 2017, we paid rent of $95,000 to a company controlled by our chief executive officer under an operating lease agreement.
  
Director Independence
 
Our securities are not listed on a national securities exchange or in an inter-dealer quotation system, which has requirements that directors be independent. Therefore, we have adopted the independence standards of Nasdaq, to determine the independence of our directors and those directors serving on our committees. These standards provide that a person will be considered an independent director if he or she is not an officer of the company and is, in the view of the company’s board of directors, free of any relationship that would interfere with the exercise of independent judgment. Our board of directors has determined that as of the date of this Report, Mr. Wolfson is our only independent director.
 
 27
 
 
ITEM 14. PRINCIPAL ACCOUNTING FEES AND SERVICES.
 
Principal Accountant Fees and Services
 
The aggregate fees for professional services rendered to us by Liggett & Webb, P.A., our independent registered public accounting firm, for the fiscal years ended December 31, 2017 and 2016 were as follows:
 
 
 
Year Ended December 31,
 
 
 
2017
 
 
2016
 
Audit fees (1)
 $37,800 
 $46,538 
Audit-Related fees
  - 
  - 
Tax fees
  - 
  - 
Other fees
  - 
  - 
Total fees
 $37,800
 
 $46,538 
 
(1)
Includes fees for (i) audits of our consolidated financial statements for the fiscal years ended December 31, 2017 and 2016, (ii) review of our interim period financial statements for fiscal year 2017, and (iii) fees related to services normally provided by the accountant in connection with statutory and regulatory filings or engagements.
 
Audit and Non-Audit Service Preapproval Policy
 
In accordance with the requirements of the Sarbanes-Oxley Act of 2002 and the rules and regulations promulgated thereunder, the audit committee has adopted an informal approval policy that it believes will result in an effective and efficient procedure to preapprove services performed by the independent registered public accounting firm.
 
Audit Services. Audit services include the annual financial statement audit (including quarterly reviews) and other procedures required to be performed by the independent registered public accounting firm to be able to form an opinion on our consolidated financial statements. The audit committee preapproves specified annual audit services engagement terms and fees and other specified audit fees. All other audit services must be specifically preapproved by the audit committee. The audit committee monitors the audit services engagement and may approve, if necessary, any changes in terms, conditions, and fees resulting from changes in audit scope or other items.
 
Audit-Related Services. Audit-related services are assurance and related services that are reasonably related to the performance of the audit or review of our consolidated financial statements, which historically have been provided to us by the independent registered public accounting firm and are consistent with the SEC’s rules on auditor independence. The audit committee has approved specified audit-related services within preapproved fee levels. All other audit-related services must be preapproved by the audit committee.
 
Tax Services. The audit committee preapproves specified tax services that the audit committee believes would not impair the independence of the independent registered public accounting firm and that are consistent with Securities and Exchange Commission’s rules and guidance. The audit committee must specifically approve all other tax services.
 
All Other Services. Other services are services provided by the independent registered public accounting firm that do not fall within the established audit, audit-related, and tax services categories. The audit committee preapproves specified other services that do not fall within any of the specified prohibited categories of services.
 
Procedures. All proposals for services to be provided by the independent registered public accounting firm, which must include a detailed description of the services to be rendered and the amount of corresponding fees, are submitted to the chairman of the audit committee and the Chief Financial Officer. The Chief Financial Officer authorizes services that have been preapproved by the audit committee. If there is any question as to whether a proposed service fits within a preapproved service, the audit committee chair is consulted for a determination. The Chief Financial Officer submits requests or applications to provide services that have not been preapproved by the audit committee, which must include an affirmation by the Chief Financial Officer and the independent registered public accounting firm that the request or application is consistent with the Securities and Exchange Commission’s rules on auditor independence, to the audit committee (or its chair or any of its other members pursuant to delegated authority) for approval.
 
PART IV
 
ITEM 15. EXHIBITS, FINANCIAL STATEMENT SCHEDULES.
 
1. 
Financial Statements.
 
The financial statements of Ocean Thermal Energy Corporation, together with the report thereon of Liggett & Webb, P.A., an independent registered public accounting firm, are included in this Annual Report on Form 10-K.
 
2. 
Financial Statement Schedules.
 
All schedules are omitted because they are not applicable or the required information is shown in the financial statements or notes thereto.
 
3. 
Exhibits
 
A list of exhibits is set forth on the Exhibit Index immediately preceding the signature page of this Annual Report on Form 10-K and is incorporated herein by reference.
 
 
28
 
 
OCEAN THERMAL ENERGY CORPORATION
 
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
AND
CONSOLIDATED FINANCIAL STATEMENTS
 
DECEMBER 31, 2017 and 2016
 
 
  
Report of Independent Registered Public Accounting Firm
 
 
 
 
 
 
Consolidated Balance Sheets as of December 31, 2017 and December 31, 2016
 
 
 
 
 
 
Consolidated Statements of Operations for the Years Ended December 31, 2017 and 2016
 
 
 
 
 
 
Consolidated Statements of Stockholders’ Deficiency for the Years Ended December 31, 2017 and 2016
 
 
  
 
 
 
Consolidated Statements of Cash Flows for the Years Ended December 31, 2017 and 2016
 
 
 
 
 
 
Notes to Consolidated Financial Statements
 
 
 
 
 
 

 
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
 
To the Shareholders and Board of Directors of:
Ocean Thermal Energy Corporation
 
 
Opinion on the Financial Statements
 
We have audited the accompanying consolidated balance sheets of Ocean Thermal Energy Corporation and Subsidiaries (the “Company”) as of December 31, 2017 and 2016, the related consolidated statements of operations, changes in stockholders’ equity and cash flows for each of the two years in the period ended December 31, 2017, and the related notes. In our opinion, the consolidated financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2017 and 2016, and the results of its operations and its cash flows for the years ended December 31, 2017 and 2016, in conformity with accounting principles generally accepted in the United States of America.
 
Explanatory Paragraph – Going Concern
 
The accompanying consolidated 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 a net loss of $14,591,675, a working capital deficiency of $10,716,255, and an accumulated deficit of $67,703,218. These factors raise substantial doubt about the Company's ability to continue as a going concern. Management’s plans in regard to these matters are described in Note 2. The consolidated financial statements do not include any adjustments that might result from the outcome of this uncertainty
 
Basis for Opinion
 
These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on the Company’s financial statements based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (“PCAOB”) and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
 
We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud. The Company is not required to have, nor were we engaged to perform, an audit of its internal controls over financial reporting. Accordingly, we express no such opinion.
 
Our audits included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.
 
 
/s/ Liggett & Webb, P.A.
LIGGETT & WEBB, P.A.
Certified Public Accountants
 
We have served as the Company’s auditor since 2008
 
Boynton Beach, Florida
April 2, 2018
 
 
F -2
 
 
 
OCEAN THERMAL ENERGY CORPORATION AND SUBSIDIARIES
 
 
(FOMERLY KNOWN AS TETRIDYN SOLUTIONS, INC)
 
 
CONSOLIDATED BALANCE SHEETS
 
 
AS OF DECEMBER 31, 2017 AND DECEMBER 31, 2016
 
 
 
 
 
 
 
 
 
 
2017
 
 
2016
 
ASSETS
 
 
 
 
 
 
Current Assets
 
 
 
 
 
 
  Cash
 $425,015 
 $7,495 
  Prepaid expenses
  25,000 
  30,549 
         Total Current Assets
  450,015 
  38,044 
 
    
    
Property and Equipment
    
    
  Property and equipment, net
  1,352 
  2,366 
  Assets under construction
  892,639 
  846,285 
        Property and Equipment, net
  893,991 
  848,651 
 
    
    
Total Assets
 $1,344,006 
 $886,695 
 
    
    
LIABILITIES AND STOCKHOLDERS' DEFICIENCY
    
    
 
    
    
Current Liabilities
    
    
 Accounts payables and accrued expense
 $6,846,010 
 $5,631,270 
Due to related party
  - 
  36,822 
 Notes payable - related party, net
  3,592,948 
  1,886,000 
Convertible notes payable -related party- net
  87,500 
  - 
 Notes payable, net
  589,812 
  300,000 
Convertible notes payable - net
  50,000 
  49,129 
      Total Current Liabilities
  11,166,270 
  7,903,221 
 
    
    
 Notes payable - related party, net
  - 
  1,045,644 
 Notes payable, net
  607,290 
  602,067 
Notes payable, convertible
  80,000 
  - 
Total Liabilities
  11,853,560 
  9,550,932 
 
    
    
Commitments and Contingencies (See Note 7)
    
    
 
    
    
Stockholders' deficiency
    
    
  Preferred Stock, $0.001 par value; 5,000,000 shares authorized,
  - 
  - 
        0 and 0 shares issued and outstanding, respectively
    
    
  Common stock, $0.001 par value; 200,000,000 shares authorized,
    
    
      122,642,247 and 94,343,776 shares issued and outstanding, respectively
  122,642 
  94,344 
   Additional paid-in capital
  57,071,022 
  44,352,962 
  Accumulated deficit
  (67,703,218)
  (53,111,543)
Total Stockholders' Deficiency
  (10,509,554)
  (8,664,237)
 
    
    
Total Liabilities and Stockholders' Deficiency
 $1,344,006 
 $886,695 
 
    
    
 
The accompanying notes are an integral part of these consolidated financial statements.
 
 
 
F -3
 
 
 
OCEAN THERMAL ENERGY CORPORATION AND SUBSIDARIES
 
 
(FOMERLY KNOWN AS TETRIDYN SOLUTIONS, INC)
 
 
 CONSOLIDATED STATEMENTS OF OPERATIONS
 
 
FOR THE YEARS ENDED DECEMBER 31, 2017 AND DECEMBER 31, 2016
 
 
 
 
 
 
 
 
 
 
2017
 
 
2016
 
Operating Expenses
 
 
 
 
 
 
  Salaries and wages
 $2,044,882 
 $1,237,438 
  Professional fees
  1,669,202 
  1,505,586 
  General and administrative
  2,169,577 
  442,394 
  Warrant Expense
  6,769,562 
  - 
  Impairment of Assets
  48,998 
  244,284 
   Total Operating Expenses
  12,702,221 
  3,429,702 
 
    
    
Loss from Operations
  (12,702,221)
  (3,429,702)
 
    
    
Other Expenses
    
    
  Interest Expense and amortization of debt discount
  (659,709)
  (2,678,415)
  Loss on settlement of debt and accounts payable
  (1,105,203)
  - 
Change in fair value of liability
  (124,542)
  - 
   Total Other expenses
  (1,889,454)
  (2,678,415)
 
    
    
Loss Before Income Taxes
  (14,591,675)
  (6,108,117)
 
    
    
Provision for Income Taxes
  - 
  - 
 
    
    
   Net Loss
 $(14,591,675)
 $(6,108,117)
 
    
    
Net Loss per Common Share
    
    
  Basic and Diluted
 $(0.13)
 $(0.07)
 
    
    
Weighted Average Number of Common Shares Outstanding
  111,735,383 
  83,236,245 
 
    
    
 
The accompanying notes are an integral part of these consolidated financial statements.
 
 
 
 
F -4
 
 
 
OCEAN THERMAL ENERGY CORPORATION AND SUBSIDIARIES
 
 
(FOMERLY KNOWN AS TETRIDYN SOLUTIONS, INC)
 
 
CONSOLIDATED STATEMENT OF CHANGES IN STOCKHOLDERS' DEFICIENCY
 
 
FOR THE YEARS ENDED DECEMBER 31, 2017 AND DECEMBER 31, 2016
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Total
 
 
 
Preferred Stock
 
 
Common Stock
 
 
Paid In
 
 
Accumulated
 
 
Stockholders'
 
 
 
Shares
 
 
Amount
 
 
Shares
 
 
Amount
 
 
Capital
 
 
Deficit
 
 
Deficiency
 
Balance, December 31, 2015
  - 
 $- 
  82,623,066 
 $82,623 
 $38,722,035 
 $(47,003,426)
 $(8,198,768)
Stock issued for $0.50 warrants
    
    
  1,380,000 
  1,380 
  688,620 
  - 
  690,000 
Stock issued for $0.75 warrants
    
    
  455,666 
  456 
  341,294 
    
  341,750 
Stock issued for $0.25 warrants
    
    
  8,000,000 
  8,000 
  1,992,000 
    
  2,000,000 
Stock issued for services
    
    
  1,197,753 
  1,198 
  1,016,892 
  - 
  1,018,090 
Stock issued for accrued interest
    
    
  687,291 
  687 
  583,511 
    
  584,198 
Debt discount on the JPF VF note
    
    
  - 
  - 
  1,008,610 
  - 
  1,008,610 
Net Loss
    
    
  - 
  - 
    
  (6,108,117)
  (6,108,117)
Balance, December 31, 2016
  - 
 $- 
  94,343,776 
 $94,344 
 $44,352,962 
 $(53,111,543)
 $(8,664,237)
 
Warrants and Options Exercised at $0.00: 1/1/17 to 5/8/17 (prior to merger)
 
  14,792,500 
  14,793 
  (14,793)
    
  - 
 
D Warrants Exercised at $0.75: 1/1/17 to 5/8/17 (prior to merger)
 
  998,079 
  998 
  747,537 
    
  748,535 
 
Stock issued for services and commitment fee
 
    
  3,887,802 
  3,888 
  2,898,876 
    
  2,902,764 
Stock issued for cash
    
    
  11,250 
  11 
  44,989 
    
  45,000 
 
Stock issued for conversion of note payable and accrued interest
 
  7,386,872 
  7,387 
  2,348,008 
    
  2,355,395 
Stock repurchased from related parties
    
    
  (148,588)
  (149)
  (111,291)
    
  (111,440)
 
Stock issued for conversion of accounts payable
 
    
  425,000 
  425 
  702,700 
    
  703,125 
Stock issued for employee bonuses
    
    
  409,066 
  409 
  919,990 
    
  920,399 
Stock issued for TetriDyn Solutions, Inc.
    
    
  536,490 
  536 
  (1,628,562)
    
  (1,628,026)
FV of warrant modifications
    
    
    
    
  6,769,562 
    
  6,769,562 
 
Beneficial conversion feature on notes payable
 
    
    
    
  41,044 
    
  41,044 
Net Loss
    
    
    
    
    
  (14,591,675)
  (14,591,675)
Balance, December 31, 2017
  - 
 $- 
  122,642,247 
 $122,642 
 $57,071,022 
 $(67,703,218)
 $(10,509,554)
 
    
    
    
    
    
    
    
 
The accompanying notes are an integral part of these consolidated financial statements.
 
 
 
F -5
 
 
 
OCEAN THERMAL ENERGY CORPORATION AND SUBSIDIARIES
 
 
(FOMERLY KNOW AS TETRIDYN SOLUTIONS, INC)
 
 
CONSOLIDATED STATEMENT OF CASH FLOWS
 
 
FOR THE YEARS ENDED DECEMBER 31, 2017 AND DECEMBER 31, 2016
 
 
 
 
 
 
 
2017
 
 
2016
 
Cash Flows From Operating Activities:
 
 
 
 
 
 
Net loss
 $(14,591,675)
 $(6,108,117)
Adjustments to reconcile net loss to net cash used in operating activities
    
    
Depreciation
  1,014 
  4,207 
Impairment of assets under construction
  48,998 
  244,284 
Stock issued for services
  2,902,764 
  1,018,090 
Stock issued for bonuses
  920,399 
    
Change in fair value of liability
  124,542 
    
Loss on settlement of debt
  1,105,203 
  412,374 
Warrant Expense
  6,769,562 
  - 
Amortization of debt discounts
  44,960 
  1,644,957 
Changes in assets and liabilities:
    
    
   Other current assets
  - 
  24,542 
       Prepaid expenses
  5,549 
  (21,326)
       Accounts payable and accrued expenses
  1,199,515 
  723,110 
   Net Cash Used In Operating Activities
  (1,469,169)
  (2,057,879)
 
    
    
Cash Flow From Investing Activities:
    
    
   Cash acquired in acquisition
  4,512 
  - 
   Assets under construction
  (95,352)
  (119,722)
   Payments for acquisition
  (49,773)
  - 
   Net Cash Used In Investing Activities
  (140,613)
  (119,722)
 
    
    
Cash Flows From Financing Activities:
    
    
    Repayment of notes payable - related party
  (64,432)
  (5,000)
    Repayment of government loans
  (4,539)
    
    Proceeds from notes payable
  490,000 
  999,025 
    Proceeds from notes payable, convertible
  80,000 
  - 
    Proceeds from issuance of common stock for cash
  45,000 
  1,031,750 
    Proceeds from notes payable - related party
  844,178 
    
    Proceeds from due to related party
  - 
  36,822 
    Stock repurchased from related parties
  (111,440)
  - 
    Stock issued for exercise of warants for cash
  748,535 
  - 
    Repayment of capital lease
  - 
  (2,530)
   Net Cash Provided by Financing Activities
  2,027,302 
  2,060,067 
 
    
    
Net increase (decrease) in cash and cash equivalents
  417,520 
  (117,534)
Cash and cash equivalents at beginning of year
  7,495 
  125,029 
   Cash and Cash Equivalents at End of Period
 $425,015 
 $7,495 
 
    
    
Supplemental disclosure of cash flow information
    
    
Cash paid for interest expense
 $17,162 
 $45,849 
Cash paid for income taxes
 $- 
 $- 
 
    
    
Supplemental disclosure of non-cash investing and financing activities:
    
    
Convertible note payable and accrued interest -related party converted to common stock
 $80,275 
 $- 
Accrued interest on related-party note converted to common stock
 $- 
 $171,823 
Exercise of warrants in lieu of repayment of related-party note payable
 $- 
 $2,000,000 
Debt discount on related-party note payable and extension of warrants
 $- 
 $1,008,610 
Note Payable and accrued interest converted into common stock
 $878,292 
 $- 
Note Payable and accrued interest - related party converted into common stock
 $668,500 
 $- 
Due to related party, converted into note payable - related party
 $38,822 
 $- 
Accounts payable convertewd into common stock
 $326,250 
 $- 
Debt discount on notes payable
 $41,044 
 $- 
        On May 9, 2017, the company issued 536,490 shares of common stock to the former shareholders of TetriDyn Solutions Inc.
    
    
        for the assumption of $617,032 of accrued expenses and $1,015,506 of convertible notes and notes payable from related and
    
    
        unrelated parties. The company recorded a debit of $1,628,026 to the additional paid in capital.
    
    
 
    
    
 
The accompanying notes are an integral part of these consolidated financial statements.
 
 
 
F -6
 
 
OCEAN THERMAL ENERGY CORPORATION AND SUBSIDIARIES
(FORMERLY KNOWN AS TETRIDYN SOLUTIONS, INC)
 
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
 
FOR THE YEARS ENDED DECEMBER 31, 2017 AND DECEMBER 31, 2016
 
NOTE 1 – SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES AND ORGANIZATION
 
(A). Source of Business and Basis of Presentation
 
Ocean Thermal Energy Corporation (“Ocean Thermal”, the “Company”, “we”, and “us”) is currently in the business of designing Ocean Thermal Energy Conversion (“OTEC”) power plants and Seawater Air Conditioning (“SWAC”) plants for large commercial properties, utilities and municipalities. These technologies provide practical solutions to mankind’s three oldest and most fundamental needs: clean drinking water, plentiful food, and sustainable, affordable energy without the use of fossil fuels. OTEC is a clean technology that continuously extracts energy from the temperature difference between warm surface ocean water and cold deep seawater. In addition to producing electricity, some of the seawater running through an OTEC plant can be efficiently desalinated using the power generated by the OTEC technology, producing thousands of cubic meters of fresh water every day for the communities served by its plants for use in agriculture and human consumption. This cold deep nutrient-rich water can also be used to cool buildings (SWAC) and for fish farming/ aquaculture. In short, it’s a technology with many benefits, and its versatility makes OTEC unique.
 
The Company previously operated under the corporate name of TetriDyn Solutions, Inc. (“TetriDyn”). On March 10, 2017, TetriDyn entered into an Agreement and Plan of Merger (the “Merger Agreement”) with Ocean Thermal Energy Corporation, a Delaware corporation (“OTE”). On May 9, 2017, TetriDyn consummated the acquisition of all outstanding equity interests of OTE pursuant to the terms of the Merger Agreement, with a newly-created Delaware corporation that is wholly-owned by TetriDyn (“TetriDyn Merger Sub”), merging with and into OTE (the “Merger”) and OTE continuing as the surviving corporation and a wholly-owned subsidiary of TetriDyn. Effective upon the consummation of the Merger (the “Closing”), the OTE Stock issued and outstanding or existing immediately prior to the Closing of the Merger was converted at the Closing into the right to receive newly issued shares of TetriDyn common stock. As a result of the Merger, TetriDyn succeeded to the business and operations of OTE. In connection with the consummation of the Merger and upon the consent of the holders of a majority of the outstanding common shares, TetriDyn filed with the Nevada Secretary of State an amendment to its articles of incorporation changing its name to “Ocean Thermal Energy Corporation”.
 
On April 13, 2017, the Company filed a Schedule 14C Information Statement with the Securities and Exchange Commission (the “Commission”) to notify stockholders that the following actions were approved without a meeting of the stockholders:
 
An amendment to our Articles of Incorporation, as amended, to effect a change in the Company’s name from TetriDyn Solutions, Inc. to Ocean Thermal Energy Corporation;
An amendment to our Articles of Incorporation, as amended, to effect and authorize 5,000,000 shares of preferred stock and 200,000,000 shares of common stock; and
An amendment to our Articles of Incorporation, as amended, to effect a forward stock split of the issued and outstanding shares of common stock of the Company on an approximately 2.1676-for-1 basis.
 
On May 25, 2017, the Company received approval from the Financial Industry Regulatory Authority (“FINRA”) to change the trading symbol for the Company’s common stock to “CPWR” from “TDYS.” The Company’s common stock began formally trading under the symbol “CPWR” on June 21, 2017.
  
For accounting purposes, this transaction is being accounted for as a reverse merger and has been treated as a recapitalization of Tetridyn Solutions, Inc. with Ocean Thermal Energy Corporation as the accounting acquirer. The historical financial statements of the accounting acquirer became the financial statements of the Company. The Company did not recognize goodwill or any intangible assets in connection with the transaction. The 110,273,767 shares issued to the shareholder of OTE in conjunction with the share exchange transaction has been presented as outstanding for all periods. The historical financial statements include the operations of the accounting acquirer for all periods presented and the accounting acquiree for the period from May 9, 2017 through December 31, 2017. The Company’s accounting year end is December 31, which was the year end of Ocean Thermal Energy Corporation.
 
The consolidated financial statements include the accounts of the Company and our wholly-owned subsidiaries. Intercompany accounts and transactions have been eliminated in consolidation. In the opinion of management, our financial statements reflect all adjustments that are of a normal recurring nature necessary for presentation of financial statements for interim periods in accordance with U.S. generally accepted accounting principles (GAAP) and with the instructions to Form 10-K in Article 10 of SEC Regulation S-X. The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities at the date of our financial statements, and the reported amounts of revenue and expenses during the reporting periods. Actual results could differ from those estimates.
 
(B)            
Principal Subsidiary Undertakings
 F -7
 
 
Our consolidated financial statements for the years ended December 31, 2017 and 2016, include the following subsidiaries:
 
Name
Place of Incorporation / Establishment
Principal Activities
Date Formed
Ocean Thermal Energy Bahamas Ltd.
Bahamas
Intermediate holding company of OTE BM Ltd. and OTE Bahamas O&M Ltd.
07/04/2011
 
 
 
 
OTE BM Ltd.
Bahamas
OTEC/SDC development in the Bahamas
09/07/2011
 
 
 
 
OCEES International Inc.
Hawaii, USA
Research and development for the Pacific Rim
01/21/1998
 
 
 
 
Ocean Thermal Energy UK Limited
England and Wales
Dormant
07/22/2010
 
 
 
 
OTEC Innovation Group Inc.
Delaware, USA
Dormant
06/02/2011
 
 
 
 
OTE-BM Energy Partners LLC
Delaware, USA
Dormant
06/02/2011
 
 
 
 
OTE Bahamas O&M Ltd.
Bahamas
Dormant
09/07/2011
 
 
 
 
Ocean Thermal Energy Holdings Ltd.
Bahamas
Dormant
03/05/2012
 
 
 
 
Ocean Thermal Energy Cayman Ltd.
Caymans
Dormant
03/26/2013
 
 
 
 
OTE HC Ltd.
Caymans
Dormant
03/26/2013
 
 
 
 
Ocean Thermal Energy USVI, Inc.
Virgin Islands
Dormant
07/12/2016
 
 
We have an effective interest of 100% in each of our subsidiaries.
 
(C)            
Use of Estimates
 
In preparing financial statements in conformity with generally accepted accounting principles, management is required to make estimates and assumptions that affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities at the date of the financial statements and revenues and expenses during the reported period. Actual results could differ from those estimates. Significant estimates include the assumptions used in valuing equity investments and issuances, valuation of deferred tax assets, and depreciable lives of property and equipment.
 
(D)            
Cash and Cash Equivalents
 
We consider all highly liquid temporary cash investments with an original maturity of three months or less to be cash equivalents. At December 31, 2017 and 2016, we had no cash equivalents.
 
(E)            
Income Taxes
 
We account for income taxes under Financial Accounting Standards Board (“FASB”) Accounting Standards Codification (“ASC”) Topic 740-10-25, “Income Taxes—Overall—Recognition.” Under ASC 740-10-25, deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. Under ASC 740-10-25, the effect on deferred tax assets and liabilities of a change in tax rates is recognized in income in the period that includes the enactment date.
 
Our 2013 to 2017 tax years remain open to audit by the Internal Revenue Service and state tax authorities.
 
(F)            
Business Segments
 
We conduct operations in various foreign jurisdictions that use our technology. Our segments are based on the location of their operations. The U.S. territories segment consists of operations in the U.S. Virgin Islands and Guam; the Bahamas segment consists of operations specific to the Bahamas; and the other segment currently consists of operations in the Cayman Islands. Direct revenues and costs, depreciation, depletion, and amortization costs, general and administrative costs (“G&A”), and other income directly associated with their respective segments are detailed within the following discussion. Identifiable net property and equipment are reported by business segment for management reporting and reportable business segment disclosure purposes. Current assets, other assets, current liabilities, and long-term debt are not allocated to business segments for management reporting or business segment disclosure purposes.
 
Reportable business segment information for the years ended December 31, 2017, and December 31, 2016, is as follows:
 
 
December 31, 2017
 
 
 
Headquarters
 
 
US Territories
 
 
Bahamas
 
 
Other
 
 
Total
 
Revenue
 $- 
 $- 
 $- 
 $- 
 $- 
Assets
  451,367 
  892,639 
    
  - 
  1,344,006 
Net loss
  (14,591,675)
  - 
  - 
  - 
  (14,591,675)
Property and equipment
  1,352 
  - 
  - 
  - 
  1,352 
Assets under construction
    
  892,639 
    
  - 
  892,639 
Depreciation
  1,014 
  - 
  - 
  - 
  1,014 
Additions to assets under construction
  - 
  95,352 
  - 
  - 
  95,352 
 
    
    
    
    
    
 
F -8
 
 
 
December 31, 2016
 

 
Headquarters
 
 
US Territories
 
 
Bahamas
 
 
Other
 
 
Total
 
Revenue
 $- 
 $- 
 $- 
 $- 
 $- 
Assets
  40,410 
  797,287 
  - 
  48,998 
  886,695 
Net Loss
  (5,837,007)
  - 
  (271,110)
  - 
  (6,108,117)
Property and equipment
  2,366 
  - 
  - 
  - 
  2,366 
Capitalized construction in process
    
  797,287 
  - 
  48,998 
  846,285 
Depreciation
  4,207 
  - 
  - 
  - 
  4,207 
Additions to assets under construction
  - 
  119,722 
  - 
  - 
  119,722 
 
For the year ended December 31, 2017, the U.S. territories are comprised of U.S. Virgin Islands project (approx. $728,000) and Guam project (approx. $165,000). Other territories are comprised of Cayman Islands project); however during the year ended December 31, 2017, $48,998 of Cayman Islands assets under construction was considered to be impaired due to the uncertainty of the project and were written off. The additions to assets under construction in 2017 were primarily salaries and consulting services.
 
For the year ended December 31, 2016, the U.S. territories are comprised of U.S. Virgin Islands project (approx. $632,000) and Guam project (approx. $165,000). Other territories are comprised of Cayman Islands project (approx. $49,000).
 
(G)            
Property and Equipment
 
Furniture, equipment, and software are recorded at cost and include major expenditures that increase productivity or substantially increase useful lives.
 
Maintenance, repairs, and minor replacements are charged to expenses when incurred. When furniture, vehicles, or equipment is sold or otherwise disposed of, the asset and related accumulated depreciation are removed from this account, and any gain or loss is included in the statement of operations.
 
Assets under construction represent costs incurred by us for our renewable energy systems currently in process. Generally, all costs incurred during the development stage of our projects are capitalized and tracked on an individual project basis and are included in construction in progress until the project has been placed into service. If a project is abandoned, the associated costs that have been capitalized are charged to expense in the year of abandonment. Expenditures for repairs and maintenance are charged to expense as incurred. Interest costs incurred during the construction period of defined major projects from debt that is specifically incurred for those projects are capitalized.
 
 
F -9
 
 
 
Direct labor costs incurred for specific major projects expected to have long-term benefits are capitalized. Direct labor costs subject to capitalization include employee salaries, as well as related payroll taxes and benefits. With respect to the allocation of salaries to projects, salaries are allocated based on the percentage of hours that our key managers, engineers, and scientists work on each project. These individuals track their time worked at each project. Major projects are generally defined as projects expected to exceed $500,000. Direct labor includes all of the time incurred by employees directly involved with construction and development activities. Time spent in general and indirect management and in evaluating the feasibility of potential projects is expensed when incurred.
 
We capitalize costs incurred once the project has met the project feasibility stage. Costs include environmental engineering, permits, government approval, and site engineering costs. We currently have four projects in the development stage and one project in the construction phase. We capitalize direct interest costs associated with the projects. As of December 31, 2017 and 2016, we have no interest costs capitalized.
 
The cost of furniture, vehicles, equipment, and software is depreciated over the estimated useful lives of the related assets.
 
Depreciation is computed using the straight-line method for financial reporting purposes. The estimated useful lives and accumulated depreciation for land, buildings, furniture, vehicles, equipment, and software are as follows:
 
 
 
Years
 
Computer Equipment
  3 
Software
  5 
 
(H)           Fair Value
 
ASC Topic 820, “Fair Value Measurements and Disclosures,” defines fair value, establishes a framework for measuring fair value under generally accepted accounting principles in the United States, and enhances disclosures about fair value measurements. ASC 820 describes a fair value hierarchy based on three levels of inputs, of which the first two are considered observable and the last unobservable, that may be used to measure fair value, which are the following:
 
Level 1–Pricing inputs are quoted prices available in active markets for identical assets or liabilities as of the reporting date.
 
Level 2–Pricing inputs are quoted for similar assets or inputs that are observable, either directly or indirectly, for substantially the full term through corroboration with observable market data. Level 2 includes assets or liabilities valued at quoted prices adjusted for legal or contractual restrictions specific to these investments.
 
Level 3–Pricing inputs are unobservable for the assets or liabilities; that is, the inputs reflect the reporting entity’s own assumptions about the assumptions market participants would use in pricing the asset or liability.
 
Management believes the carrying amounts of the short-term financial instruments, including cash and cash equivalents, accounts receivable, prepaid expense and other assets, accounts payable, accrued liabilities, notes payable, deferred compensation, and other liabilities reflected in the accompanying balance sheets approximate fair value at December 31, 2016 and 2015, due to the relatively short-term nature of these instruments.
 
(I)            
Concentrations
 
Cash and cash equivalents and restricted cash are deposited with major financial institutions, and at times, such balances with any one financial institution may be in excess of FDIC-insured limits. As of December 31, 2017 and 2016, $179,855 and $0 were deposited in excess of FDIC-insured limits. Management believes the risk in these situations to be minimal.
 
(J)            
Loss per Share
 
The basic loss per share is calculated by dividing our net loss available to common shareholders by the weighted average number of common shares during the period. The diluted loss per share is calculated by dividing our net loss by the diluted weighted average number of shares outstanding during the period. The diluted weighted average number of shares outstanding is the basic weighted number of shares adjusted for any potentially dilutive debt or equity. We have 134,000 and 16,012,210 shares issuable upon the exercise of warrants and options and 7,056,721 and 205,667 shares issuable upon the conversion of the green energy bonds and convertible notes that were not included in the computation of dilutive loss per share because their inclusion is antidilutive for the years ended December 31, 2017 and 2016, respectively.
 
(K)            
Revenue Recognition
 
We will recognize revenue on arrangements in accordance with FASB ASC Topic 605, “Revenue Recognition.” In all cases, revenue is recognized only when the price is fixed and determinable, persuasive evidence of an arrangement exists, the service is performed, and collectability of the resulting receivable is reasonably assured.
 
(L)            
Recent Accounting Pronouncements
 
In August 2016, the FASB issued ASU 2016-15, Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments. Historically, there has been a diversity in practice in how certain cash receipts/payments are presented and classified in the statement of cash flows under Topic 230. The purpose of the Update is to reduce the existing diversity in practice by clarifying the presentation of certain types of transactions. The amendments in this Update are effective for public business entities for fiscal years beginning after December 15, 2017, and interim periods within those fiscal years. Early adoption is permitted. The Company notes that this guidance applies to its reporting requirements and will implement the new guidance accordingly.
 
We have reviewed all recently issued, but not yet adopted, accounting standards in order to determine their effects, if any, on our consolidated results of operations, financial position, and cash flows. Based on that review, we believe that none of these pronouncements will have a significant effect on current or future earnings or operations.
 
 
 
F -10
 
 
 
NOTE 2 – GOING CONCERN
 
We had a net loss of $14,591,675 and used cash in operations of $1,469,169 for the year ended December 31, 2017, and had an accumulated deficit of $67,703,218 and a working capital deficiency of $10,716,255 as of December 31, 2017. This raises substantial doubt about our ability to continue as a going concern. Our ability to continue as a going concern is dependent on our ability to raise additional capital through the sale of debt or equity securities or stockholder loans and to implement our business plan. The financial statements do not include any adjustments that might be necessary if we are unable to continue as a going concern.
 
Management believes that we will be able to continue as a going concern through additional affiliate loans, implementation of our strategic operating plan, continuing a multi-focused plan to obtain external capital, and offering sales incentives to accelerate ocean thermal energy conversion (“OTEC”) project development.
  
NOTE 3 – PROPERTY AND EQUIPMENT
Property and equipment consist of the following at December 31, 2017:
 
 
Property & Equipment as of December 31, 2017
 
 
 
 
 
 
 
Estimated
 
 
 
 
 
Accumulated
 
 
Net Book
 
Useful Life
 
 
Cost
 
 
Depreciation
 
 
Value
 
 Life
Computer & Office Equipment
 $13,751 
  12,399 
 $1,352 
 3 Years
Software (Video System)
  19,061 
  19,061 
  - 
 5 Years
Construction in Process
  892,639 
    
  892,639 
 
 
 $925,451 
  31,460 
 $893,991 
 
 
 
Property and equipment consist of the following at December 31, 2016:
 
 
Property & Equipment as of December 31, 2016
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Estimated
 
 
 
 
 
Accumulated
 
 
Net Book
 
Useful Life
 
 
Cost
 
 
Depreciation
 
 
Value
 
 Life
Computer & Office Equipment
 $13,751 
  11,385 
 $2,366 
3 Years
Software (Video System)
  19,061 
  19,061 
  - 
5 Years
Construction in Process
  846,285 
    
  846,285 
 
 
 $879,097 
  30,446 
 $848,651 
 
 
 
Depreciation expense for the years ended December 31, 2017 and 2016 was $1,014 and $4,207, respectively. During the year ended December 31, 2016, $244,284 of Clifton Pier assets under construction were considered to be impaired due to the uncertainty of the project. During the year ended December 31, 2017, $48,998 of Cayman Islands assets under construction was considered to be impaired due to the uncertainty of the project and were written off.
 
 NOTE 4 – CONVERTIBLE NOTES AND NOTES PAYABLE
 
On December 12, 2006, TetriDyn Solutions, Inc. (TDYS) borrowed funds from the Southeast Idaho Council of Governments (SICOG). This is referred as the “EDA -#180” loan. At the time of the merger between TDYS and Ocean Thermal Energy Corporation (OTE) on May 8, 2017, OTE assumed the liability for this loan. The remaining balance on the loan at the date of merger was $14,974. The interest rate is 6.25% and the maturity date was January 5, 2013. The loan principal was $12,272 with no accrued interest as of December 31, 2017. This note is in default.
 
On December 1, 2007, TetriDyn Solutions, Inc. (TDYS) borrowed funds from the Eastern Idaho Development Corporation; this is referred as the “EIDC ” loan. At the time of the merger between TDYS and Ocean Thermal Energy Corporation (OTE) on May 8, 2017, OTE assumed the liability for this loan. The remaining balance on the loan at the date of merger was $85,821. The interest rate is 7% and the maturity date was September 1, 2015. The loan principal was $85,821 with accrued interest of $33,323 as of December 31, 2017. This note is in default.
 
On September 25, 2009, TetriDyn Solutions, Inc. (TDYS) borrowed funds from the Pocatello Development Authority. At the time of the merger between TDYS and Ocean Thermal Energy Corporation (OTE) on May 8, 2017, OTE assumed the liability for this loan. The remaining balance on the loan at the date of merger was $50,000. The interest rate is 5% and the maturity date was October 25, 2011. The loan principal was $50,000 with accrued interest of $18,206 as of December 31, 2017. This note is in default.
 
On December 23, 2009, TetriDyn Solutions, Inc. (TDYS) borrowed funds from the Southeast Idaho Council of Governments (SICOG). This is referred as the “EDA - #273” loan. At the time of the merger between TDYS and Ocean Thermal Energy Corporation (OTE) on May 8, 2017, OTE assumed the liability for this loan. The remaining balance on the loan at the date of merger was $94,480. The interest rate is 7% and the maturity date was December 23, 2014. The loan principal was $94,480 with accrued interest of $21,150 as of December 31, 2017. This note is in default.
 
 
F -11
 
 
On December 23, 2009, TetriDyn Solutions, Inc. (TDYS) borrowed funds from the Southeast Idaho Council of Governments (SICOG). This is referred as the “MICRO I - #274” loan. At the time of the merger between TDYS and Ocean Thermal Energy Corporation (OTE) on May 8, 2017, OTE assumed the liability for this loan. The remaining balance on the loan at the date of merger was $23,619. The interest rate is 7% and the maturity date was December 23, 2014. The loan principal was $23,619 with accrued interest of $4,596 as of December 31, 2017. This note is in default.
 
On December 23, 2009, TetriDyn Solutions, Inc. (TDYS) borrowed funds from the Southeast Idaho Council of Governments (SICOG). This is referred as the “MICRO II - #275” loan. At the time of the merger between TDYS and Ocean Thermal Energy Corporation (OTE) on May 8, 2017, OTE assumed the liability for this loan. The remaining balance on the loan at the date of merger was $23,620. The interest rate is 7% and the maturity date was December 23, 2014. The loan principal was $23,620 with accrued interest of $5,897 as of December 31, 2017. This note is in default.
 
During 2012, we issued a note payable for $1,000,000 and three-year warrants to purchase 3,295,761 shares of common stock with an exercise price of $0.50 per share. The note had an interest rate of 10% per annum, was secured by a first lien in all of our assets and was due on February 3, 2015. We determined the warrants had a fair value of $378,500 based on the Black-Scholes option-pricing model. The fair value was recorded as a discount on the note payable and was being amortized over the life of the note. We repriced the warrants during 2013 and took an additional charge to earnings of $1,269,380 related to the repricing. The warrants were exercised upon the repricing. On March 6, 2018, the note holder agreed to amend the note to extend the due date of the note to December 31, 2018. As of December 31, 2017, the outstanding balance was $1,000,000, plus accrued interest of $535,559.
 
During 2013, we issued Series B units. Each unit is comprised of a note agreement, a $50,000 promissory note that matures on September 30, 2023, and bears interest at 10% per annum payable annually in arrears, a security agreement, and a warrant to purchase 10,000 shares of common stock at an exercise price to be determined pursuant to a specified formula. During 2013, we issued $525,000 of 10% promissory notes and warrants to purchase 105,000 shares of common stock. The warrants have an expiration date of September 30, 2023. We determined the warrants had a fair value of $60,068 based on the Black-Scholes option-pricing model. As part of our agreement with the Memphis Investors, the Board repriced the warrants to $0.00 and exercised the warrants and issued shares of common stock. On December 31, 2016, the accrued interest was $168,934. During 2015, one of the original note holders transferred its ownership of the note in the amount of $50,000 to Jeremy P. Feakins & Associates LLC through the JPF Venture Fund 1, LP. On August 15, 2017, loans in the amount of $316,666 and accrued interest of $120,898 were converted to 437,564 shares at $1.00 per share, which was ratified by the Board of Directors. The shares were recorded at fair value of $1,165,892. The Company recorded a loss on settlement of debt of $728,328 on conversion date. On November 8, 2017, Jeremy P. Feakins & Associates LLC, converted loans in the amount of $50,000 and accrued interest of $16,263 at $1.00 per share into 66,263 shares of common stock. As of December 31, 2017, the loan balance was $158,334 and the accrued interest was $68,894.
 
During 2013, we paid cash of $10,000 and issued a note payable for $290,000 in connection with the reverse merger transaction. We repurchased and retired 7,546,464 shares of common stock simultaneously with the closing of the merger with Broad Band Network Associates. The note is unsecured and due the earlier of December 31, 2015, or upon our receiving $50,000 of proceeds from the exercise of the Class A warrants, $50,000 from the exercise of the Class B warrants, $60,000 from the exercise of the Class C warrants, $60,000 from the exercise of Class D warrants, and $70,000 from the exercise of the Class E warrants. During 2014, we paid $100,000 and during 2015, we paid $60,000, leaving a balance of $130,000. Accrued interest totaled $40,313 at December 31, 2017 and $29,769 at December 31, 2016. We have determined that no further payment of principal or interest on this note should be made because the note holder failed to perform his underlying obligations giving rise to this note. As such, we are confident that if the note holder were to seek legal redress, a court would decide in our favor by either voiding the note or awarding damages sufficient to offset the note value.
 
 
F -12
 
 
During 2014, we issued a note payable for $2,265,000 and warrants to purchase 12,912,500 shares of common stock, with an exercise price equal to the greater of a 50% discount of the stock price when our shares are listed on a public exchange or $0.425 per share, to an entity owned by our chief executive officer, together our principal stockholders. The warrants expire one year after our shares are listed on a recognized public exchange. The unsecured note has an interest rate of 10% per annum and the balance was due on January 31, 2015. We determined the warrants had a fair value of $2,265,000 based on the Black-Scholes option-pricing model. The fair value was recorded as a discount on the note payable and is being amortized over the life of the note. As part of our agreement with the Memphis Investors, the Board repriced the warrants to $0.00 and exercised the warrants and issued shares of common stock. As of December 31, 2015, principal of $152,500 has been repaid and principal of $351,500 has been converted into 468,667 shares of common stock, leaving a note balance of $1,761,000. During 2016, a principal payment of $5,000 was made leaving a note balance of $1,756,000 at December 31, 2016. On December 31, 2016, the accrued interest was $453,093. On August 15, 2017, loans in the amount of $618,500 and accrued interest of $207,731 were converted to 826,231 shares at $1.00 per share, which was ratified by the Board of Directors. The conversion was recorded at historical cost due to the related party nature of the transaction. As of December 31, 2017, the loan balance was $1,137,500 and the accrued interest was $399,692. On January 18, 2018 the note holder agreed to extend the due date for the repayment of the loan and interest to the earlier of December 31, 2018 or the date for the Ocean Thermal Energy Corporation’s financial closings of its Baha Mar Project (or any other project of $25 million or more), or partial payments will begin as the Company draws upon investment provided by L2 Capital. whichever occurs first. (see note 9)
 
During 2014, we issued Secured Convertible Promissory Notes (Bonds) totaling $166,800 through September 30, 2014. The bonds carry an interest rate ranging from 7.86% to 9.86% and mature on April 30, 2019 and December 31, 2019. In addition, the bondholders are entitled to convert each $1,200 bond into 1,000 shares of common stock at a price of $1.20 per share. Should our shares trade for 10 consecutive days at $1.80 per share or higher. On August 15, 2017, bonds in the amount of $166,800 and accrued interest of $48,866 were converted to 179,722 shares of common stock at $1.20 per share.
 
During 2014, we issued a note payable of $100,000 to a related party and $200,000 to a third party, for a total of $300,000, and warrants to purchase 300,000 shares of common stock with an exercise price of $1.00 per share. As part of our agreement with the Memphis Investors, the Board repriced the warrants to $0.00 and exercised the warrants and issued shares of common stock. These unsecured notes have an interest rate of 12% per annum. The $100,000 note with a related party is due the earlier of December 26, 2015; the completion by us of an equity financing resulting in our receipt of gross proceeds of at least $2,000,000; or the financial close of the Baha Mar project and release of funds by the bank. The balance on the $200,000 note is due the earlier of March 31, 2015; the completion by us of an equity financing resulting in our receipt of gross proceeds of at least $2,000,000; or the financial close of the Baha Mar project and release of project financing funds by the bank. As of December 31, 2016, the notes are in default. Due to the delay in opening of the Baha Mar Resort, our Baha Mar SWAC Project’s financial closing was delayed causing us to default on the notes. We have accrued the interest at a default rate of 22%. We intend to repay the notes and accrued interest upon the project’s financial closing. As of December 31, 2017, the outstanding loan balance was $300,000. Accrued interest totaled $180,129 as of December 31, 2017 and $113,119 as of December 31, 2016.
  
On April 7, 2015, we issued an unsecured convertible promissory note in the principal amount of $50,000 to an unrelated party. The note bears interest of 10% and is due on April 17, 2017. On April 6, 2017, the note holder agreed to extend the maturity date to April 7, 2018. The note and accrued interest can be converted into our common stock at a conversion rate of $0.75 per share at any time prior to the repayment. We recorded a debt discount of $6,667 for the fair value of the beneficial conversion feature. During the year ended December 31, 2017, we amortized debt discount of $871. As of December 31, 2017, the outstanding loan balance was $50,000. Accrued interest totaled $13,847 as of December 31, 2017 and $12,668 as of December 31, 2016.
 
 
F -13
 
 
On March 12, 2015, the Company exchanged convertible notes issued in 2010, 2011, and 2012, payable to its officers and directors in the aggregate principal amount of $320,246, plus accrued but unpaid interest of $74,134, into a single, $394,380 consolidated convertible note (the “Consolidated Note”). The Consolidated Note was assigned to JPF Venture Group, Inc. (“JPF”), an investment entity that is majority-owned by Jeremy Feakins, the Company’s director, chief executive officer, and chief financial officer. The Consolidated Note was convertible to common stock at $0.025 per share, the approximate market price of the Company’s common stock as of the date of the issuance. On February 24, 2017 the Company completed an amendment with JPF to eliminate the conversion feature of the Consolidated Note. The Consolidated Note bears interest at 6% per annum and is due and payable within 90 days after demand. As of December 31, 2017, the outstanding loan balance was $394,380 and the accrued but unpaid interest on the Consolidated Note was $70,568.
 
 On March 12, 2015, the Company assigned the liabilities for unpaid salaries of two of its former officers in the amount of $213,436 to JPF. The assignment was evidenced by a consolidated promissory note dated December 31, 2014. The note does not bear any interest. On December 31, 2016, the $213,436 was reclassified to accrued expenses.
 
On June 23, 2015, the Company borrowed $50,000 from JPF pursuant to a promissory note. The Company received $25,000 on July 31, 2015, and the remaining $25,000 on August 18, 2015. The terms of the note are as follows: (i) interest is payable at 6% per annum; (ii) the note is payable 90 days after demand; and (iii) payee is authorized to convert part or all of the note balance and accrued interest, if any, into shares of the Company’s common stock at the rate of one share for each $0.01384. On September 8, 2017, JPF elected to convert $50,000 of notes payable and accrued interest of $6,342 into 3,612,596 and 458,198 shares of common stock, respectively.
 
On November 23, 2015, the Company borrowed $50,000 from JPF pursuant to a promissory note. The Company received $37,500 before December 31, 2015, and the remaining $12,500 was received after the year-end. The terms of the note are as follows: (i) interest is payable at 6% per annum; (ii) the note is payable 90 days after demand; and (iii) payee is authorized to convert part or all of the note balance and accrued interest, if any, into shares of the Company’s common stock at the rate of one share each for $0.01384. As of December 31, 2017, the outstanding balance was $50,000, plus accrued interest of $6,049.
 
On February 25, 2016, the Company borrowed $50,000 from JPF pursuant to a promissory note. The terms of the note are as follows: (i) interest is payable at 6% per annum; (ii) the note is payable 90 days after demand; and (iii) payee is authorized to convert part or all of the note balance and accrued interest, if any, into shares of our common stock at the rate of one share for each $0.01384. On February 24, 2017 the Company completed an amendment with JPF to eliminate the conversion feature of the note. As of December 31, 2017, the outstanding balance was $50,000, plus accrued interest of $5,636
 
On May 20, 2016, the Company borrowed $50,000 from JPF pursuant to a promissory note. The terms of the note are as follows: (i) interest is payable at 6% per annum; (ii) the note is payable 90 days after demand; and (iii) the payee is authorized to convert part or all of the note balance and accrued interest, if any, into shares of our common stock at the rate of one share for each $0.01384. On February 24, 2017 the Company completed an amendment with JPF to eliminate the conversion feature of the note. As of December 31, 2017, the outstanding balance was $50,000, plus accrued interest of $4,788.
 
On October 20, 2016, the Company borrowed $12,500 from JPF pursuant to a promissory note. The terms of the note are as follows: (i) interest is payable at 6% per annum; (ii) the note is payable 90 days after demand; and (iii) the payee is authorized to convert part or all of the note balance and accrued interest, if any, into shares of our common stock at the rate of one share for each $0.01384. On February 24, 2017 the Company completed an amendment with JPF to eliminate the conversion feature of the note. As of December 31, 2017, the outstanding balance was $12,500, plus accrued interest of $928.
  
 
F -14
 
 
On October 20, 2016, the Company borrowed $12,500 from an independent director pursuant to a promissory note. The terms of the note are as follows: (i) interest is payable at 6% per annum; (ii) the note is payable 90 days after demand; and (iii) the payee is authorized to convert part or all of the note balance and accrued interest, if any, into shares of our common stock at the rate of one share for each $0.01384 of As of December 31, 2017, the outstanding balance was $12,500, plus accrued interest of $994.
 
On October 20, 2016, the Company borrowed $25,000 from a stockholder pursuant to a promissory note. The terms of the note are as follows: (i) interest is payable at 6% per annum; (ii) the note is payable 90 days after demand; and (iii) the payee is authorized to convert part or all of the note balance and accrued interest, if any, into shares of our common stock at the rate of one share for each $0.01384. As of June 5, 2017 the note holder converted the note principal of $25,000 into 1,806,298 shares common stock. As of December 31, 2017, there was no outstanding balance and accrued interest was $904.
.
On December 21, 2016, the Company borrowed $25,000 from JPF pursuant to a promissory note. The terms of the note are as follows: (i) interest is payable at 6% per annum; (ii) the note is payable 90 days after demand; and (iii) the payee is authorized to convert part or all of the note balance and accrued interest, if any, into shares of our common stock at the rate of one share for each $0.01384. As of December 31, 2017, the outstanding balance was $25,000, plus accrued interest of $1,563.
 
On March 9, 2017, an entity owned by our chief executive officer is an officer and director, agreed to provide up to $200,000 in working capital. The note bears interest of 10% and is due and payable with 90 days of demand. As of December 31, 2017, the balance of the loan outstanding was $177,000 and the accrued interest was $14,905.
 
During the third quarter of 2017, the Company launched a $2,000,000 convertible promissory note private placement offering. The terms of the note are as follows: (i) interest is payable at 6% per annum; (ii) the note is payable two years after purchase; (iii) and all principal and interest on each Note shall automatically convert on the Conversion Maturity Date into shares of the Company’s common stock at a conversion price of $4.00 per share, as long as the closing share price of the Company’s common stock on the trading day immediately preceding the Conversion Maturity Date is at least $4.00, as adjusted for stock splits, stock dividends, reclassification, and the like. If the price of the Company’s shares on such date is less than $4.00 per share, the Note (principal and interest) will be repaid in full. As of December 31, 2017, the outstanding balance for all four loans was $80,000, plus accrued interest of $2,186.
 
On November 6, 2017, the Company entered into an agreement with a promissory note with JPF Venture Group, Inc. (“JPF”), an investment entity that is majority-owned by Jeremy Feakins, the Company’s director, chief executive officer, and chief financial officer, to loan the Company up to $2,000,000. The terms of the note are as follows: (i) interest is payable at 10% per annum; (ii) all unpaid principal and all accrued and unpaid interest shall be due and payable at the earliest of (a) resolution of the Memphis litigation; (b) June 30, 2018; or (c) when the company is otherwise able to pay. As of December 31, 2017, the outstanding balance was $641,568 and the accrued interest was $14,372.
 
In December 2017, the Company entered into a Note and Warrant Purchase Agreement pursuant to which we issued a series of unsecured promissory notes (the “Notes”) to accredited investors, in the aggregate principal amount of $490,000 as of December 31, 2017. The Notes accrue interest at a rate of 10% per annum payable on a quarterly basis and are not convertible into shares of capital stock of the Company. The Notes are payable within five business days after receipt of funds from L2 Capital under the Equity Purchase Agreement equal to 20% of the total funds received by the Company from L2 payable on a pro rata basis to all holders of the Notes. The Company may prepay the Notes in whole or in part without penalty or premium on or before the maturity date of July 30, 2019. In connection with the issuance of the Notes, for each Note purchased the Noteholder will receive a warrant exercised as follows:
 
$10,000 note with a warrant to purchase 2,000 shares
$20,000 note with a warrant to purchase 5,000 shares
$25,000 note with a warrant to purchase 6,500 shares
$30,000 note with a warrant to purchase 8,000 shares
$40,000 note with a warrant to purchase 10,000 shares
$50,000 note with a warrant to purchase 14,000 shares
 
The exercise price per share of the Warrants is equal to Eighty-Five Percent (85%) of the closing price of the Company’s common stock on the day immediately preceding the exercise of the relevant Warrant, subject to adjustment as provided in the Warrant. The Warrant includes a cashless net exercise provision whereby the holder can elect to receive shares equal to the value of the Warrant minus the fair market value of shares being surrendered to pay the exercise. As of December 31, 2017, the balance outstanding was $490,000, the accrued interest was $613, and we had issued Warrants to purchase 134,000 shares of common stock. We determined that the warrants had a fair value of $41,044 based on the Black-Scholes option-pricing model. The fair value was recorded as a discount on the notes payable and is being amortized over the life of the notes payable.
 
F -15
 
 
 
The following convertible note and notes payable were outstanding at December 31, 2017:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Related Party
 
 
Non Related Party
 
Date of Issuance
Maturity Date
 
Interest Rate
 
In Default
 
Original Principal
 
 
Principal at December 31, 2017
 
 
Discount at December 31 2017
 
 
Carrying Amount at December 31, 2017
 
 
Current
 
 
Long-Term
 
 
Current
 
 
Long-Term
 
12/12/2006
1/5/2013
  6.25%
 Yes
  58,670 
  12,272 
  - 
  12,272 
  - 
  - 
  12,272 
  - 
12/1/2007
9/1/2015
  7.00%
 Yes
  125,000 
  85,821 
  - 
  85,821 
  - 
  - 
  85,821 
  - 
9/25/2009
10/25/2011
  5.00%
 Yes
  50,000 
  50,000 
  - 
  50,000 
  - 
  - 
  50,000 
  - 
12/23/2009
12/23/2014
  7.00%
 Yes
  100,000 
  94,480 
  - 
  94,480 
  - 
  - 
  94,480 
  - 
12/23/2009
12/23/2014
  7.00%
 Yes
  25,000 
  23,619 
  - 
  23,619 
  - 
  - 
  23,619 
  - 
12/23/2009
12/23/2014
  7.00%
 Yes
  25,000 
  23,620 
  - 
  23,620 
  - 
  - 
  23,620 
  - 
02/03/12
12/31/18
  10.00%
 No
  1,000,000 
  1,000,000