UNITED STATES SECURITIES AND EXCHANGE COMMISSION


Washington D.C., 20549





FORM 10-K





TANNUAL REPORT UNDER SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934





For the fiscal year ended December 31, 2010





£TRANSITION REPORT UNDER SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934





Commission File No. 0-30351





DEEP DOWN, INC.


(Exact name of registrant as specified in its charter)





Nevada

75-2263732(State of other jurisdiction of incorporation)

(I.R.S. Employer Identification No.)8827 W. Sam Houston Pkwy N., Suite 100, Houston, Texas

77040(Address of Principal Executive Office)

(Zip Code)





Registrant’s telephone number, including area code: (281) 517-5000





Securities registered pursuant to Section 12(b) of the Act: NONE





Securities registered pursuant to Section 12(g) of the Act: Common Stock $0.001 par value





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





Indicate by check mark whether the issuer is not required to file reports pursuant to Section 13 or 15(d) of the Act.  Yes o  No þ





Indicate by check mark whether the issuer (1) 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 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 þ  No o





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





Indicate by check mark if disclosures of delinquent filers in response to Item 405 of Regulations S-K is not contained in this form, 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. o





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





Large accelerated filer oAccelerated filer oNon-accelerated filer oSmaller reporting company þ





Indicate by checkmark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).  Yes o  No þ





The aggregate market value of the voting stock and non-voting common equity held by non-affiliates, computed by reference to the price at which the common equity was sold, or the average bid and asked price of such common equity, as of June 30, 2010, the last business day of our most recently completed second quarter, was approximately $8,521,700.





At April 13, 2011, the issuer had 206,399,155 shares outstanding of Common Stock, par value $0.001 per share.




DOCUMENTS INCORPORATED BY REFERENCE


None.








TABLE OF CONTENTS








PART IItem 1
Description of Business
4Item 2
Description of Properties
13Item 3
Legal Proceedings
13PART IIItem 5
Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities
14Item 6
Selected Financial Data
15Item 7
Management’s Discussion and Analysis of Financial Condition and Results of Operations
16Item 7A
Quantitative and Qualitative Disclosures About Market Risk
26Item 8
Financial Statementsand Supplementary Data
26Item 9
Changes in and Disagreements with Accountants on Accounting and Financial Disclosure
26Item 9A
Controls and Procedures
27Item 9B
Other Information
28PART IIIItem 10
Directors, Executive Officers and Corporate Governance
29Item 11
Executive Compensation
32Item 12
Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters
38Item 13
Certain Relationships and Related Transactions, and Director Independence
39Item 14
Principal Accountant Fees and Services
39Item 15
Exhibits
41Signatures
45




2


Forward-Looking Information





Unless otherwise indicated, the terms “Deep Down, Inc.”, “Deep Down”, “Company”, “we”, “our” and “us” are used in this report to refer to Deep Down, Inc., a Nevada corporation, and its wholly-owned subsidiaries.





In this Annual Report on Form 10-K (“the Report”), we may make certain forward-looking statements, including statements regarding our plans, strategies, objectives, expectations, intentions and resources that are made pursuant to the safe harbor provisions of the Private Securities Litigation Reform Act of 1995. We do not undertake to update, revise or correct any of the forward-looking information. The following discussion should also be read in conjunction with the audited consolidated financial statements and the notes thereto.





The statements contained in this Report that are not historical fact are forward-looking statements (as such term is defined in the Private Securities Litigation Reform Act of 1995), within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. The forward-looking statements contained herein are based on current expectations that involve a number of risks and uncertainties. These statements can be identified by the use of forward-looking terminology such as “believes”, “expects”, “may”, “will”, “should”, “intend”, “plan”, “could”, “is likely”, or “anticipates”, or the negative thereof or other variations thereon or comparable terminology, or by discussions of strategy that involve risks and uncertainties. We wish to caution the reader that these forward-looking statements that are not historical facts are only predictions. No assurances can be given that the future results indicated, whether expressed or implied, will be achieved. While sometimes presented with numerical specificity, these projections and other forward-looking statements are based upon a variety of assumptions relating to the business of the Company, which, although considered reasonable by us, may not be realized. Because of the number and range of assumptions underlying our projections and forward-looking statements, many of which are subject to significant uncertainties and contingencies that are beyond the reasonable control of us, some of the assumptions inevitably will not materialize, and unanticipated events and circumstances may occur subsequent to the date of this report. These forward-looking statements are based on current expectations and we assume no obligation to update this information. Therefore, our actual experience and the results achieved during the period covered by any particular projections or forward-looking statements may differ substantially from those projected. Consequently, the inclusion of projections and other forward-looking statements should not be regarded as a representation by us or any other person that these estimates and projections will be realized, and actual results may vary materially. There can be no assurance that any of these expectations will be realized or that any of the forward-looking statements contained herein will prove to be accurate.




3





PART I





ITEM 1.DESCRIPTION OF BUSINESS.





History





Deep Down, Inc. is a Nevada corporation engaged in the oilfield services industry.  As used herein, “Deep Down”, “Company”, “we”, “our” and “us” may refer to Deep Down, Inc. and/or its subsidiaries.  Deep Down, Inc. (OTCBB:DPDW), a publicly traded Nevada corporation, was incorporated on December 14, 2006, through a reverse merger with MediQuip Holdings, Inc. (“MediQuip”), a publicly-traded Nevada corporation.





Deep Down is the parent company of the following wholly-owned subsidiaries: Deep Down, Inc., a Delaware corporation (“Deep Down Delaware”); ElectroWave USA, Inc., a Nevada corporation (“ElectroWave”), since its acquisition April 2, 2007; Mako Technologies, LLC, a Nevada limited liability company (“Mako”), since its acquisition effective December 1, 2007; Flotation Technologies, Inc., a Maine corporation (“Flotation”), since its acquisition effective May 1, 2008 and Deep Down International Holdings, LLC, a Nevada limited-liability company (“DDIH”), since its formation in February 2009. As discussed below, effective December 31, 2010, we engaged in a transaction in which all of the operating assets and liabilities of Flotation were contributed, along with other contributions we made, to a joint venture entity named Cuming Flotation Technologies, LLC (“CFT”), in return for a 20% common unit ownership interest in CFT.





On April 2, 2007, we acquired substantially all of the assets of ElectroWave USA, Inc., a Texas corporation. We formed a wholly-owned subsidiary, ElectroWave USA, Inc., a Nevada corporation, to complete the acquisition.  This division has been inactive since 2009 and currently has no material assets or operations.





On December 1, 2007, we acquired all of the common stock of Mako Technologies, Inc.  We formed a wholly-owned subsidiary, Mako Technologies, LLC to complete the acquisition.  Located in Morgan City, Louisiana, Mako serves the offshore petroleum and marine industries with technical support services, and equipment vital to offshore petroleum production, through the provision of highly qualified technicians, remotely operated vehicle (“ROV”) services, topside and subsea equipment and support systems used in diving operations, maintenance and repair operations, and offshore construction.





On June 5, 2008, we completed the acquisition of Flotation. We effectively dated the acquisition for accounting purposes as of May 1, 2008 and consummated the closing on June 6, 2008. Flotation engineers, designs and manufactures deepwater buoyancy systems using high-strength FlotecTM syntactic foam and polyurethane elastomers from its facilities in Biddeford, Maine.





In February 2009, we formed Deep Down International Holdings, LLC, a Nevada limited-liability company and wholly-owned subsidiary of the Company, for the purpose of holding securities for foreign companies organized or acquired by the Company. DDIH currently has no material assets or operations.





As noted above, effective December 31, 2010, we engaged in a joint venture transaction in which all of Flotation's operating assets and liabilities (except for one intercompany corporate overhead payable) were contributed, along with other contributions we made, to CFT in return for a 20% common unit ownership interest in CFT (the "JV").  For a more detailed explanation of this transaction, please see “Part II, Item 8. Financial Statements and Supplementary Data” Note 4 to the consolidated financial statements, “Investment in Joint Venture.”





Importantly, this transaction impacts the presentation of our financial condition and results of operations because it means that the operations of Flotation will no longer be included in such presentation for periods beginning January 1, 2011, except on the basis of our 20% common unit ownership interest in CFT.  However, the operations of Flotation will continue to be fully included in our presentation of historical information for periods ended December 31, 2010 and prior (since the acquisition of Flotation in 2008).





Our current operations include the significant acquisitions of Deep Down Delaware and Mako.  In addition to our strategy of continuing to grow and strengthen our operations, including by expanding our services and products in accordance with our customers’ demands, we intend to continue to seek strategic acquisitions of complementary service providers, product manufacturers and technologies that are focused primarily on supporting deepwater and ultra-deepwater offshore exploration, development and production of oil and gas reserves and other maritime operations.




4


Business Overview





We provide services to the offshore energy industry to support deepwater and ultra-deepwater exploration, development and production of oil and gas and other maritime operations.  We are primarily a service company, and we also produce custom engineered products that assist us in fulfilling service objectives for specific projects on a contractual basis.  We design and manufacture a broad line of deepwater and ultra-deepwater, surface and offshore rig equipment solutions which are used by major integrated, large independent and foreign national oil and gas companies in offshore areas throughout the world.  We also manufacture monitoring and control systems used by offshore energy and other maritime operations.  Our products are often initially developed in direct response to customer requests for solutions to critical problems in the field.  We also serve the growing offshore petroleum and maritime industries with technical management and support services.  One of our greatest strengths is the extensive knowledge base of our service, engineering and management personnel in many aspects of the deepwater and ultra-deepwater industry. Set forth below is a more detailed description of important services and products we provide.





Our goal is to provide superior services and products to our clients in a safe, cost-effective and timely manner.  We believe there is significant demand for, and brand name recognition of, our established products due to the technological capabilities, reliability, cost-effectiveness, timeliness of delivery and operational efficiency features of these products. Since our formation, we have introduced many new products that continue to broaden the market we currently serve.





We market our services and products primarily through our offices in Houston, Texas, and Morgan City, Louisiana.  Our sales representatives travel worldwide to the major international energy and maritime markets.  We generally manufacture and fabricate our products at our facilities, although we also work with third parties who provide manufacturing and fabrication support through their own facilities in the Houston, Texas metroplex.





See Note 1 to the consolidated financial statements, "Description of Business and Summary of Significant Accounting Policies," included in this Report for information related to segment reporting.





Services and Products




Services. We provide a wide variety of project engineering and management services, including the design, installation and retrieval of subsea equipment and systems, connection and termination operations, well-commissioning services, as well as construction support and ROV operations support.  We pride ourselves on our ability to collaborate with the engineering functions of oil and gas operators, installation contractors and subsea equipment manufacturers to determine the fastest, safest, and most cost-effective solutions to the full spectrum of complex issues which arise in our industry.  We also provide various products in connection with the use of our installation, retrieval, storage and management services.




Offshore Project Management.  Our installation management team specializes in deepwater subsea developments. We are often contracted by our customers to assist with the preparation and evaluation of subsea development bids and requests for quotes.  Our experience comes from working with installation contractors, oil and gas operators, controls suppliers, umbilical manufacturers and other subsea equipment manufacturers, who often hire us to help ensure that a project progresses smoothly, on time and on budget.




Project Engineering.  Our engineers have experience ranging from the initial conceptual design phases through manufacturing and installation, and concluding with topside connections and commissioning.  Our experience provides us with a level of “hands on” and practical understanding that has proven to be indispensable in enabling us to offer customer solutions to the many problems encountered both subsea and topside.  Because of our wide knowledge base, our engineering team is often hired by oil and gas operators, installation contractors and subsea equipment manufacturers to provide installation management and engineering support services.  Our engineering team has been involved in most of the innovative solutions used today in deepwater subsea systems.  We specialize in offshore installation engineering and the writing of practical installation procedures.  We deal with issues involving flying leads, compliant umbilical splices, bend stiffener latchers, umbilical hardware, hold-back clamps, and the development of distribution system components.  We are heavily involved in the fabrication of installation aids to simplify offshore executions, and offer hydraulic, fiber optic, and electrical testing services and various contingency testing tools.




5




Installation Support and Management.  Our installation management services are centered on the utilization of standardized hardware, proven, well-tested installation techniques, and an experienced, consistent team that has proven to be safe and skilled in all aspects of the installation process.  We pride ourselves on supporting installation contractors through our installation management and engineering services, installation aids and equipment, and our offshore installation support services, including spooling operations, offshore testing, and flying lead installation support. Many installation contractors find it beneficial to utilize our services to help reduce on-board personnel since our specialized technicians can perform multiple tasks. We have designed and fabricated many different installation tools and equipment over the years.  We have been involved in the design of the following equipment to help make installations run as smoothly as possible:  steel flying leads, steel flying lead deployment systems, umbilical hardware and termination systems, umbilical bell mouths, lay chutes, rapid deployment cartridges, horizontal drive units, mud mats, flying lead installation and parking frames, umbilical termination assembly stab & hinge over systems, and numerous other pieces of offshore equipment.  Our team has vast experience with the installation of flexible and rigid risers and flowlines, umbilicals, flexible and rigid jumpers, steel tube and thermoplastic hose flying leads, pipeline end terminations (“PLETs”) and manifolds.  In addition, we provide an extensive array of installation aids, including steel flying lead installation systems, a 5-ton Caterpillar® tensioner, a 10-foot radius lay chute with work platform, many varieties of buoyancy, clump weights, VIV strakes, mud mats, dual tank skids, gang boxes, work vans, pumping and testing skids, control booths, fluid drum carriers, crimping systems, load cells,  300 and 340-ton under-rollers, a 200-ton and 400-ton carousel, UTA running and parking deployment frames, termination shelters, pipe straightners, ROV hooks and shackles, intervention tooling, stackable SeaStax®tanks, baskets, and boxes, and ballgrab rental rigging.




Spooling Services.  Our experienced personnel are involved in the operation of spooling equipment on many projects, including operations for other companies to run their spooling equipment.  We have developed a very efficient (in both time and cost) system for spooling, utilizing our horizontal drive units, under-rollers, tensioners, carousels and rapid deployment cartridges.




Pull-In Operations.  We are involved in the pull-in operations for most of the major umbilical projects in the Gulf of Mexico.  Our familiarity with offshore systems is important, and our pull-ins run smoothly because the same engineers who plan the pull-in operations are also involved in supervising the offshore operations.  Our offshore servicemen comprise the topside umbilical support team and are familiar with the umbilical termination hardware.  These same servicemen are often involved in terminating the umbilicals at the manufacturers’ yard several weeks prior to the installation.  Everything is thoroughly tested prior to installation, including winches at the rental contractor’s yard and after set-up on the platform. Load cells are tested onshore, and the same load cells are used to test the system offshore. This eliminates variables and validates the condition of the pull-in system.  We then perform pull-ins under more controlled conditions with increased confidence, resulting in safer operations.




Terminations.  Deep Down and members of its team have been involved in umbilical terminations since 1988.  Our team was involved with the designs for the armored thermo plastic umbilicals at Multiflex, the first steel tube umbilical in the Gulf of Mexico for the Shell Popeye® umbilical, and the standardization of many steel tube umbilical terminations.  We have also pioneered the concept of the compliant Moray® section that enables a traditional helically wound umbilical to be used for direct well step outs, or long field flying leads.  Our management believes we are the only company that can terminate umbilicals provided by any manufacturer with the same termination system.




Testing Services.  Umbilical manufacturers, control suppliers, installation contractors, and oil and gas operators utilize our services to perform all aspects of testing, including initial Factory Acceptance Testing (“FAT”), Extended Factory Acceptance Testing (“EFAT”) and System Integration Testing (“SIT”), relating to the connecting of the umbilical termination assemblies, the performing of installations, and the completion of the commissioning of the system thereafter.  To execute these services, we have assembled a variety of personnel and equipment to ensure that all testing operations are done in the safest and time-efficient manner, ensuring a reduced overall project cost.  We also work hard to utilize the most detailed digital testing and monitoring equipment to ensure that the most accurate data is provided to our clients.  We have been hired to perform coiled tubing flushing, cleaning, and hydro testing, umbilical filling, flushing, pressure, flow rate, and cleanliness testing, load out monitoring and testing, installation monitoring, post installation testing, system commissioning, umbilical intermediate testing, and umbilical termination assembly cleanliness, flow, and leak testing.  We believe we have one of the best filling, flushing and testing teams in the business. Deep Down employs a variety of different pumping systems to meet industry needs and offers maximum flexibility.  Our philosophy is to flush through the maximum number of lines at the highest flow rate possible to maximize efficiency.  We have assembled a comprehensive list of offshore pumping units and an assortment of chemical pumping skids.  Our equipment can be used to pump all of the standard offshore water-based chemicals as well as all offshore commissioning fluids such as Methanol and diesel.  We have been involved in the design, procurement, testing, installation, and operation of the testing equipment.  Deep Down’s engineers and service technicians can also assist in writing the testing procedures and sequences from simple FAT to very extensive multiple pressures and fluids testing up to full system SIT procedures.




6




System Integration Testing.  We have led the offshore industry move into the digital age with our use of digital transducers to provide much greater levels of accuracy compared to information gathered from conventional chart recorders. We have a wide variety of digital pressure transducers, flow meters, and temperature gauges. We have two wire data systems (4 port and one 16 port) as well as 25 individual digital pressure and temperature recorders that are often employed for installation monitoring activities. In addition to these units, we also have three desks set up with data systems that are capable of tracking from 4 to 15 individual sensors simultaneously. These capabilities, in combination with subsea handling equipment, experienced personnel, and a fully-equipped facility, render Deep Down ideal for managing SIT operations.




Commissioning.  We have been involved in most of the topside connections and commissioning (the removal of inert fluids used during the umbilicals’ transportation and installation) projects in the Gulf of Mexico since its formation in 1997.  Our commissioning team is often identified early in the project and participates in all aspects of planning and risk assessment for the project.  Due to the limited time associated with project commissioning, it is extremely important to perform detailed planning and engineering prior to arrival at the offshore production platform location to reduce any possible shut in or down time.  Our engineers and technicians work closely with the project managers and production platform engineers to help ensure that all aspects of the installation or retrieval project, including potential risks and dangers, are identified, planned for, and eliminated prior to arrival on the production platform.  Due to the different requirements for testing and commissioning of subsea systems, we have an assortment of pumps and equipment to deploy to ensure a safe and efficient commissioning program.  We have experience handling all types of commissioning fluids, including asphaltine dispersants, diesel, methanol, xylene, corrosion inhibitors, water-based control fluids, oil-based control fluids, 100 percent glycol, paraffin inhibitors, and alcohol.




Storage Management.  Our facility in Channelview covers more than 50,000 square feet of internal high quality warehousing capacity and 300,000 square feet of external storage and is strategically located in Houston's Ship Channel area.  Our warehouse is designed to provide clients with flexible and cost effective warehousing and storage management alternatives.  Our professional and experienced warehouse staff, combined with the very latest in information technology, results in a fully integrated warehousing package designed to deliver effective solutions to client needs. Among other capabilities, we are capable of providing long-term specialized contract warehousing; long and short-term storage; modern materials handling equipment; undercover loading areas; quality security systems; integrated inventory management; packing and repacking; computerized stock controls; and labeling.





Marine Technical Support Services





We serve the growing offshore petroleum and marine industries with technical support services and products vital to offshore petroleum production.  Our offerings in this area are primarily through the provision of ROV services which include the provision of skilled ROV operators/technicians and ROV equipment, as well as topside and subsea equipment, and support systems used in diving operations, maintenance and repair operations, and offshore construction.





ROV and ROV Tooling Services.  We provide the latest ROV tooling technology as part of our ROV services.  Our ROV tooling services are constantly growing, with the addition of tools as they are requested by our customers.  As part of our ROV services, we have observation and light work class ROV units capable of operating in depths of 10,000 feet. Our services include platform inspection (Level I, II and III, jack-up and template), platform installation and abandonment, search and recovery, salvage, subsea intervention (hot stab operations, torque tool, well, pipeline commissioning, and stack landings), telecommunication cable inspections (existing and as built), anchor handling (mooring and anchor chain monitoring), ROV consulting and project management, ROV pilots and technicians, and underwater cinematography.  We provide an extensive line of ROV intervention tooling, ROV clamps and ROV-friendly hooks and shackles that are state-of-the-art in design.  In the past few years, we began providing maintenance and fleet management services to other ROV owners as an outsourced support function to their ROV fleet.





Offshore Construction Equipment Rental.  We employ a permanent staff of highly qualified technicians and mechanics to maintain and refurbish our equipment in-between rentals. We carry a wide array of equipment to service the diving industry, including water blasting equipment, breathing air dive compressors, hot water units with feed pumps, man rider winches, hydraulic tools and hose reels, underwater video units, sonar units, magnetic gradiometers, dive radios, lift bags, volume tanks, decompression chambers, and hot water pressure washers.





7




Products.  We provide installation support equipment and component parts and assemblies for subsea distribution systems.  We believe the key to successful installations of hardware is to design the subsea system by considering installation issues first, working backwards to the design of the hardware itself.  This is why we have been instrumental in the development of hardware and techniques to simplify deepwater installations.  We design, manufacture, fabricate, inspect, assemble, test and market subsea equipment, surface equipment and offshore rig equipment that are used by major integrated, large independent and foreign national oil and gas companies in offshore areas throughout the world.  Our products are used during oil and gas exploration, development and production operations on offshore drilling rigs, such as floating rigs and jack-ups, and for drilling and production of oil and gas wells on offshore platforms, tension leg platforms and moored vessels such as floating production storage and offloading vessels (“FPSO”).  We have significant involvement in umbilical and steel flying lead installations in the Gulf of Mexico and throughout the world.  A few of our major product lines are highlighted below.




Flying Leads.  We have developed a method to pull individual steel tubes, hoses, or electrical cables to create a loose steel tube flying lead or short umbilical.  We can manufacture steel flying leads up to 10,000 feet in length with any J-plate desired, with or without electrical cables included.  We have built flying leads with up to 14 tubes.  Additional electrical lines and fiber optic cables can be added to produce any combination required for the transportation of various fluids, chemicals or data.  The flying leads are then fitted with our terminations and Morays® that are attached to the multiple quick connection plate, and finished off with our elastomeric bend limiters.  The non-helix wound design allows for our flying leads to be very installation friendly with minimal-bending stiffness.  A Moray® is the termination head on the flying lead and connects the tubing assembly to the junction plate.  A compliant Moray® consists of a 20-foot flexible flying lead with an electro-hydraulic Moray® that is connected to a full-sized umbilical with the installation tension being applied through an armor pot and slings extending by the compliant section.




Umbilical Hardware.  Our operational team has been involved in more umbilical installations than probably any other team in the industry.  Our blend of experiences with drilling contractors, umbilical manufacturers, subsea engineers and installation contractors has been effective in positioning us to act on behalf of oil and gas operators to ensure key hardware installation is performed in the most efficient and safe manner.  This breadth of experiences gives us a unique perspective when fabricating and designing terminations for umbilical manufacturers.  Our designs are often much lighter in weight and smaller than the typical hardware that has been created and used in the past by our competitors.  Our engineering team has designed and fabricated bending restrictors, armor pots, split barrels, tubing fittings and unions, hinging umbilical splices and topsides terminations with our unique threaded welded fittings, the compliant umbilical splice, and the bend stiffener latcher.  Our umbilical hardware has enabled our clients to use installation friendly techniques for deploying hardware on the ocean floor.




Bend Limiters.  We offer both polymer and steel bend limiters.  Steel bend limiters are typically utilized for steel tube umbilicals and have been designed with a simple and reliable hinged attachment system which significantly decreases installation time.  Polymer bend limiters are typically provided for small diameter umbilicals or flying leads, as well as for their compliant umbilical section, which turn a traditional umbilical into a ROV-friendly, installable flying lead.  Due to our ability to design and manufacture bend limiters in-house, delivery time is greatly reduced.




Compliant Splice®.Compliant Splice®  is a patented method of converting spare umbilicals into actual production umbilicals by splicing spare umbilicals together to produce any length required.  This termination system eliminates the burdens of dealing with umbilical splices during installation and is capable of housing both electrical and fiber optic Fiber Termination Assemblies while still allowing for the splice to be spooled up onto a reel or carousel. This allows oil and gas operators to save significant costs through utilization of existing capital investments in spare umbilicals, which reduces field development costs and delivery time.




SeaStax®.  SeaStax®embodies our concept for offshore storage and space management to help optimize available deck space on offshore installation vessels, drilling rigs and production platforms.  The key philosophy behind SeaStax® is to take common offshore items and store them in a standard-sized container to allow for the storage system to be stackable and interchangeable in subsurface conditions.  The current system utilizes newly-designed 550 gallon tote tanks, baskets, and tool boxes that are all inter-changeable and stackable.  Using common dimensions and designs allows a variety of different items to all be commonly stored and stacked, to minimize required storage area.  The stacking philosophy can be applied to other custom applications if required. In order to maximize accessibility and to reduce maintenance, a variety of options are available such as galvanizing, ladders, and drip pans.




Installation Aids.  To help our clients and to meet our own internal needs, we have developed an extensive array of installation aids, including steel flying lead installation systems, a 5-ton Caterpillar® tensioner, a 10-foot radius lay chute with work platform, many varieties of buoyancy, clump weights, VIV strakes, mud mats, dual tank skids, gang boxes, work vans, pumping and testing skids, control booths, fluid drum carriers, crimping systems, load cells,  300 and 340-ton under-rollers, a 200-ton carousel, UTA running and parking deployment frames, termination shelters, pipe straightners, ROV hooks and shackles, stackable SeaStax®tanks, baskets, and boxes, and ballgrab rental rigging.




8





Buoyancy Products




We engineer, design and manufacture deepwater buoyancy systems using high-strength FlotecTMsyntactic foam and polyurethane elastomers.  Our  product offerings include distributed buoyancy for flexible pipes and umbilicals, drilling riser buoyancy modules, CoreTecTM drilling riser buoyancy modules, ROVitsTM buoyancy, Hydro-FloatTM mooring buoys, StablemoorTM low-drag ADCP deployment solution, Quick-LocTM cable floats, HardballTM umbilical floats, FlotecTM cable and pipeline protection, InflexTM polymer bend restrictors, and installation buoyancy of any size and depth rating.




The majority of our buoyancy product offerings are made with FlotecTMsyntactic foam, a product composed of hollow glass microballoons, combined with an epoxy resin system. These microballoons (also known as “microspheres”) are very small, 20-120 microns in diameter, and provide buoyancy.  The epoxy system provides the strength to the system.  The result is a light weight composite with low thermal conductivity and resistance to compressive stress that far exceeds other types of foams. The foam comes in different densities and strengths which are required for greater depth applications. In some applications, the liquid syntactic foam resulting from the combination of ingredients is poured into high-density polyethylene shells that form the flotation device and encase and protect the syntactic foam from damage. Some of our products are produced with proprietary, high-strength macrospheres.




As of December 31, 2010, the operations relating to buoyancy products were contributed to CFT as part of the JV transaction, and for periods beginning after that date will not be a direct part of our financial condition and results of operations, except on the basis of our minority ownership interest in CFT.





Marine Products





We offer products and services in the fields of electronic monitoring and control systems for the energy, military, and commercial business sectors.  We design, manufacture, install, and commission integrated Programmable Logic Controller (“PLC”) and Supervisory Control and Data Acquisition (“SCADA”) based instrumentation and control systems, including ballast control and monitoring, drilling instrumentation, vessel management systems, marine advisory systems, machinery plant control and monitoring systems, and closed circuit television systems.  We can take projects from conceptual/system design through installation, commissioning, and support. Our understanding of system requirements and our ability to quickly understand our customer’s needs allows us to produce quality products and services on time and on budget.





We have supplied equipment on drilling production rigs operating throughout the world, including Abu Dhabi, Angola, Australia, Azerbaijan, Brazil, Congo, Dubai, Egypt, Equatorial Guinea, India, Indonesia, Kuwait, Mexico, Nigeria, Norway, Russia, the United Kingdom, United States, Vietnam, and other areas. We are also a supplier of integrated marine systems for ships with design, manufacture, and delivery of machinery plant control and monitoring systems and/or alarm monitoring systems for 3 Molinari Class Staten Island ferries, a United States Coast Guard ice breaker, one of the world’s largest hopper dredges, and other vessels.





Manufacturing





Our manufacturing facilities in Channelview, Texas, a suburb of Houston, house a broad variety of processes, including machining, fabrication, inspection, assembly and testing. We are devoted to the design, manufacturing, testing, and commissioning of heavy equipment used in both on- and offshore operations in a variety of markets and industries.





Our manufacturing plant is ISO 9001 and American Petroleum Institute certified.  We maintain our high standards of product quality through the use of quality assurance specialists who work with product manufacturing personnel throughout the manufacturing process and inspect and document equipment as it is processed through our manufacturing facility.  We have the capability to manufacture various products from each of our product lines at our major manufacturing facility and believe that this localized manufacturing capability is essential in order to compete with our major competitors.  We maintain valuable relationships with several other companies that own additional fabrication facilities in and around Houston, Texas.  These other companies provide excellent subcontract manufacturing support on an as-needed basis.  Our manufacturing process includes heat treatment, machining, fabrication, inspection, assembly and testing.





During fiscal years 2010 and 2009, we also had manufacturing facilities for Flotation in Biddeford, Maine, but these facilities were contributed along with Flotation’s other assets and liabilities to CFT effective December 31, 2010.




9


Customers





Demand for our deepwater and ultra-deepwater services, surface equipment and offshore rig equipment is substantially dependent on the condition of the oil and gas industry to invest in substantial capital expenditures as well as continual maintenance and improvements on its offshore exploration, drilling and production operations. The level of these expenditures is generally dependent upon various factors such as expected prices of oil and gas, exploration and production costs of oil and gas, the level of offshore drilling and production activity.  The prevailing view of future oil and gas prices are influenced by numerous factors affecting the supply and demand for oil and gas.  These factors include worldwide economic activity, interest rates, cost of capital, environmental regulation, tax policies, and production levels and prices set and maintained by producing nations and OPEC.  Capital expenditures are also dependent on the cost of exploring for and producing oil and gas, the sale and expiration dates of domestic and international offshore leases, the discovery rate of new oil and gas reserves in offshore areas and technological advances. Oil and gas prices and the level of offshore drilling and production activity have historically been characterized by significant volatility.





Our principal customers are major integrated oil and gas companies, large independent oil and gas companies, foreign national oil and gas companies, subsea equipment manufacturers and subsea equipment installation contractors involved in offshore exploration, development and production.  Offshore drilling contractors, engineering and construction companies, and other companies involved in maritime operations represent a smaller customer base.





We are not dependent on any one customer or group of customers. The number and variety of our products required in a given period by a customer depends upon their capital expenditure budget as well as the results of competitive bids. Consequently, a customer may account for a material portion of revenues in one period and may represent an immaterial portion of revenues in a subsequent period. While we are not dependent on any one customer or group of customers, the loss of one or more of our significant customers could, at least on a short-term basis, have an adverse effect on the results of our operations.





Marketing and Sales





We market our services and products throughout the world directly through our sales personnel in our Houston, Texas and Morgan City, Louisiana offices (prior to December 31, 2010 we also had a sales presence in Biddeford, Maine). We periodically advertise in trade and technical publications of our customer base.  We also participate in industry conferences and trade shows to enhance industry awareness of our products and services.  Our customers generally order products and services after consultation with us on their project.  Orders are typically completed within two weeks to three months depending on the type of product or service.  Larger and more complex products may require four to six months to complete, though we have accepted several longer-term projects, including one that has exceeded a year completion.  Our customers select our products and services based on the quality, reliability and reputation of the product or service, price, timely delivery and advance technology.  For large drilling and production system orders, we engage our project management team to coordinate customer needs with engineering, manufacturing and service organizations, as well as with subcontractors and vendors.  Our profitability on projects is dependent on performing accurate and cost-effective bids as well as performing efficiently in accordance with bid specifications.  Various factors can adversely affect our performance on individual projects that could potentially adversely affect the profitability of a project.





10




Product Development and Engineering





The technological demands of the oil and gas industry continue to increase as offshore exploration and drilling operations expand into deeper and more hostile environments.  Conditions encountered in these environments include well pressures of up to 15,000 psi, mixed flows of oil and gas under high pressure that may also be highly corrosive, and water depths in excess of 5,000 feet.  We are continually engaged in product development activities to generate new products and to improve existing products and services to meet our customers’ specific needs.  We also focus our activities on reducing the overall cost to the customer, which includes not only the initial capital cost but also operating costs associated with its products.





We have an established track record of introducing new products and product enhancements.  Our product development work is conducted at our facilities in Channelview, Texas, and in the field (and prior to December 31, 2010, in Biddeford, Maine).  Our application engineering staff also provides engineering services to customers in connection with the design and sales of our products.  Our ability to develop new products and maintain technological advantages is important to our future success.





We believe that the success of our business depends more on the technical competence, creativity and marketing abilities of our employees than on any individual patent, trademark or copyright.  Nevertheless, as part of our ongoing product development and manufacturing activities, our policy is to seek patents when appropriate on inventions concerning new products and product improvements.  All patent rights for products developed by employees are assigned to us.





Competition





The principal competitive factors in the petroleum drilling, development and production and maritime equipment markets are quality, reliability and reputation of the product, price, technology, and timely delivery.  We face significant competition from other manufacturers of exploration, production, and maritime equipment.  Several of our primary competitors are diversified multinational companies with substantially larger operating staffs and greater capital resources and have a longer history in the manufacturing of these types of equipment.  We compete principally with Dynacon, FMC, Kvaerner, Norson, Ocean Works, Oceaneering, VFL, and Halliburton Product Pipeline Services on our umbilical services; Dynacon, Ocean Works and Odem on our Launch and Recovery Systems; and Entech, Technip, Manatec and Pegasus on our installation management services.





Until the contribution of Flotation to CFT on December 31, 2010, our principal competitors in the polyurethane area were Trelleborg AB, Balmoral Group, Dunlaw Engineering Ltd., ABCO Industries Limited, and Whitefield Plastics Corporation. Our principal competitor in the syntactic foam market was Trelleborg Offshore, Inc. Other competitors included Cuming Corp., located in Massachusetts; Matrix Composites & Engineering Ltd., located in Australia; Balmoral Group, located in Scotland; Syntech Materials, Inc., located in Virginia; and Marine Subsea Group, located in Norway.




Employees





At March 31, 2011, we had approximately 75 full-time employees.  Our employees are not covered by collective bargaining agreements and we generally consider our employee relations to be good.  Our operations depend in part on our ability to attract a skilled labor force.  While we believe that our wage rates are competitive and that our relationship with our skilled labor force is good, a significant increase in the wages paid by competing employers could result in a reduction of our skilled labor force, increases in the wage rates that we pay or both.




11




Governmental Regulations





A significant portion of our business activities are subject to federal, state, local and foreign laws and regulations and similar agencies of foreign governments.  The technical requirements of these laws and regulations are becoming increasingly expensive, complex and stringent.  These regulations are administered by various federal, state and local health and safety and environmental agencies and authorities, including the Occupational Safety and Health Administration of the U.S. Department of Labor and the U.S. Environmental Protection Agency.  From time to time, we are also subject to a wide range of reporting requirements, certifications and compliance as prescribed by various federal and state governmental agencies.  Expenditures relating to such regulations are made in the normal course of our business and are neither material nor place us at any competitive disadvantage. We do not currently expect that compliance with such laws will require us to make material additional expenditures.





We are also affected by tax policies, price controls and other laws and regulations generally relating to the oil and gas industry, including those specifically directed to offshore operations.  Adoption of laws and regulations that curtail exploration and development drilling for oil and gas could adversely affect our operations by limiting demand for our services or products.





Increased concerns about the environment have resulted in offshore drilling in certain areas being opposed by environmental groups, and certain areas have been restricted.  To the extent that new or additional environmental protection laws that prohibit or restrict offshore drilling are enacted and result in increased costs to the oil and gas industry in general, our business could be materially affected.  In addition, these laws may provide for "strict liability" for damages to natural resources or threats to public health and safety, rendering a party liable for the environmental damage without regard to negligence or fault on the part of such party.  Sanctions for noncompliance may include revocation of permits, corrective action orders, administrative or civil penalties and criminal prosecution.  Certain environmental laws provide for joint and several strict liabilities for remediation of spills and releases of hazardous substances.  In addition, companies may be subject to claims alleging personal injury or property damage as a result of alleged exposure to hazardous substances, as well as damage to natural resources.  Such laws and regulations may also expose us to liability for the conduct of or conditions caused by others, or for our acts that were in compliance with all applicable laws at the time such acts were performed.  Compliance with environmental laws and regulations may require us to obtain permits or other authorizations for certain activities and to comply with various standards or procedural requirements.





We cannot determine to what extent our future operations and earnings may be affected by new legislation, new regulations or changes in existing regulations.  We believe that our facilities are in substantial compliance with current regulatory standards.  Based on our experience to date, we do not currently anticipate any material adverse effect on our business or consolidated financial position as a result of future compliance with existing environmental laws and regulations controlling the discharge of materials into the environment.  However, future events, such as changes in existing laws and regulations or their interpretation, more vigorous enforcement policies of regulatory agencies, or stricter or different interpretations of existing laws and regulations, may require additional expenditures which may be material.





Intellectual Property





While we are the holder of various patents, trademarks and licenses relating to our business, we do not consider any individual intellectual property to be material to our business operations.




12


ITEM 2.DESCRIPTION OF PROPERTY





Our principal corporate offices were relocated to 8827 W. Sam Houston Parkway N., Suite 100, Houston, TX  77040 on February 21, 2009. The 89-month lease term began on that date and includes an allowance for leasehold improvements by the landlord, plus a charge for monthly common area expenses (“CAM charges”) on a pro-rata basis of the total building expenses (including insurance, security, maintenance, property taxes and utilities) beginning on the sixth month of the lease term. Monthly lease costs range from $12,177 to $14,391 plus CAM charges, due to a rent escalation clause over the term of the lease.





Our operating facilities for Deep Down Delaware continue to be located at 15473 East Freeway, Channelview, Texas 77530.  We purchased the Channelview property from the lessor in May 2009, which consists of approximately 8 acres of land that houses 60,000 square feet of manufacturing space and 7,000 square feet of office space.   See Item 13 “Certain Relationships and Related Transactions, and Director Independence” included in this Report for information regarding the related nature of the former lessor.





Mako leases its property and buildings from Sutton Industries at a base rate of $7,300 per month.  Mako is located at 125 Mako Lane, Morgan City, LA 70380.  The 5-year lease term commenced on June 1, 2006, and includes an additional 5-year renewal option at the end of the initial term.




Prior to December 31, 2010, we also had operating facilities and administrative offices located at 20 Morin Street, Biddeford, Maine 04005. We had originally acquired the facility in May 2008 for a fair market value of $3.3 million, and the facility consisted of 3.61 acres of land, including a 46,925 square-foot light industrial manufacturing facility and administrative offices. Additionally, in October 2008, Flotation entered into a 60-month lease for 18,000 square feet of warehouse space, which was increased to 21,900 square feet in April 2009, within a 107,000 square foot warehouse located at 26 Morin Street, Biddeford, Maine and purchased a three-quarter acre parcel, which are both adjacent to Flotation’s operating facility.  Both the owned and leased real property in Biddeford, Maine was contributed to CFT effective as of December 31, 2010. See Note 4 "Investment in Joint Venture" to the consolidated financial statements included in this Report.





Our operating facilities in Channelview, Texas are subject to the liens of our lender, Whitney National Bank, under our credit agreement. We believe that our current space is suitable, adequate and of sufficient capacity to support our current operations.





ITEM 3.LEGAL PROCEEDINGS





Periodically, we may be involved in legal proceedings arising in the normal course of business. As of the date of this Report, we are currently not involved in any pending, material legal proceedings.




As disclosed in our Form 8-K filed on November 12, 2010, we received a Notice of Federal Tax Lien from the Internal Revenue Service (“IRS”) in an approximate amount of $573,000 for nonpayment of certain taxes. This claim related primarily to 2007 and 2008 tax returns that were filed when the Company changed its tax year. We paid approximately $592,000 in December 2010, resolved the issue with the IRS and the lien was removed effective December 7, 2010.  As of December 31, 2010, we have recorded a receivable from the IRS of approximately $592,000, which is included as a component of accounts receivable on the accompanying consolidated balance sheet.




13





PART II





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





Market for Common Stock





Our common stock trades publicly on the OTC Bulletin Board ("OTCBB") under the symbol “DPDW.” The OTCBB is a regulated quotation service that displays real-time quotes, last-sale prices and volume information in over-the-counter equity securities. The OTCBB securities are traded by a community of market makers that enter quotes and trade reports. This market is extremely limited and any prices quoted may not be a reliable indication of the value of our common stock.





Prior to the reverse merger with MediQuip on December 14, 2006, no public market in our common stock existed. Beginning December 14, 2006, our common stock was quoted on the OTCBB. These quotes represent inter-dealer quotations, without adjustment for retail mark-up, markdown or commission and may not represent actual transactions.  The following table sets, for the periods indicated, the high and low sales prices for our common stock as reported by the OTCBB.





High


LowFiscal Year 2010:December 31, 2010

$
0.10


$
0.05September 30, 2010

$
0.07


$
0.04June 30, 2010

$
0.17


$
0.05March 31, 2010

$
0.15


$
0.11Fiscal Year 2009:December 31, 2009

$
0.28


$
0.11September 30, 2009

$
0.16


$
0.10June 30, 2009

$
0.17


$
0.10March 31, 2009

$
0.19


$
0.08





Holders





As of March 31, 2011, there were approximately 1,050 stockholders of record of our common stock.  All common stock held in street names are recorded in the Company’s stock register as being held by one stockholder.





Dividend Policy





To date, we have not paid any cash dividends and our present policy is to retain earnings for working capital use.  Under the terms of our credit agreement with Whitney National Bank, we are restricted from paying cash dividends on our common stock, unless no default under the credit agreement exists at the time of or would arise after giving effect to any such distribution. We intend to retain operating capital for the growth of the company operations.




14




Equity Compensation Plan Information





The following table sets forth the outstanding equity instruments as of December 31, 2010:




Plan Category

Number of securities to

be issued upon exercise

of outstanding options,

warrants and rights

Weighted-average exercise

price of outstanding

options,

warrants and rights

Number of securities

remaining available for

future issuance under equity

compensation plans (excluding securities reflected

in first column)Equity compensation  plans approved by securityholders

16,141,667 (1)

$0.13

11,468,000(1)Equity compensationplans not approved by securityholders

638,812 (2)

$0.78TOTAL

16,780,479

$0.15

11,468,000




(1)Represents approximately 31,100,000 shares of common stock that may be issued pursuant to equity awards granted as of December 31, 2010, less 3,500,000 outstanding shares of restricted stock granted under the 2003 Directors, Officers and Consultants Stock Option, Stock Warrant and Stock Award Plan (the “Plan”) and approximately 11,468,000 additional shares of common stock available for future grant under the Plan. Shares available for grant is net of 3,500,000 restricted shares that were granted under the Plan to executives and employees in 2009 and 2010 (see additional discussion of terms and vesting under Executive Compensation). These restricted shares are included in the shares outstanding as of December 31, 2010.  Under the Plan, the total number of shares subject to grants and awards is 15 percent of issued and outstanding shares of common stock. Effective in March 2010, we cancelled 2,000,000 outstanding options held by two executives which were scheduled to vest on February 14, 2011, and did not reissue any replacement options, thus increasing the number of securities available for future issuance. We recorded the remaining unamortized share-based compensation in March 2010 when the shares were cancelled. The Plan was approved by security holders of our predecessor MediQuip Holdings, Inc.





(2) Represents 438,812 shares of common stock underlying warrants, granted in 2007 as part of our prior borrowing facility, plus an additional 200,000 warrants issued in 2008 in connection with the purchase of Flotation during fiscal 2008.  See Note 9 "Warrants" to our consolidated financial statements included in this Report with regard to material terms of such warrants.





Recent Sales of Unregistered Securities





We have previously disclosed in our quarterly and current reports our sales of equity that were not registered under the Securities Act. In particular for this purpose, please see our Current Report on Form 8-K filed on January 5, 2011.





ITEM6.SELECTED FINANCIAL DATA





This item is not applicable for smaller reporting companies.




15


ITEM7.MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS





The following discussion of our financial condition and results of operations should be read in conjunction with our consolidated financial statements and the notes to those financial statements appearing elsewhere in this Form 10-K. This discussion contains forward-looking statements that involve significant risks and uncertainties. As a result of many factors, our actual results may differ materially from those anticipated in our forward-looking statements.





In this Part II, Item 7 “Management’s Discussion and Analysis of Financial Condition and Results of Operations”, all dollar and share amounts are in thousands of dollars and shares, unless otherwise indicated.





Revision of 2009 Consolidated Financial Statements





As discussed in our Form 10Q/A for the quarter ended September 30, 2010, filed with the SEC on March 8, 2011, in conjunction with an internal review meeting of Flotation, our management reviewed the status of one of our long-term fixed price contracts (the “Contract”) that we entered into in November 2008 which is scheduled to be completed in the third quarter of 2011. As a result of this review, our management identified errors in the percentage-of-completion accounting model for revenue recognition pertaining to this Contract. We considered the effect of the error to be immaterial to the consolidated financial statements for the year ended December 31, 2009. The audited consolidated balance sheet and statements of operations, cash flows and stockholders’ equity for the year ended December 31, 2009 included in this Annual Report on Form 10-K (the “Report”) have been adjusted to correct the immaterial effects of the error.





The 2009 consolidated balance sheet reflects the increase of $639 to the amounts of billings in excess of costs and estimated earnings on uncompleted contracts and accumulated deficit. On the consolidated statement of operations, revenues and gross profit for the year ended December 31, 2009 were reduced by $639, which resulted in a corresponding $639 increase to operating loss, loss before income taxes and net loss. On the consolidated statement of cash flows, the revision increased net loss by $639 which was offset to billings in excess of costs and estimated earnings on uncompleted contracts, for a net impact to cash flows provided by operations of $0. On the consolidated statement of stockholders’ equity, the revision increased accumulated deficit by $639. See additional discussion in Note 2 "Revision of 2009 Financial Statements" to the consolidated financial statements included in this Report.





General





We are an oilfield services company specializing in complex deepwater and ultra-deepwater oil production distribution system support services, serving the worldwide offshore exploration and production industry. Our services and technological solutions include distribution system installation support and engineering services, umbilical terminations, loose-tube steel flying leads, ROVs and related services. We support subsea engineering, installation, commissioning, and maintenance projects through specialized, highly experienced service teams and engineered technological solutions. Our primary focus is on more complex deepwater and ultra-deepwater oil production distribution system support services and technologies, used between the platform and the wellhead.  In connection with our JV, we install buoyancy modules on risers for deepwater drilling; we manufacture collars used with the riser buoyancy and we provide buoyancy repair and maintenance.





Equity Investment in Joint Venture





On December 31, 2010, the Company and its wholly-owned subsidiary Flotation, entered into a Contribution Agreement by and among the Company, Flotation, Cuming Flotation Technologies, LLC, a Delaware limited liability company (“CFT”), and Flotation Investor, LLC, a Delaware limited liability company (“Holdings”), pursuant to which Flotation contributed all of its operating assets and liabilities (except for one intercompany corporate overhead payable) to CFT in exchange for common units of CFT.  Pursuant to the Contribution Agreement, we contributed to CFT $1,400 in cash and all of our rights and obligations under that certain Stock Purchase Agreement, dated May 3, 2010, as amended (the “Cuming SPA”), by and among the Company, Cuming Corporation, a Massachusetts corporation (“Cuming”), and the stockholders of Cuming, in exchange for common units of CFT.  Concurrently with the closing of the transactions described above, CFT contributed the operating assets and liabilities it acquired from Flotation to Flotation Tech, LLC, a Delaware limited liability company and wholly-owned subsidiary of CFT.


On December 31, 2010, we entered into a Contract Assignment and Amendment Agreement by and among the Company, CFT and Cuming, pursuant to which we assigned all of our rights and obligations under the Cuming SPA to CFT.  Concurrent with our entry into such Contract Assignment and Amendment Agreement, we entered into a Securities Purchase Agreement, by and among the Company and Holdings (the “Securities Purchase Agreement”), pursuant to which we sold and issued to Holdings 20,000 shares of our common stock for an aggregate purchase price of $1,400.  The Securities Purchase Agreement provides Holdings with registration rights for such 20,000 shares only in the event we fail to maintain current public filings.




16




In connection with the consummation of the foregoing described transaction, on December 31, 2010, the Company and Flotation entered into an Amended and Restated Limited Liability Company Agreement (the “JV LLC Agreement”) of CFT by and among us, Flotation and Holdings, each as a member of the CFT, to provide for the respective rights and obligations of the members of CFT.  We and Flotation collectively hold 20% of the common units of CFT.  Holdings holds 80% of the common units and 100% of the preferred units, which are entitled to a preferred return until the holder thereof receives a full return of its initial capital contribution.  The preferred units have no voting rights.  Pursuant to the terms of the JV LLC Agreement, we and Flotation collectively have the right to appoint one director to CFT’s board of directors and Holdings has the right to appoint the other 4 directors.  The JV LLC Agreement provides that, without the prior approval of Deep Down and Flotation, certain actions cannot be taken by CFT, including:  increasing the number of members of CFT’s board of directors; amending the JV LLC Agreement or the certificate of formation of CFT in a manner that disproportionately adversely affects Deep Down or Flotation; engaging in activities other than the business of CFT; declaring or paying dividends or distributions not in accordance with the JV LLC Agreement; repurchasing or redeeming CFT units; causing a material change in the nature of CFT’s business; engaging in activity that disproportionately affects Deep Down or Flotation as holders of units of CFT; liquidating, dissolving or effecting a recapitalization or reorganization of CFT; prior to November 2, 2012, authorizing or issuing any equity securities or other securities with equity features or convertible into equity securities except with regard to incentive plans for management; making loans, advancements, guarantees or investments except under certain circumstances; granting an exclusive license in all or substantially all of the intellectual property rights of CFT; amending any provision of, or entering into a resolution of any dispute with the parties under the Cuming SPA; entering into a transaction with an officer, director or other person who is an affiliate of CFT; incurring any funded indebtedness other than for the purpose of retiring CFT’s indebtedness to Holdings until such time as such indebtedness is fully repaid; or agreeing or committing or causing any subsidiary to agree to or commit to any of the above.





Concurrent with the closing of the joint venture transaction on December 31, 2010, we entered into a Management Services Agreement to be effective as of January 1, 2011, with CFT, pursuant to which we provide CFT the services of certain officers and management personnel.  We have amended this Management Services Agreement effective as March 1, 2011 to, among other things, alter the minimum monthly fee we are paid by CFT (due partly to a change in the staffing levels for services and personnel we provide to CFT).









Industry and Executive Outlook





Effective May 30, 2010, the United States Department of the Interior, (the “DOI”) ordered a moratorium on all deepwater drilling on the Outer Continental Shelf in response to the April 20, 2010, Deepwater Horizonincident (the “GOM Incident”). Although this moratorium was lifted by the DOI on October 12, 2010, the impact of the GOM Incident on our operations and severity of the industry downturn cannot be predicted with certainty. The timing of market recovery will depend upon several additional factors outside of our control, including the securing of permits, among other required approvals, necessary prior to commencement of deepwater operations in the GOM. Recently, several of our customers have received drilling permits. We expect our operations in the GOM will start improving sometime during the last half of 2011.





Financial markets, which are critical to the funding of the major offshore and deepwater projects, also continued to show some signs of stabilization and recovery and we continue to see an increase in our multi-national bidding activity.  Our operations continue to benefit from increased demand for our products and services primarily in Brazil and West Africa.





The deepwater and ultra-deepwater industry remains one of the best frontiers for adding large hydrocarbon reserves with high production flow rates. We are well positioned to supply services and products required to support safe offshore and deepwater projects of our customers. We anticipate demand for our deepwater and ultra-deepwater services and products will continue to grow and we will continue to focus on this sector of the industry worldwide.





For fiscal year 2011, our focus remains on successful execution of our projects, obtaining new project awards and effective cash management.





17





Results of Operations




Year Ended December 31,


Increase (Decrease)2010


2009


$


%Revenues

$
42,471


$
28,810


$
13,661



47.4
%
 Revenues


Revenues increased $13,661, or 47.4 percent, to $42,471 for the year ended December 31, 2010 from $28,810 for the previous year. The increase in revenues was due primarily to generally higher demand for our services and products, especially in the GOM and West Africa, leading to higher utilization of our personnel, equipment and ROVs, increased equipment and tooling rentals, greater output of engineered subsea projects (including installation support services) and increased manufacture of products for deepwater and ultra-deepwater projects.


Year Ended December 31,


Increase (Decrease)2010


2009


$


%Cost of sales

$
28,886


$
19,888


$
8,998



45.2%Gross Profit

$
13,585


$
8,922


$
4,663



52.3%Gross Profit %


32.0%



31.0%







1.0%


Gross profit increased $4,663 to $13,585 for the year ended December 31, 2010, an increase of 52.3 percent over the same period of the prior year, reflecting an overall increase in the gross profit margin to 32 percent from 31 percent.  The increases in gross profit and gross profit margin were due to the increased revenues described above and to the larger percentage of service rather than product revenue during the same period last year.





We record depreciation expense related to revenue-generating fixed assets as cost of sales, which totaled $2,327 and $1,615 for the years ended December 31, 2010 and 2009, respectively.The increase in 2010 resulted from the purchases of ROVs and other capital expenditures to increase capacity in 2010 and late in fiscal year 2009.





Selling, general and administrative expenses





Year Ended December 31,


Increase (Decrease)2010


2009


$


%Selling, general & administrative

$
13,963


$
14,371


$
(408
)


(2.8)%Selling, general & administrative as a % of revenues


32.9%



49.9%







(17.0)%





Selling, general and administrative expenses (“SG&A”), as a percent of revenue, decreased 17.0% from the previous fiscal year.  SG&A decreased $408 from the previous year, even though revenues for the same period increased by 47.4%. Now that we have completed the JV transaction, we will continue our cost containment program. During the year ended December 31, 2009, we reversed an accrual of $586 for registration penalty expense that was accrued during fiscal 2008. The effect of this accrual reversal in 2009 indicates ourSG&Aactually declined by $994, which is a significant reduction in SG&A as a result of our cost containment program.





Depreciation and amortization expense (excluded from Cost of sales)




Year Ended December 31,


Increase (Decrease)2010


2009


$


%Depreciation

$
329


$
343


$
(14
)


(4.1)%Amortization


1,402



6,195



(4,793
)


(77.4)%Depreciation and amortization

$
1,731


$
6,538


$
(4,807
)


(73.5)%


Depreciation and amortization expense consists primarily of depreciation of our fixed assets that are not related to revenue generation, plus amortization of intangible assets, including our customer lists, technology and trademarks. Depreciation and amortization expense, excluded from “Cost of sales” in the accompanying statements of operations, was $1,731 and $6,538 for the years ended December 31, 2010 and 2009, respectively.




18





Amortization of intangible assets for the year ended December 31, 2010 was $1,402 compared to $6,195 for the year ended 2009. Included in amortization for 2009 was an impairment charge to certain long-lived intangible assets totaling $4,616, due partially to a change in the estimated useful life of some technology intangible assets from twenty-five years to ten years which reduced the fair value measurement of the asset. See further discussion regarding the specific assumptions and test results in Note 6 "Intangible Assets and Goodwill" to the consolidated financial statements included in this Report.





Goodwill impairment





During the year ended December 31, 2010, we recognized an impairment to goodwill in the amount of $4,513 related to the Flotation and Mako reporting units. As of December 31, 2009, we recognized an impairment to goodwill in the amount of $5,537 related to the Deep Down Delaware and Mako reporting units. See further discussion of the related analysis in Note 6 "Intangible Assets and Goodwill" to the consolidated financial statements included in this Report.





Net interest expense





Net interest expense for the year ended December 31, 2010 was $510 compared to $356 for the same prior year period.  Net interest expense for the years ended December 31, 2010 and 2009 was generated by our outstanding bank debt, capital leases and our outstanding subordinated debenture.




Loss on contribution of net assets of wholly-owned subsidiary
  Effective December 31, 2010, we engaged in a joint venture transaction in which all of Flotation’s operating assets and liabilities (except for one intercompany corporate overhead payable) were contributed, along with other contributions we made, to CFT in return for a 20% common unit ownership interest in CFT.  A gain or loss is recognized on the difference between the determined fair value of our investment in CFT and the book value of the net assets contributed. Because the fair value of CFT’s net assets (common equity) was determined to be $17,000, our 20% investment was valued at $3,400.  When this amount was compared to the combined book value of Flotation’s net assets of $12,119 plus cash we contributed of $1,400, a loss on contribution in the amount of $10,119 was generated. Based on the financial forecasts of CFT, we believe that the expected equity earnings from our 20% investment in CFT in future years will exceed the loss on contribution of Flotation.
  Equity in net loss of joint venture
  The transaction with CFT closed on December 31, 2010. The loss of CFT for the year ended December 31, 2010 was comprised of acquisition and legal costs, which were partially offset by the recognition of a bargain purchase gain.  There was no operating activity recorded in 2010. We recorded our 20% equity-method portion of CFT’s net loss in the amount of $254 for the year ended December 31, 2010.
 Adjusted EBITDA





Our management evaluates our performance based on a non-GAAP measure, Adjusted EBITDA, which consists of earnings (net income or loss) available to common shareholders before cumulative effect of accounting change, net interest expense, income taxes, non-cash stock compensation expense, non-cash impairments, depreciation and amortization, other non-cash items and one-time charges.  This measure may not be comparable to similarly titled measures employed by other companies and is not a measure of performance calculated in accordance with U.S. GAAP. The measure should not be considered in isolation or as a substitute for operating income, net income or loss, cash flows provided by operating, investing or financing activities, or other cash flow data prepared in accordance with U.S. GAAP. The amounts included in the Adjusted EBITDA calculation, however, are derived from amounts included in the accompanying consolidated statements of operations data.





We believe Adjusted EBITDA is useful to an investor in evaluating our operating performance because it is widely used by investors in our industry to measure a company’s operating performance without regard to items such as income taxes, net interest expense, depreciation and amortization, non-cash impairment, non-cash stock compensation expense, non-cash impairments, other non-cash items and one-time charges which can vary substantially from company to company depending upon accounting methods and book value of assets, financing methods, capital structure and the method by which assets were acquired; it helps investors more meaningfully evaluate and compare the results of our operations from period to period by removing the impact of our capital structure (primarily interest) and asset base (primarily depreciation and amortization) and actions that do not affect liquidity (stock compensation expense, goodwill impairment and loss on contribution of assets of a wholly-owned subsidiary) from our operating results; and it helps investors identify items that are within our operational control. Depreciation and amortization charges, while a component of operating income, are fixed at the time of the asset purchase or acquisition in accordance with the depreciable lives of the related asset and as such are not a directly controllable period operating charge.





The following is a reconciliation of net loss to Adjusted EBITDA for the years ended December 31, 2010 and 2009:




Year Ended December 31,


Increase (Decrease)2010


2009


$


%Net loss

$
(17,415
)

$
(16,781
)

$
(634
)


(3.8
)%Add back interest expense, net of interest income


510



356



154



43.3
%Add back depreciation and amortization


4,058



8,154



(4,096
)


(50.2
)%Add back income tax expense (benefit)


175



(1,026
)


1,201



117.1
%Add back loss on contribution of net assets of wholly-owned subsidiary


10,119



-



10,119



100.0
%Add back share-based compensation


727



836



(109
)


(13.0
)%Add back goodwill impairment


4,513



5,537



(1,024
)


(18.5
)%Adjusted EBITDA

$
2,687


$
(2,924
)

$
5,611



191.9
%




Adjusted EBITDA was $2,687 for the year ended December 31, 2010 compared to $(2,924) for the previous year. The $5,611 improvement was primarily driven by improved operations and reduced costs, particularly in the second half of the year.




19


Capital Resources and Liquidity





Overview





As a deepwater service provider, our revenues, profitability, cash flows, and future rate of growth are substantially dependent on the condition of the global oil and gas industry generally, and our customers’ ability to invest capital for offshore exploration, drilling and production and maintain or increase levels of expenditures for maintenance of offshore drilling and production facilities.  Oil and gas prices and the level of offshore drilling and production activity have historically been characterized by significant volatility.  We enter into large, fixed-price contracts which may require significant lead time and investment. A decline in offshore drilling and production activity could result in lower contract volume or delays in significant contracts which could negatively impact our earnings and cash flows.  Our earnings and cash flows could also be negatively affected by delay in payments by significant customers or delays in completion of our contracts for any reason.  While our objective is to enter into contracts with our customers that are cash flow positive, we may not always be able to achieve this objective.  We are dependent on our cash flows from operations to fund our working capital requirements and the uncertainties noted above create risks that we may not achieve our planned earnings or cash flow from operations, which may require us to raise additional debt or equity capital.  There can be no assurance that we could raise additional capital.





During our fiscal years ended December 31, 2010 and 2009, we have supplemented the financing of our capital needs through a combination of debt and equity financings.  Most significant in this regard has been our debt facility we have maintained with Whitney National Bank (“Whitney”).  Our loans outstanding under the Amended and Restated Credit Agreement with Whitney (the “Restated Credit Agreement”)  become due on April 15, 2012.  We will need to raise additional debt or equity capital or renegotiate the existing debt prior to such date.  We are currently in discussions with several lenders who have expressed interest in refinancing our debt. Our plan is to refinance the outstanding indebtedness under the Restated Credit Agreement or seek terms with Whitney that will provide an extension of such Restated Credit Agreement along with additional liquidity.  However, we cannot provide any assurance that any financing will be available to us on acceptable terms or at all.  If we are unable to raise additional capital or renegotiate our existing debt, this would have a material adverse impact on our business or would raise substantial doubt about our ability to continue as a going concern.  In addition to the foregoing, as of December 31, 2010, we were not in compliance with the financial covenants under the Restated Credit Agreement.  On March 25, 2011 we obtained a waiver for these covenants as of December 31, 2010.




Although the factors described above create uncertainty, if our planned financial results are achieved we believe that we will have adequate liquidity to meet our future operating requirements, and we believe we will be able to raise additional capital or renegotiate our existing debt.


The following are summaries regarding our primary sources of capital financing for our fiscal year ended December 31, 2010.





Whitney Credit Agreement





We originally entered into a credit agreement with Whitney in November 2008.  The credit agreement originally provided a commitment to lend to us the lesser of $2,000 or 80 percent of eligible receivables.  All of this commitment was also available for Whitney to issue letters of credit (“L/C”) for our benefit.  In December 2008, we entered into an amendment of the credit agreement that provided for us to receive a term loan in the principal amount of $1,150.  Then, in May 2009, we entered into another amendment to the credit agreement providing for us to receive another term loan in the principal amount of $2,100.  We used the proceeds from the December 2008 term loan to purchase a piece of equipment (a remotely operated vehicle) and we used the proceeds of the May 2009 term loan to purchase real property in Channelview, Texas.  There was $850 outstanding under the revolving credit line available on December 31, 2009.  We also used the credit agreement to have Whitney issue an irrevocable transferable standby L/C in the ordinary course of business, with an annual commission rate of 2.4 percent for $1,107 during the year ended December 31, 2009 (which such L/C related to a large contract we expect to have completed during 2011).  The Restated Credit Agreement does not obligate Whitney to issue new L/Cs. However on September 1, 2010, Whitney did renew the aforementioned L/C under the same terms for a period of one year to expire on August 31, 2011.  We paid the annual commission in advance, and the L/C will remain in effect until it expires.




On April 14, 2011, we entered into a Second Amendment to the Restated Credit Agreement with Whitney, pursuant to which Whitney extended the maturity dates of the respective term loans and the letter of credit facility under the Restated Credit Agreement to April 15, 2012.




20




Under the original credit agreement with Whitney, we were obligated to repay the December 2008 term loan on the basis of monthly installments of $35, with the initial payment on February 1, 2009 and a final payment on January 2, 2012.  Outstanding amounts of principal of the December 2008 term loan accrue interest at a rate of 6.5 percent per annum.  Under the terms of the Restated Credit Agreement, the monthly installment payments and interest rate of the December 2008 term loan remain the same. As of December 31, 2010, the outstanding principal amount of the December 2008 term loan was $443.





Under the original credit agreement with Whitney, we were obligated to repay the May 2009 term loan on the basis of monthly installments of $18, with the initial payment on June 1, 2009 and a final payment on May 1, 2024.  Outstanding amounts of principal of the May 2009 term loan accrue interest at a rate of 6.5 percent per annum.  Under the terms of the Restated Credit Agreement, the monthly installment payments and interest rate of the May 2009 term loan remain the same, and the final balloon payment of $1,834 is now due on April 15, 2012.  As of December 31, 2010, the outstanding principal amount of the May 2009 term loan was $1,944.





Upon execution of the Restated Credit Agreement in April 2010, our indebtedness in the amount of $850 outstanding under the revolving credit line of the credit agreement was converted to a term loan.  This term loan requires us to make monthly installments in the amount of $40 plus the amount of accrued and unpaid interest beginning on May 1, 2010 with a final payment on February 1, 2012.  Outstanding amounts of principal of the April 2010 term loan accrue interest at a rate of 6.5 percent per annum.  As of December 31, 2010, the outstanding principal amount of the April 2010 term loan was $530.





Whitney possesses a lien on all of our assets to secure the outstanding indebtedness under the Restated Credit Agreement.  Furthermore, each of our subsidiaries has guaranteed our obligations under the Restated Credit Agreement, and as such, our obligations in connection with the Restated Credit Agreement are generally secured by a first priority lien on all of our subsidiaries’ assets.  With regard to the Channelview Property purchased with the proceeds of the May 2009 term loan, we also entered into a Deed of Trust, Security Agreement and UCC Financing Statement for Fixture Filing creating a lien on such property.





On December 31, 2010, we entered into a First Amendment to Amended and Restated Credit Agreement with Whitney, pursuant to which Whitney provided its consent concerning our contribution of Flotation’s assets to CFT and our issuance of shares to Holdings and using the proceeds thereof for a further cash contribution to CFT.  This amendment allowed the Company to complete the acquisition of Cuming Corporation and form the JV, which we contributed all of the assets, liabilities and bank debt of the Flotation subsidiary to the JV for our 20% ownership in the JV.  However, as a result of this transaction occurring on December 31, 2010, we are required to expense all acquisition costs and write down the value of the contributed assets in order to establish a fair value of our investment in the JV.  These expenses and write down caused us to be not in compliance with certain financial covenants under the Restated Credit Agreement.  On March 25, 2011 we obtained a waiver for these covenants as of December 31, 2010.





Under the Restated Credit Agreement, as amended and restated, beginning with the quarter ended June 30, 2010, and for each quarter thereafter, we have been obligated to comply with the following financial covenants: (i) total debt to consolidated earnings before interest, taxes, depreciation and amortization (“EBITDA”) of not greater than 3.0 to 1.0 (“Leverage Ratio”), consolidated EBITDA to consolidated net interest expense and principal payments on the total debt greater than 1.5 to 1.0 (“Fixed Charge Coverage Ratio”), and consolidated net worth after deducting other assets as are properly classified as “Intangible Assets”, plus 50 percent of net income, after provision for taxes (“Tangible Net Worth”) in excess of $15,000.  The calculation of EBITDA, with regards to the Leverage Ratio and Fixed Charge Coverage Ratio, allows us to deduct certain non-cash items, specifically asset impairment charges as of December 31, 2009 and going forward.  As of both September 30, 2010 and December 31, 2010, we were not in compliance with the Leverage Ratio and the Fixed Charge Coverage Ratio and, as noted above, such circumstance entitles Whitney at its option to accelerate and immediately require all amounts outstanding under the Restated Credit Agreement to become immediately due. Under the Restated Credit Agreement, we continue to have obligations for other covenants, including limitations on issuance of common stock, liens, transactions with affiliates, additional indebtedness and permitted investments, among others.





The Restated Credit Agreement removed a provision from the prior credit agreement with Whitney that permitted us to obtain additional indebtedness from a third party in the event Whitney declined to increase its commitment of indebtedness to us.  As such, we expect to have to refinance the indebtedness outstanding under the Restated Credit Agreement at any such time as we seek to obtain new financing from a third party.




21




TD Bank Loan Agreement


During fiscal 2009, Flotation, our wholly-owned subsidiary, obtained loan proceeds from TD Bank, N.A. in the principal amount of $2,160 (the “TD Bank Loan”).  Under the terms of the TD Bank Loan, we were obligated to make payments in monthly installments of $15, with an initial payment on March 13, 2009 and a final payment of the unpaid principal and accrued interest in February 2029.  The interest rate on the TD Bank Loan was 5.75 percent.





The TD Bank Loan was secured by Flotation’s operating premises in Biddeford, Maine under a mortgage and security agreement and a collateral assignment of leases and rents.  The TD Bank loan required us to enter into a debt subordination agreement that subordinated any debt Flotation owed to Deep Down, other than accounts payable between them arising in the ordinary course of business.  Additionally, the TD Bank Loan required a “negative pledge” that prohibited Flotation and Deep Down from granting security interests in Flotation’s personal property, other than such security interests granted in respect of our credit agreement with Whitney, as appropriate.





Under the TD Bank Loan, we were required to meet certain covenants and restrictions.  The financial covenants were reportable annually beginning with the year ended December 31, 2009, and were specific to the Flotation subsidiary financials.  At December 31, 2009, we were not in compliance with the financial covenants, and on April 15, 2010, we obtained a waiver for these covenants as of December 31, 2009.





In connection with Flotation’s contribution of all of its assets to CFT on December 31, 2010, CFT assumed the obligations of Flotation under the TD Bank Loan and we were released from the obligations under such loan.




Other Debt
 
 We have a subordinated debenture with a principal amount of $500 which originated from the exchange of preferred stock in a prior year. The debenture has a fixed interest rate of 6.0 percent per annum, which is required to be paid annually beginning March 31, 2009 through maturity on March 31, 2011, when the unpaid principal balance is due.


Equity Financings





Between April 25 and April 30, 2010, we sold 5,150 shares of our common stock in a private placement to accredited investors at a per share price of $0.10 resulting in total proceeds of $501, net of $14 applied to an outstanding vendor invoice for services provided, which we have used for working capital purposes.





On December 31, 2010, we sold 20,000 shares of our common stock in a private placement to Holdings for an aggregate purchase price of $1,400.  We then contributed these proceeds to CFT in return for common units of CFT.  For a description of the joint venture transaction of which this sale and contribution were a part, see “Part II, Item 8. Financial Statements and Supplemental Data” Note 4 "Investment in Joint Venture" to the consolidated financial statements.





Cash Flows





For the year ended December 31, 2010, cash used in operating activities was $4,043 as compared to cash provided by operating activities of $2,532 for the prior year. Our working capital balances vary due to delivery terms and payments on key contracts, costs and estimated earnings in excess of billings on uncompleted contracts, and outstanding receivables and payables. For the year ended December 31, 2009, we recorded depreciation and amortization of $8,154, which included $4,616 additional amortization due to the impairment of two long-lived intangible assets. The net intangible assets and other operating assets and liabilities of Flotation were contributed to CFT effective December 31, 2010, as discussed above.





For the year ended December 31, 2010, cash provided by investing activities was $5,946 compared to cash used in investing activities of $6,611 for the prior year. During the year ended December 31, 2010, we used $2,634 to purchase property and equipment and $278 for capitalized software. Additionally, we contributed $1,400 to the joint venture with CFT, which was generated by the sale of 20,000 shares of our common stock at $0.07 per common share, and contributed the net assets and liabilities of Flotation to CFT, which resulted in a loss of $10,119.  For the year ended December 31, 2009, we used $6,117 to purchase property and equipment related to plant improvements and the purchase of ROVs, plus $614 for capitalized software.




For the year ended December 31, 2010, cash provided by financing activities was $915 which represented net proceeds from the sale of stock of $1,901, offset by $961 in principal payments on long term debt and $25 value of stock canceled for payroll taxes related to employee restricted stock vestings.  During the year ended December 31, 2009, cash provided by financing activities was $2,496 which consisted of borrowings of $3,000 and principle payments of $504.




22




Critical Accounting Policies





The discussion and analysis of our financial condition and results of operations is based on our consolidated financial statements, which have been prepared in accordance with accounting principles generally accepted in the United States. The preparation of these financial statements in accordance with U.S. GAAP requires us to make estimates and judgments that may affect assets and liabilities. On an on-going basis, we evaluate our estimates, including those related to revenue recognition and related allowances, costs and estimated earnings incurred in excess of billings on uncompleted contracts, inventory, impairments of long-lived assets, including intangible assets, impairments of goodwill, income taxes including the valuation allowance for deferred tax assets, billings in excess of costs and estimated earnings on uncompleted contracts; contingencies and litigation, and share-based payments. We base our estimates on historical experience and on various other assumptions that are believed to be reasonable, the results of which form the basis for making judgments about the carrying values of assets and liabilities. Actual results may differ from these estimates under different assumptions or conditions.





We believe the following accounting policies are critical to our business operations and the understanding of our operations and include the more significant judgments and estimates used in the preparation of our consolidated financial statements.  The consolidated financial statements include the accounts of Deep Down, Inc. and its wholly-owned subsidiaries.





All intercompany transactions and balances have been eliminated in consolidation.





Collectability of Accounts Receivable





Accounts receivable are reduced by an allowance for amounts that may become uncollectible in the future.  Estimates are used in determining our allowance for doubtful accounts and are based on our historical level of write-offs and judgments management makes about the creditworthiness of significant customers based on ongoing credit evaluations.  Further, we monitor current economic trends that might impact the level of credit losses in the future.  Since we cannot predict with certainty future changes in the financial stability of our customers, actual future losses from uncollectible accounts may differ from our estimates.  Additional allowances may be required if the economy or the financial condition of our customers deteriorates.  If we determined that a smaller or larger allowance was appropriate, we would record a credit or a charge to selling, general and administrative expense in the period in which we made such a determination.




Revenue Recognition




We recognize revenue once the following four criterions are met:  (i) persuasive evidence of an arrangement exists, (ii) delivery of the equipment has occurred or services have been rendered, (iii) the price of the equipment or service is fixed and determinable and (iv) collectability is reasonably assured. Fabrication and sale of equipment billings are contingent upon satisfaction of a significant condition of sale milestone, including but not limited to, factory acceptance testing and customer approval, and recognized upon transfer of title to the customer.  Service revenue is recognized as the service is provided, and “time and material” contracts are billed on a bi-weekly or monthly basis as costs are incurred. Customer billings for shipping and handling charges are included in revenue.





From time to time, we enter into large fixed price contracts which we determine that recognizing revenues for these types of contracts is appropriate using the percentage-of-completion method, which compares the percentage of costs incurred to date to the estimated total costs for the contract.  This method is appropriate because management considers total costs the best available measure of progress.





Total costs include all direct material and labor costs plus all indirect costs related to contract performance, such as supplies, equipment repairs, employee travel and supervisor time. Selling, general and administrative costs are charged to expense as incurred.  Provisions for estimated losses on uncompleted contracts (if any) are made in the period in which such losses are determined.  Changes in job performance, job conditions, and total contract values may result in revisions to costs and income and are recognized in the period in which the revisions are determined.  Unapproved change orders are accounted for in revenue and cost when it is probable that the costs will be recovered through a change in the contract price. In circumstances where recovery is considered probable but the revenues cannot be reliably estimated, costs attributable to change orders are deferred pending determination of contract price.





Costs and estimated earnings in excess of billings on uncompleted contracts arise when revenues are recorded on a percentage-of-completion basis but cannot be invoiced under the terms of the contract. Such amounts are invoiced upon completion of contractual milestones. Billings in excess of costs and estimated earnings on uncompleted contracts arise when milestone billings are permissible under the contract, but the related costs have not yet been incurred.All contract costs are recognized currently on jobs formally approved by the customer and contracts are not shown as complete until virtually all anticipated costs have been incurred and the items are shipped to the customer.




23




Assets and liabilities related to costs and estimated earnings in excess of billings on uncompleted contracts, as well as billings in excess of costs and estimated earnings on uncompleted contracts, have been classified as current. The contract cycle for certain long-term contracts may extend beyond one year, thus complete collection of amounts related to these contracts may extend beyond one year, though such long-term contracts include contractual milestone billings as discussed above.





All intercompany revenue balances and transactions were eliminated in consolidation.





Long-Lived Assets





Long-lived assets include property, plant and equipment and long-lived intangible assets.Our intangible assets generally consist of assets acquired in the purchases of the Mako and Flotation subsidiaries and are comprised of customer lists, non-compete covenants with key employees and trademarks related to Mako’s ROVs and to Flotation’s branding, processes, materials and technology.  We amortize intangible assets over their useful lives ranging from six to twenty-five years on a straight-line basis.  We make judgments and estimates in conjunction with the carrying value of these assets, including amounts to be capitalized, depreciation and amortization methods, useful lives and the valuation of acquired long-lived intangible assets.





We test for the impairment of long-lived assets upon the occurrence of a triggering event. We base our evaluation on impairment indicators such as the nature of the assets, the future economic benefit of the assets, any historical or future profitability measurements and other external market conditions or factors that may be present. If these impairment indicators are present or other factors exist that indicate the carrying amount of an asset may not be recoverable, we determine whether an impairment has occurred through the use of an undiscounted cash flows analysis of the asset at the lowest level for which identifiable cash flows exist. The undiscounted cash flow analysis consists of estimating the future cash flows that are directly associated with and expected to arise from the use and eventual disposition of the asset over its remaining useful life. These cash flows are inherently subjective and require significant estimates based upon historical experience and future expectations reflected in our budgets and internal projections. If the undiscounted cash flows do not exceed the carrying value of the long-lived asset, an impairment has occurred, and we recognize a loss for the difference between the carrying amount and the estimated fair value of the asset. The fair value of the asset is measured using quoted market prices or, in the absence of quoted market prices, is based on an estimate of discounted cash flows. Cash flows are generally discounted at an interest rate commensurate with our weighted average cost of capital for a similar asset.





We assessed the conditions and concluded, as of December 31, 2009, that a triggering event had occurred that required an impairment analysis of long-lived intangible assets (see further discussion below related to Goodwill annual testing). For the year ended December 31, 2009, we recorded impairment charges totaling $4,616 to several long-lived intangible assets, which total impairment charges were recorded on the statement of operations as amortization expense. There was no impairment of long-lived assets for the year ended December 31, 2010.Unanticipated changes in revenue, gross margin, or long-term growth factor could result in a material impact on the estimated fair values of our long-lived assets which could result in long-lived asset impairments in future periods. See further discussion in Note 6 "Intangible Assets and Goodwill" to the consolidated financial statements included in this Report. Additionally, the net intangible assets of Flotation were contributed to CFT effective December 31, 2010, as discussed above.





Goodwill





Goodwill represents the cost in excess of the fair value of net assets acquired in business combinations. We evaluate the carrying value of goodwill annually on December 31 and between annual evaluations if events occur or circumstances change that would more likely than not reduce the fair value of the reporting unit below its carrying amount. Such circumstances could include a significant adverse change in legal factors or in business or the business climate or unanticipated competition.




The test for goodwill impairment is a two-step approach. The first step is to compare the estimated fair value of any reporting units within the Company that have goodwill with the recorded net book value (including the goodwill) of the reporting unit. If the estimated fair value of the reporting unit is higher than the recorded net book value, no impairment is deemed to exist and no further testing is required. If, however, the estimated fair value of the reporting unit is below the recorded net book value, then a second step must be performed to determine the goodwill impairment required, if any. In this second step, the estimated fair value from the first step is used as the purchase price in a hypothetical acquisition of the reporting unit. Purchase business combination accounting rules are followed to determine a hypothetical purchase price allocation to the reporting unit’s assets and liabilities. The residual amount of goodwill that results from this hypothetical purchase price allocation is compared to the carrying value of goodwill for the reporting unit, and the carrying value is written down to the hypothetical amount, if lower.




24




At December 31, 2010 and 2009, respectively, our management completed the annual impairment test of goodwill. There was no indication of impairment for the year ended December 31, 2010. Management’s calculations indicated as of December 31, 2009, due to a number of factors, including the global economic environment, increased costs of capital and the decrease in our market capitalization, that the calculations for the reporting units of Deep Down Delaware, Mako and Flotation each indicated their respective net book value exceeded its fair value and, accordingly, goodwill for each unit was considered to be potentially impaired. We used the estimated fair value of each reporting unit from the first step as the purchase price in a hypothetical acquisition of the respective reporting unit. See Note 6 "Intangible Assets and Goodwill" to the consolidated financial statements for a discussion of testing inputs and assumptions. We recognized a goodwill impairment of $3,056 for Deep Down Delaware, $2,481 for Mako and $0 for Flotation for the year ended December 31, 2009. Remaining goodwill by reporting unit was $4,472, $2,874 and $2,083 for the Deep Down Delaware, Mako and Flotation reporting units, respectively, as of December 31, 2009.





Additionally, we assessed market conditions and concluded, as of September 30, 2010, that a triggering event had occurred that required an impairment analysis of goodwill for each reporting unit.  Management’s calculations indicated, due to a number of factors, including the global economic environment, increased costs of capital and the decrease in our market capitalization, that the calculations for the reporting units of Mako and Flotation each indicated their respective net book value exceeded its fair value and, accordingly, we estimated the implied fair value of the goodwill for each reporting unit. The calculation for Deep Down Delaware did not indicate any impairment of goodwill.  We used the estimated fair value of each reporting unit from the first step as the purchase price in a hypothetical acquisition of the respective reporting unit. We recognized a goodwill impairment of $2,430 for Mako and $2,083 for Flotation reporting units as of the nine months ended September 30, 2010.  The impairment was recorded in operating expenses in the consolidated statement of operations for the year ended December 31, 2010. This non-cash charge did not impact our liquidity position, debt covenants or cash flows.




Determining the fair value of a reporting unit is judgmental in nature and requires the use of significant estimates and assumptions, including revenue growth rates and operating margins, discount rates and future market conditions, among others. Unanticipated changes in revenue, gross margin, long-term growth factor or discount rate could result in a material impact on the estimated fair values of our reporting units, which could result in additional goodwill impairments in future periods.





Share-based Compensation





We record share-based payment awards exchanged for employee services at fair value on the date of grant and expense the awards in the consolidated statements of operations over the requisite employee service period.  Share-based compensation expense includes an estimate for forfeitures and is generally recognized over the expected term of the award on a straight-line basis.  At December 31, 2010, we had two types of share-based employee compensation: stock options and restricted stock.





Key assumptions used in the Black-Scholes model for stock option valuations include (1) expected volatility (2) expected term (3) discount rate and (4) expected dividend yield. Since we do not have a sufficient trading history to determine the volatility of our own stock, we based our estimates of volatility on a representative peer group consisting of companies in the same industry, with similar market capitalizations and similar stage of development.  Additionally, we continue to use the simplified method related to employee option grants.





Income Taxes





We follow the asset and liability method of accounting for income taxes.  This method takes into account the differences between financial statement treatment and tax treatment of certain transactions. 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. The effect of a change in tax rates is recognized as income or expense in the period that includes the enactment date. Our effective tax rates for 2010 and 2009 were (1.0) percent, and 5.98 percent, respectively.




We record a valuation allowance to reduce the carrying value of our deferred tax assets when it is more likely than not that some or all of the deferred tax assets will expire before realization of the benefit or that future deductibility is not probable. The ultimate realization of the deferred tax assets depends upon our ability to generate sufficient taxable income of the appropriate character in the future. This requires management to use estimates and make assumptions regarding significant future events such as the taxability of entities operating in the various taxing jurisdictions. In evaluating our ability to recover our deferred tax assets, we consider all reasonably available positive and negative evidence, including our past operating results, the existence of cumulative losses in the most recent years and our forecast of future taxable income. In estimating future taxable income, we develop assumptions, including the amount of future state, and federal pretax operating income, the reversal of temporary differences and the implementation of feasible and prudent tax planning strategies. These assumptions require significant judgment. When the likelihood of the realization of existing deferred tax assets changes, adjustments to the valuation allowance are charged, in the period in which the determination is made, either to income or goodwill, depending upon when that portion of the valuation allowance was originally created.




25




We record an estimated tax liability or tax benefit for income and other taxes based on what we determine will likely be paid in the various tax jurisdictions in which we operate.  We use our best judgment in the determination of these amounts.  However, the liabilities ultimately realized and paid are dependent upon various matters, including resolution of tax audits, and may differ from amounts recorded.  An adjustment to the estimated liability would be recorded as a provision or benefit to income tax expense in the period in which it becomes probable that the amount of the actual liability or benefit differs from the recorded amount.





Our future effective tax rates could be adversely affected by changes in the valuation of our deferred tax assets or liabilities or changes in tax laws or interpretations thereof.  If and when our deferred tax assets are no longer fully reserved, we will begin to provide for taxes at the full statutory rate.  In addition, we are subject to the examination of our income tax returns by the Internal Revenue Service and other tax authorities.  We regularly assess the likelihood of adverse outcomes resulting from these examinations to determine the adequacy of our provision for income taxes.





Recent Accounting Pronouncements





Recent Accounting Pronouncements are included in “Part II, Item 8. Financial Statements” Note 1 to the consolidated financial statements, “Summary of Significant Accounting Policies.”




Off-Balance Sheet Arrangements





We have no off-balance sheet arrangements that have or are reasonably likely to have a current or future effect on our financial condition, changes in financial condition, revenues or expenses, results of operations, liquidity, capital expenditures or capital resources that is material to investors.





Inflation and Seasonality





We do not believe that our operations are significantly impacted by inflation. Our business is not seasonal in nature.




ITEM7A.QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK





This item is not applicable for smaller reporting companies.




ITEM8.FINANCIAL STATEMENTS





The financial statements and schedules are included herewith commencing on page F-1.





Reports of Independent Registered Public Accounting Firms
F-2Consolidated Balance Sheets
F-4Consolidated Statements of Operations
F-5Consolidated Statements of Changes in Stockholders’ Equity
F-6Consolidated Statements of Cash Flows
F-7Notes to Consolidated Financial Statements
F-8





ITEM9.CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE





None.




26


ITEM9A.CONTROLS AND PROCEDURES





Evaluation of Disclosure Controls and Procedures.   We carried out an evaluation, under the supervision and with the participation of our management, including our Chief Executive Officer and Chief Financial Officer, of the effectiveness of our disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)). Based upon that evaluation, our Chief Executive Officer and Chief Financial Officer concluded that, as of the end of the period covered in this report, our disclosure controls and procedures were not effective due to the material weaknesses described below to ensure that information required to be disclosed in reports filed under the Securities Exchange Act of 1934, as amended, is recorded, processed, summarized and reported within the required time periods and is accumulated and communicated to our management, including our Chief Executive Officer and Chief Financial Officer, as appropriate, to allow timely decisions regarding required disclosure.





Management’s Report on Internal Control Over Financial Reporting.Management is responsible for the fair presentation of the consolidated financial statements of Deep Down, Inc.  Management is also responsible for establishing and maintaining a system of internal control over financial reporting as defined in Rule 13a-15(f) and 15d-15(f) under the Securities Exchange Act of 1934, as amended.  Our internal control over financial reporting is designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles.  Our internal control over financial reporting includes those policies and procedures that:




(i)  pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company;




(ii)  provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of our management and directors; and




(iii)  provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use or disposition of assets that could have a material effect on the financial statements.





Management conducted an evaluation of the effectiveness of our internal control over financial reporting based on the framework in Internal Control—Integrated Frameworkissued by the Committee of Sponsoring Organizations of the Treadway Commission.  Based on this evaluation, our management concluded our internal control over financial reporting was not effective as of December 31, 2010.





A material weakness is a deficiency, or combination of deficiencies, in internal control over financial reporting, such that there is a reasonable possibility that a material misstatement of our annual or interim financial statements will not be prevented or detected on a timely basis.  We have identified the following material weaknesses as of December 31, 2010:





We did not maintain effective monitoring controls.Specifically, we did not have sufficient personnel with an appropriate level of technical accounting knowledge, experience, and training who could execute appropriate monitoring and review controls, particularly in situations where transactions were complex or non-routine. This material weakness contributed to the additional material weaknesses discussed below.





We did not have adequate controls to provide reasonable assurance that revenue was recorded in accordance with GAAP.  Specifically, we did not have appropriately designed or effectively operating management review controls performed by individuals with appropriate technical expertise to ensure that the accounting for contracts under the percentage-of-completion method was appropriate. This material weakness resulted in material errors that caused a restatement of our interim financial statements for the fiscal periods ended March 31, 2010, June 30, 2010, and September 30, 2010.





We did not have an adequate internal control designed to prevent or detect and correct erroneous information in our project cost accounting application. This material weakness resulted in material errors that caused a restatement of our interim financial statements for the fiscal periods ended March 31, 2010, June 30, 2010, and September 30, 2010.





As a result of the material weaknesses described above, we concluded that we did not maintain effective internal control over financial reporting as of December 31, 2010 based on criteria established in the Framework.





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 rules of the SEC.




27




Changes in Internal Control Over Financial Reporting.   Management has implemented the following changes to our internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) during the fiscal quarter ended December 31, 2010 which have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting:





·
During the fourth quarter of fiscal 2010 and into 2011, Management has increased review of the processes related to the recognition of revenue accounted for under the percentage-of-completion methodology, including the timely review of cost estimates at completion for all material percentage-of-completion contracts. Effective with the Restatement and during the fourth quarter of fiscal 2010, Management corrected the errors identified in the labor and burden rates applied to the project costs used in the percentage-of-completion accounting model.


·
As discussed elsewhere in this Form 10-K, the Flotation subsidiary was contributed to CFT effective December 31, 2010.  We retain a 20% equity ownership interest in the joint venture.





Management’s remediation plans.In our efforts to continuously improve our internal controls, management has taken steps to enhance the following controls and procedures subsequent to December 31, 2010 as part of our remediation efforts in addressing the material weaknesses above:





·
During the quarter ended March 31, 2011, management strengthened management review controls surrounding revenue recognition to provide reasonable assurance that revenue was recorded in accordance with GAAP, including review by operating and finance management of all estimates to complete for percentage-of-completion contracts.


·
Management also plans to complete and distribute an Accounting Policy and Procedures manual.


·
Though the operations of Flotation were contributed to CFT effective December, 31, 2010, we plan to monitor improvements to the JV’s internal controls deemed necessary by the JV’s management, particularly those related to revenue recognition.





ITEM9B.OTHER INFORMATION





None.




28





PART III





ITEM10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE





The following table sets forth the names, ages and positions of our directors and executive officers.




Name

Age

Position Held With Deep DownRonald E. Smith(2)

52

President, Chief Executive Officer and DirectorEugene L. Butler(1)

69

Executive Chairman and Chief Financial OfficerMary L. Budrunas(2)

59

Vice President, Corporate Secretary and DirectorMichael J. Newbury

43

Vice President Operations and Business DevelopmentMark R. Hollinger

53

Director


_________________________




(1) Mr. Butler was appointed our Executive Chairman of the Board effective September 1, 2009. Effective April 29, 2010, in connection with Gay Mayeux’s appointment as Chief Financial Officer, the Board accepted the resignation of Mr. Butler as Chief Financial Officer.  We continued to employ Mr. Butler as Executive Chairman of the Board under the Employment Agreement dated January 1, 2010. Mr. Butler was then was reappointed as Chief Financial Officer upon Ms. Mayeux’s departure, effective January 24, 2011.


(2) Ronald E. Smith and Mary L. Budrunas are married to each other.





Biographical information regarding each of our directors and named executive officers is as follows.  The following paragraphs also include specific information about each director’s experience, qualifications, attributes or skills that led the Board of Directors to the conclusion that the individual should serve on the Board as of the time of this filing, in light of our business and structure:




Ronald E. Smith, President, Chief Executive Officer and Director. Mr. Smith co-founded Deep Down in 1997 and has served as our Chief Executive Officer, President and Director since December 2006. Prior to December 2006, Mr. Smith was Deep Down’s President. Mr. Smith graduated from Texas A&M University with a Bachelor of Science degree in Ocean Engineering in 1981. Mr. Smith worked both onshore and offshore in management positions for Ocean Drilling and Exploration Company (ODECO), Oceaneering Multiflex, Mustang Engineering and Kvaerner before founding Deep Down. Mr. Smith’s interests include all types of offshore technology, nautical innovations, state of the art communications, diving technology, hydromechanics, naval architecture, dynamics of offshore structures, diving technology and marketing of new or innovative concepts. Mr. Smith is directly responsible for the invention or development of many innovative solutions for the offshore industry, including the first steel tube flying lead installation system.





Mr. Smith is qualified for service on the Board due to his extensive background in many aspects of the offshore industry, spanning almost three decades. Mr. Smith’s wide range of knowledge and experience with the various technologies and platforms in the deepwater industry brings invaluable expertise to our Board.




Eugene L. Butler, Executive Chairman and Chief Financial Officer.  Mr. Butler has served as Chief Financial Officer and Director with Deep Down since June 2007, and was appointed Executive Chairman of the Board effective September 1, 2009. Mr. Butler was Managing Director of CapSources, Inc., an investment banking firm specializing in mergers, acquisitions and restructurings, from 2002 until 2007. Prior to this, he has served in various capacities as a director, president, chief executive officer, chief financial officer and chief operating officer for Weatherford International, Inc., a  multi-billion multinational service and equipment corporation serving the worldwide energy market, from 1974 to 1991.  He was elected to Weatherford’s Board of Directors in May of 1978, elected president and chief operating officer in 1979, and president and chief executive officer in 1984.  He successfully developed and implemented a turnaround strategy eliminating debt and returning the company to profitability during a severe energy recession.  Mr. Butler also expanded operations into international markets allowing Weatherford to become a major worldwide force with its offshore petroleum products and services.  Mr. Butler graduated from Texas A&M University in 1963, and served as an officer in the U.S. Navy until 1969 when he joined Arthur Andersen & Co.  Mr. Butler is distinguished by numerous medals and decorations, including the Bronze Star with combat “V” and the Presidential Unit Citation for his service with the river patrol force in Vietnam. Mr. Butler also serves on the Board of Powell Industries, Inc. (Nasdaq: POWL) since 1991, where he is the Chairman of the Audit Committee and on the Governance Committee.  Mr. Butler is a Certified Public Accountant.




29




In addition to his extensive knowledge of us, Mr. Butler is qualified for service on the Board based on his leadership skills and long-standing senior management experience in the energy and petroleum industries.  Additionally, his background in public accounting and investment banking, familiarity with complex accounting issues and financial statements, as well as his service on the board, including various committees, of another public company, provide invaluable financial expertise and overall insight to our Board.




Mary L. Budrunas, Vice-President, Corporate Secretary and Director. Ms. Budrunas, co-founder of Deep Down, Inc. along with current chief executive officer Ronald E. Smith, and has served as our Vice-President, Corporate Secretary and Director since December 2006.  Ms. Budrunas is responsible for our administrative functions, including human resources and accounting.  Ms. Budrunas has more than 30 years of logistical management experience in manufacturing, fabrication, and industrial sourcing in the oil and gas industry. Prior to Ms. Budrunas co-founding Deep Down in 1997, she managed the purchasing efforts of many projects over a 10-year period for Mustang Engineering, and previously directed procurement for a large petroleum drilling and production facility project in Ulsan, Korea.




Ms. Budrunas is qualified for service on the Board based on her extensive oil and gas industry experience. Such expertise provides valuable insight to the Board.




Michael J. Newbury, Vice President Operations and Business Development.  Mr. Newbury joined Deep Down in March 2009 in the role of Corporate Business Development Manager, bringing more than 19 years of international experience and relationships in offshore business development, sales and marketing, and subsea service project support.  Mr. Newbury’s initial role at Deep Down was the improvement in our marketing, sales and commercial aspects, additionally to oversee large project opportunities and to strengthen our contractual functions.  In February 2010, Mr. Newbury was promoted to Vice President Business Development and was tasked with the additional responsibilities of corporate operations and interfacing with all of our business units.  Prior to joining us, Mr. Newbury held various positions with increasing authority and responsibility with such companies as Subsea 7 from 2002 to 2009, a $2 billion multi-national service and equipment corporation serving the worldwide energy market, General Manager, North and Central America – i-Tech Division, Commercial Manager, North and Central America – ROV, Survey & DGPS, Business Development Manager, North America; Halliburton Subsea (US) 1999 – 2002, Senior Manager – Business Development, Operations Project Manager – ROV and Marine; Subsea International (US) 1997 – 1999,  Safety, Quality and Environmental Group Manager & Human Resources & Payroll Manager, and Subsea Offshore Limited (Great Yarmouth and Aberdeen UK) 1990-1997, General Manager, HSEQ Global Manager, Quality Assurance Global Manager, Quality Assurance Engineer.  Mr. Newbury has worked in most major oil producing regions of the world, including the Gulf of Mexico, Central America, North Sea, Asia, and Australia.  Mr. Newbury’s main areas of focus over the past eight years have been in offshore business development, tendering, and contract negotiation.  Mr. Newbury graduated in 1990 with a Bachelor of Science in Business Management.





Mark R.Hollinger,Director.Mr. Hollinger joined the Board as an independent director effective April 12, 2010, and was appointed Chairman of the Audit Committee of the Board of Directors. Mr. Hollinger is currently President of MacDermid Offshore Solutions at MacDermid, Inc. (“MacDermid”), which provides specialty fluids used for the hydraulic controls of valves in the offshore drilling and production systems; a position he has held since September 2007.  Prior to MacDermid, Mr. Hollinger served as President of Merix Corporation from May 1999 to January 2007 and Chief Executive Officer from September 1999 to January 2007.During the past five years, Mr. Hollinger served on the board of directors of Merix Corporation and Simple Tech, as well as several non-profit board of directors.  Mr. Hollinger holds an MBA in Finance from The Ohio State University.





Mr. Hollinger isqualified for service on the Board based on his experience and expertise in management, plus his knowledge of the international energy market and business strategy, and is a financial expert as defined in Item 407(d)(5)(ii) of Regulation S-K. Also, Mr. Hollinger’s past and current service on the Boards of other public companies brings a depth of experience and perspective to our Board.




30




Corporate Governance





We promote accountability for adherence to honest and ethical conduct; we endeavor to provide full, fair, accurate, timely and understandable disclosure in reports and documents that we file with the SEC and in other public communications made by us and strive to be compliant with applicable governmental laws, rules and regulations. We have adopted a Directors Code of Business Conduct to promote honest and ethical conduct and compliance with applicable laws, rules, regulations and standards on the part of our board of directors. This code addresses several matters, including conflicts of interest, corporate opportunities, confidentiality, fair dealing, protection and proper use of Company assets, compliance with laws, rules and regulations (including insider trading laws), and encouraging the reporting of any illegal or unethical behavior.  We have also adopted Financial Officer’s Code of Business Conduct to promote honest and ethical conduct, proper disclosure of financial information in the Company’s periodic reports, and compliance with applicable laws, rules, and regulations by the Company’s officers and management personnel, including the Company’s chief executive officer, chief financial officer and controller.  The policies established by this code are aimed at preventing wrongdoing and at promoting honest and ethical conduct, including ethical handling of actual and apparent conflicts of interest, the full, fair, accurate, timely and understandable disclosure in public communications, compliance with applicable laws, rules and regulations, and accountability for adherence to the code through prompt internal reporting of violations of the code.







Until the addition of Mr. Hollinger to our Board, in lieu of an Audit Committee, our Board of Directors was responsible for reviewing and making recommendations concerning the selection of outside auditors, reviewing the scope, results and effectiveness of the annual audit of our financial statements and other services provided by our independent public accountants. We created an Audit Committee in April 2010 who will perform these functions. The Board of Directors reviews our internal accounting controls, practices and policies. Our Board of Directors has determined that Mr. Hollinger, Chairman of the Audit Committee,  qualifies as an independent audit committee financial expert as defined in Item 407(d) (5) (ii) of Regulation S-K.





Section 16(a) Beneficial Ownership Reporting Compliance





Section 16(a) of the Exchange Act requires our officers and directors, and persons who own more than ten percent of a registered class of our equity securities, to file reports of securities ownership and changes in such ownership with the SEC. Officers, directors and greater than ten percent shareholders also are required by rules promulgated by the SEC to furnish us with copies of all Section 16(a) forms they file.





Based solely upon a review of the copies of such forms furnished to us or written representations of our officers and directors, we believe that all Section 16(a) filing requirements were filed on a timely basis, except that Mr. Newbury and Mr. Hollinger were each not timely in the filing of one Form 3, Mr. Hollinger was not timely in the filing of two Form 4s and Ms. Budrunas was not timely in the filing of one Form 5.





31


ITEM11.EXECUTIVE COMPENSATION





The following table sets forth information concerning the total compensation earned in the years ended December 31, 2010 and 2009 by our Chief Executive Officer and our three highest compensated executive officers other than our CEO, which included one executive who resigned in January 2011 (collectively, our “Named Executive Officers” or “NEOs”).





Summary Compensation Table





Name and Principal Position
Year

Salary

($)


Bonus

($) (6)


Stock

Awards

($) (1)


Option

Awards

($) (1)


All Other

Compensation

($) (2)


TotalRonald E. Smith
2010

$
362,250


$
-


$
-


$
-


$
18,000


$
380,250President and Chief Executive Officer
2009

$
345,000


$
-


$
93,000


$
-


$
12,000


$
450,000Eugene L. Butler
2010

$
325,500


$
-


$
-


$
-


$
46,817


$
372,317Executive Chairman and Chief Financial Officer (3)
2009

$
310,000


$
-


$
93,000


$
771,600


$
24,348


$
1,198,948Gay Stanley Mayeux
2010

$
163,462


$
-


$
87,500


$
61,600


$
12,000


$
324,562Vice President and Chief Financial Officer (4)
2009

$
-


$
-


$
-


$
-


$
-


$
-Michael J. Newbury
2010

$
190,000


$
-


$
-


$
18,150


$
12,000


$
220,150Vice President of Operations and Business

Development (5)
2009

$
109,615


$
-


$
-


$
-


$
-


$
109,615


(1) Included in the “Stock Awards” and “Option Awards” columns are the aggregate grant date fair values of restricted stock awards and option awards made in 2010 and 2009.  The grant date fair values of the awards were computed in accordance with FASB ASC Topic 718.  A total of 2,000,000 option awards which were originally issued on February 14, 2008 were cancelled in March 2010 and not reissued (such cancellation has no impact on compensation, since we are required to expense the remaining unamortized stock based compensation at the time of cancellation). For a discussion of the assumptions and methodologies used to value the stock and option awards reported in the table above, see Note 8 “Share-Based Compensation” to our consolidated financial statements included in this Report. All options are for the purchase of our common stock. Stock awards are grants of restricted stock representing time-vesting shares.




(2) The amounts in the “All Other Compensation” column for 2010 were attributed to the following:




·
Mr. Smith: Amounts included for the year ended 2010 consisted of a vehicle allowance ($1,500 per month).·
Mr. Butler: Amounts included for the year ended 2010 consisted of a vehicle allowance ($1,500 per month), payroll tax reimbursement of $13,517 and healthcare premium reimbursement of $13,800.·
Ms. Mayeux: Amounts included for the year ended 2010 consisted of a vehicle allowance ($1,500 per month) for the eight months of her employment.·
Mr. Newbury: Amounts included for the year ended 2010 consisted of a vehicle allowance ($1,000 per month).





(3) Mr. Butler was appointed Executive Chairman of the Board effective September 1, 2009. Effective April 29, 2010, in connection with Ms. Mayeux’s appointment as Chief Financial Officer, the Board accepted the resignation of Mr. Butler as Chief Financial Officer.  We continued to employ Mr. Butler as Executive Chairman of the Board under the Employment Agreement dated January 1, 2010. Mr. Butler was then was reappointed as Chief Financial Officer upon Ms. Mayeux’s departure, effective January 24, 2011.





(4) Ms. Mayeux was hired as Chief Financial Officer effective April 29, 2010, and resigned effective January 24, 2011.





(5) Mr. Newbury was hired by Deep Down effective March 30, 2009 as Manager of Business Development and was promoted to Vice President of Operations and Business Development effective February 17, 2010.





(6) There were no bonuses awarded in 2010 or 2009 due to our current cost containment efforts.




32


Narrative Disclosure to Summary Compensation Table





All of the compensation described in the foregoing table, other than those amounts shown in the “Bonus”, “Stock Awards” and “Option Awards” columns, was paid to the NEOs pursuant to agreements with Deep Down.




Mr. Smith has an employment agreement to serve as our President and Chief Executive Officer, which provided initially for annual cash compensation of $345,000, and a monthly vehicle allowance of $1,000.  Effective January 1, 2010, Mr. Smith’s annual cash compensation was increased to $362,250, and a monthly vehicle allowance of $1,500. The term of Mr. Smith’s employment agreement is through January 1, 2013, and is subject to further automatic renewals for annual periods up to an additional two years.




For the year ended December 31, 2009, Mr. Butler had a consulting agreement between Deep Down and Eugene L. Butler & Associates to serve as our Chief Financial Officer. Mr. Butler’s consulting agreement provided for annual cash compensation of $310,000 effective January 1, 2009; also a monthly vehicle allowance of $1,000 and reimbursement for federal and state payroll withholdings customarily withheld for an employee which are included in the “All Other Compensation” column. Effective January 1, 2010, Mr. Butler’s consulting agreement was replaced by an employment agreement.  The employment agreement provides for Mr. Butler to receive cash compensation of $325,500 and a monthly vehicle allowance of $1,500. The term of Mr. Butler’s employment agreement is through January 1, 2013, and is subject to further automatic renewals for annual periods up to an additional two years.





Ms. Mayeux had an employment agreement to serve as our Vice President and Chief Financial Officer, which provided for annual cash compensation of $250,000, and a monthly vehicle allowance of $1,500.  The term of Ms. Mayeux’s employment agreement was through January 1, 2013; Ms. Mayeux resigned from the Company effective January 24, 2011.




Mr. Newbury has an employment agreement to serve as our Vice President Operations and Business Development, which provides for annual cash compensation of $190,000, and a monthly vehicle allowance of $1,000.  The term of Mr. Newbury’s employment agreement is through February 17, 2012, and is subject to automatic renewals for annual periods unless cancelled by either party upon 90 days notice.




The amount included for 2010 in the “Stock Awards” column above reflects a grant of 1,000,000 restricted shares of our common stock provided to Ms. Mayeux on May 25, 2010 under the Plan. The grant of restricted shares of our common stock was scheduled to vest over three years ratably beginning one year from grant date, provided that the officer continues to be employed with Deep Down through the vesting date. All these shares were cancelled and returned to the Company upon resignation of Ms. Mayeux on January 24, 2011.





The amounts included for 2009 in the “Stock Awards” column above reflect grants of 750,000 restricted shares of our common stock provided to each of Messrs. Smith, and Butler on March 23, 2009 under the Plan. Each of the grants of restricted shares of our common stock vested in its entirety on March 23, 2011.





The amounts included for Ms. Mayeux for 2010 in the “Option Awards” column above reflect awards to purchase 1,000,000 shares of our common stock granted to Ms. Mayeux on April 29, 2010 under the Plan. The options were scheduled to vest over three years ratably beginning one year from grant date, and had an exercise price of $0.105. These options were cancelled and returned to the Company upon the resignation of Ms. Mayeux on January 24, 2011.





The amounts included for Mr. Newbury for 2010 in the “Option Awards” column above reflect awards to purchase 250,000 shares of our common stock granted to Mr. Newbury on February 19, 2010 under the Plan. The options are scheduled to vest over three years ratably beginning one year from grant date, and have an exercise price of $0.122.





The amounts included for Mr. Butler for 2009 in the “Option Awards” column above reflect awards to purchase 2,000,000 and 10,000,000 shares of our common stock granted to Mr. Butler on March 23, 2009 and September 1, 2009, respectively, under the Plan. The options vest over three years ratably beginning one year from grant date, and have an exercise price of $0.124 and $0.10, respectively.




33


Outstanding Equity Awards at December 31, 2010





The following tables present information regarding the outstanding equity awards held by each of the NEOs as of December 31, 2010. Mr. Smith had no outstanding option awards on that date.





Option Awards


Name

Option Grant

Date

Number of Securities Underlying Unexercised Options

Exercisable

Number of Securities Underlying Unexercised Options

Unexercisable (#)

Option

Exercise Price

($/Sh)

Option

Expiration

DateEugene L. Butler

9/1/2009

3,333,333

6,666,667 (1)

0.10

9/1/20143/23/2009

666,667

1,333,333 (2)

0.12

3/23/2014Gay Stanley Mayeux

4/29/2010

-

1,000,000 (3)

0.11

4/29/2015Michael J. Newbury

2/19/2010

-

250,000 (4)

0.12

2/19/2015




(1)
The remaining unvested portion of this option award is scheduled to vest in equal installments on September 1, 2011 and September 1, 2012, provided that Mr. Butler continues to be employed with Deep Down through those vesting dates.




(2)
A total of 666,667 options that were unexercisable at December 31, 2010 vested on March 23, 2011. The remaining 666,666 unvested options are scheduled to vest on March 23, 2012, provided that Mr. Butler continues to be employed with Deep Down through that vesting date.




(3)
These unvested options were cancelled in connection with Ms. Mayeux’s resignation effective January 24, 2011.





(4)
A total of 83,334 options vested on February 19, 2011. The unvested portions of this option award are scheduled to vest in equal installments on February 19, 2012 and February 19, 2013, provided that Mr. Newbury continues to be employed with Deep Down through those vesting dates.





Stock Awards


Name

Award

Grant Date

Number of Shares or Units of Stock That Have Not Vested

(#)

Market Value of Shares or Units of Stock that Have Not Vested

($)(1)

Number of Shares or Units of Stock

That Vested

(#)

Market Value of Shares or Units of Stock that Have Vested

($)(1)Ronald E. Smith

3/23/2009

750,000
(2)
$60,000

-

-2/14/2008





350,000 (3)

$28,000Eugene L. Butler

3/23/2009

750,000
(2)
$60,000

-

-2/14/2008





350,000 (3)

$28,000Gay Stanley Mayeux

5/25/2010

1,000,000
(4)
$80,000

-

-
  (1)
The market value is calculated by multiplying the number of shares by the closing price of our common stock of $ 0.08 on December 31, 2010.
 (2)
This restricted stock award vested in its entirety on March 23, 2011.
 (3)
This restricted stock award was granted on February 14, 2008, and vested in its entirety on February 14, 2010.
 (4)
This unvested restricted stock award was cancelled in connection with Ms. Mayeux’s resignation effective January 24, 2011.




34


Benefits payable upon change in control





Each of Mr. Butler’s and Mr. Smith’s (the “Executive”) employment agreements contain provisions related to change in control. Ms. Mayeux’ employment agreement contained the same provisions, however her agreement was terminated in connection with her departure in January 2011.





In the event of termination of the Executive’s employment for any reason, he will be entitled to receive all accrued, unpaid salary and vacation time through the date of termination and all benefits to which the Executive is entitled or vested under the terms of all employee benefit and compensation plans, agreements and arrangements in which the Executive is a participant as of the date of termination.  In addition, subject to executing a general release in favor of us, the Executive will be entitled to receive certain severance payments in the event his employment is terminated by the Company “other than for cause” or by the Executive with “good reason.”  These severance payments include the following:





(i) a lump sum in cash equal to one times the Executive’s annual base salary (at the rate in effect on the date of termination), provided, however, that is such termination occurs prior to the date that is twelve months following a change of control, then such payment will be equal to three times the Executive’s annual base salary (at the rate in effect on the date of termination);




(ii) a lump sum in cash equal to the average annual bonus paid to the Executive for the prior two full fiscal years preceding the date of termination; provided, however, that is such termination occurs prior to the date that is twelve months following a change of control, then such payment will be equal to two times the average annual bonus paid to the Executive for the prior two full fiscal years preceding the date of termination;





(iii) a lump sum in cash equal to a pro rata portion of the annual bonus payable for the period in which the date of termination occurs based on the actual performance under our annual incentive bonus arrangement; provided, however, that such pro rata portion shall be calculated based on the Executive’s annual bonus for the previous fiscal year; provided further that if no previous annual bonus has been paid to the Executive, then the lump sum cash payment shall be no less than fifty percent of Executive’ annual base salary; and




(iv) if the Executive’s termination occurs prior to the date that is twelve months following a Change of Control (as defined in the Employment Agreement), then each and every share option, restricted share award and other equity-based award that is outstanding and held by the Executive shall immediate vest and become exercisable.





Each of the Executives have agreed to not, during the respective term of his employment and for a one-year period after his termination, engage in Competition (as defined in the Employment Agreement) with us, solicit business from any of our customer or potential customers, solicit the employment or services of any person employed by or a consultant us on the date of termination or with six months prior thereto, or otherwise knowingly interfere with our business or accounts or any of our subsidiaries.





The Employment Agreements also provide that we, to the extent permitted by applicable law and our by-laws, will defend, indemnify and hold harmless the Executive from any and all claims, demands or causes of action, including reasonable attorneys’ fees and expenses, suffered or incurred by the Executive as a result of the assertion or filing of any claim, demand, litigation or other proceedings based upon statements, acts or omissions made by or on behalf of the Executive pursuant to the Employment Agreement or in the course and scope of the Executive’s employment with us.  We will also maintain and pay all applicable premiums for directors’ and officers’ liability insurance which shall provide full coverage for the defense and indemnification of the Executives, to the fullest extent permitted by applicable law.




35


Compensation Committee Report





We do not have a separate compensation committee. Accordingly, to the extent that decisions are made regarding the compensation policies pursuant to which our named executive officers are compensated, they are made by our Board.





In light of the foregoing, the Board has reviewed and discussed with management the Compensation Discussion and Analysis set forth above and determined that it be included in this annual report for the year ended December 31, 2010.





Submitted by:


Ronald E. Smith


Mary L. Budrunas


Eugene L. Butler


Mark R. Hollinger





Notwithstanding anything to the contrary set forth in any previous filings under the Securities Act, as amended, or the Exchange Act, as amended, that incorporate future filings, including this annual report, in whole or in part, the foregoing Compensation Committee Report shall not be incorporated by reference into any such filings.





Option Exercises and Stock Vested During the Year Ended December 31, 2010





There were no options exercised by NEOs during the yearended December 31, 2010. All of the restricted stock issued on February 14, 2008 became fully vested on February 14, 2010.  Additionally, 666,667 option granted to Mr. Butler on March 23, 2009 vested on March 23, 2010.  All of the restricted stock issued on May 25, 2010 was cancelled in connection with the resignation of the executive effective January 24, 2011.





Compensation of Directors




The following table provides certain information with respect to the 2010 compensation of our directors who served in such capacity during the year.  The 2010 compensation of those directors who are also our named executive officers is disclosed in the Summary Compensation Table above.  We refer to our directors who are neither employed by us nor by our principal stockholders as outside directors.  Compensation for our outside directors consists of equity and cash as described below.  Our outside director as of the date of this statement is Mark R. Hollinger.




Name

Fees Earned or

Paid in Cash

($)


Stock Awards

($) (1)


Option Awards

($) (1)


All Other

Compensation

($)


TotalEugene L. Butler(2)

$
-


$
-


$
-


$
-


$
-Ronald E. Smith (2)

$
-


$
-


$
-


$
-


$
-Mary L. Budrunas (2)

$
-


$
-


$
-


$
-


$
-Mark R. Hollinger

$
32,500


$
87,500


$
50,800


$
-


$
170,800




(1)
Included in the “Stock Awards” and “Option Awards” columns are the aggregate grant date fair values of restricted stock awards and option awards made to our outside director in 2010.  The grant date fair values of the awards were computed in accordance with FASB ASC Topic 718. For a discussion of the assumptions and methodologies used to value the stock and option awards reported in the table above, see Note 8 “Share-Based Compensation” to our consolidated financial statements included in this Report. All options are for the purchase of our common stock. Stock awards are grants of restricted stock representing time-vesting shares.



In May 2010, we granted 1,000,000 restricted shares, par value $0.001 per share for a total of $1,000, to Mr. Hollinger.  The shares were valued at $0.0875 per share and vest over three years in equal tranches on the grant date anniversary, with continued service on our Board of Directors; we are amortizing the related share-based compensation of $87,500 over the three-year requisite service period. Additionally, in May 2010, we granted option awards to purchase 1,000,000 shares of our common stock to Mr. Hollinger. The options are scheduled to vest over three years ratably beginning one year from grant date, and have an exercise price of $0.09.







(2)
Each of our directors who also serve as our executive officers do not receive any additional compensation for their performance of services as directors.  We may agree to provide compensation to these directors in the future.





36


Equity Compensation




We have not formalized equity compensation for outside directors.




Cash Compensation




We pay our outside directors an annual retainer of $12,000, plus meeting fees of $2,000 per meeting of the Board of Directors attended in person and $1,000 per meeting attended by telephone or other electronic means.  All directors are also entitled to reimbursement of expenses.  Outside directors serving in specified committee positions also receive the following additional annual retainers:




Chairman of the Audit Committee

$
10,000Chairman of the Compensation Committee

$
10,000Chairman of the Governance Committee

$
5,000





Each committee member receives $1,000 for each meeting of a committee of the Board of Directors attended in person or by telephone or other electronic means.




Our outside director fees are payable in cash or, at the election of each director, which is made on an annual basis, in shares of stock determined by the current market price of the stock at the time of each payment.




Determining Director Compensation




The Board of Directors makes all decisions regarding the compensation of the Board of Directors.  The Chief Executive Officer makes periodic recommendations regarding director compensation based on his subjective judgment and review of available survey data, and the Board of Directors may exercise its discretion in modifying or approving any adjustments or awards to the directors.




Compensation Policy Related to Risk Management





We do not believe that there are any risks arising from our compensation policies and practices for our employees that are reasonably likely to have a material adverse effect on us.





37





ITEM12.SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS





The following table sets forth certain information, as of April 15, 2011, concerning the beneficial ownership of shares of Common Stock of Deep Down by (i) each person known by us to beneficially own more than 5 percent of the  outstanding shares of our common stock; (ii) each Director; (iii) our “Named Executive Officers” (as determined under Item 402(m) of Regulation S-K); and (iv) all directors and executive officers of Deep Down as a group. To our knowledge, all persons listed in the table have sole voting and investment power with respect to their shares, except to the extent that authority is shared with their respective spouse under applicable law. Unless otherwise indicated, the address for each of the individuals listed below is c/o Deep Down, Inc., 8827 W. Sam Houston Pkwy N., Suite 100, Houston, Texas 77040.




Name of Beneficial Owner (1)

Shares of Common Stock

Beneficially Owned

Percent of Common

Stock OutstandingDirectors and Executive Officers:Ronald E. Smith (2)

45,337,301


22.0%Mary L. Budrunas (2)

45,337,301


22.0%Eugene L. Butler (4)

5,674,092


2.7%Michael J. Newbury (5)

83,334


*Mark R. Hollinger (6)

1,166,666


*All directors and officers as a group (5 persons)
52,261,393
(7)

24.7%5% Shareholders:Flotation Investor, LLC

20,000,000


9.7%767 Fifth Avenue, 17th FloorNew York, New York  10153Robert E. Chamberlain, Jr. (3)

19,750,975


9.6%2909 N. Island DriveSeabrook, Texas  77586* Less than 1%




(1)
A person is deemed to be the beneficial owner of securities that can be acquired within 60 days from the date set forth above through the exercise of any option, warrant or right. Shares of common stock subject to options, warrants or rights that are currently exercisable or exercisable within 60 days are deemed outstanding for computing the percentage of the person holding such options, warrants or rights, but are not deemed outstanding for computing the percentage of any other person. The amounts and percentages are based upon 206,399,155 shares of common stock outstanding as of April 13, 2011.(2)
Mr. Smith and Ms. Budrunas are husband and wife. Shares include 26,724,296 shares owned directly by Mr. Smith and 18,613,005 shares owned directly by Ms. Budrunas. Such shares also include 350,000 shares of restricted stock issued to Mr. Smith on February 14, 2008 which vested on February 14, 2010, and 750,000 shares of restricted stock issued to Mr. Smith on March 23, 2009 which vested on March 23, 2011.(3)
Shares include 350,000 shares of restricted stock issued to Mr. Chamberlain on February 14, 2008, and 750,000 shares of restricted stock issued to Mr. Chamberlain on March 23, 2009 which were fully vested on September 1, 2009 in connection with Mr. Chamberlain’s Severance and Separation Agreement, plus 750,000 shares of restricted stock issued to Mr. Chamberlain on September 1, 2009 which vested on, September 1, 2010, in connection with such Severance and Separation Agreement.(4)
Shares include 350,000 shares of restricted stock issued to Mr. Butler on February 14, 2008 which vested on February 14, 2010 and 750,000 shares of restricted stock issued to Mr. Butler on March 23, 2009 which vested on March 23, 2011, plus 4,666,667 shares of Deep Down’s common stock that Mr. Butler has the right to acquire by exercise of stock options which vested during 2010 and 2011.(5)
Includes 83,334 shares of Deep Down’s common stock that Mr. Newbury has the right to acquire by exercise of stock options which vested February 11, 2011.(6)
Includes 500,000 shares of restricted stock purchased by Mr. Hollinger in April 2010 as part of a private placement, plus 333,333 shares of Deep Down’s common stock that Mr. Hollinger has the right to acquire by exercise of stock options which vest on May 31, 2011, and 333,333 shares of restricted stock issued to Mr. Hollinger on May 31, 2011 which will vest on May 31, 2011.(7)
Shares include 5,416,667 shares of Deep Down’s common stock that executive officers and directors have the right to acquire by exercise of stock options or restricted stock that are vested within 60 days of April 15, 2011.




Disclosure regarding our equity compensation plans as required by this item is incorporated by reference to the information set forth under Item 5 “Market for the Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities” in Part II of this report.




38




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





Review and Approval of Related Person Transactions




Our board of directors and management recognize that related person transactions present a heightened risk of conflicts of interest, and therefore we review all relationships and transactions in which we and our directors, director nominees and executive officers or their immediate family members, as well as holders of more than 5 percent of any class of our voting securities and their family members, have a direct or indirect material interest.  As required under SEC rules, transactions that are determined to be directly or indirectly material to us or a related person are disclosed in the appropriate annual and/or quarterly statements filed with the SEC.





Ronald E. Smith, President, CEO and Director of Deep Down and Eugene Butler, Executive Chairman, CFO and Director of Deep Down, were investors in Ship and Sail, Inc. (“Ship and Sail”), a former vendor of Deep Down. During the year ended December 31, 2010, we made payments of $10,000 to Ship and Sail, and we expensed the prepaid balance of $38,000 as of December 31, 2009 during the first quarter of 2010. The payments and expense to Ship and Sail related to services provided by that entity for the support of the development of marine technology which is currently being marketed. Ship and Sail discontinued operations in mid-2010, thus there is no longer a related party relationship. As disclosed in the 2009 Form 10-K, we made a deposit for a boat in the amount of $100,000 which was written off in connection with the discontinued operations of Ship and Sail.





In January 2010, we loaned South Texas Yacht Services, a vendor of Deep Down, $100,000.  The owner of South Texas Yacht Services was in a business alliance with Ship and Sail. The note receivable, included in other assets on the consolidated balance sheet, bears interest at a rate of 5.5 percent per annum and monthly principal and interest payments in the amount of $2,000 commenced in April 2010. The final principal and interest payment is due March 24, 2015. As of March 31, 2011, the payments on this note were current. Additionally, as of September 30, 2010, South Texas Yacht Services is no longer a related party as they are no longer in a business alliance with Ship and Sail.





Additionally, during the year ended December 31, 2010, we recorded expenses to JUMA, a company owned by Ronald E. Smith, and his wife Mary L. Budrunas, Corporate Secretary and Director of Deep Down, in the amount of $35,000; there is no balance due as of December 31, 2010.  Payments related to the monthly rental of a boat owned by JUMA, in connection with the development of marine technology as discussed above. The board of directors approved the arrangement between JUMA and Deep Down with a termination date of December 31, 2010. No future payments are anticipated to JUMA.





Until the addition of Mr. Hollinger to our Board in April 2010, none of our Directors was independent. We feel additional independent directors will add strength and perspective to our Board of Directors and will increase our internal control process as discussed above, thus we are actively working towards adding additional independent members to our Board.





ITEM 14.PRINCIPAL ACCOUNTANT FEES AND SERVICES





We retained KPMG, LLP (“KPMG”) as our principal accountant in 2010.  We had no relationship with KPMG prior to their retention as our principal accountant. The following table sets forth the aggregate fees paid to KPMGfor audit services rendered in connection with our consolidated financial statements and reports for the year ended December 31, 2010, and for other services rendered during that year on behalf of Deep Down and its subsidiaries, and fees billed to us by PricewaterhouseCoopers LLP for audit and other services during 2009:





December 31, 2010


December 31, 2009(i) Audit Fees

$
821,700


$
502,023(ii) Audit Related Fees


-



-(iii) Tax Fees


118,307



5,250(iv) All Other Fees


-



-


Audit Fees: Consists of fees billed for professional services rendered for the audit of Deep Down’s consolidated financial statements, the review of interim condensed consolidated financial statements included in quarterly reports, services that are normally provided in connection with statutory and regulatory filings or engagements and attest services, except those not required by statute or regulation.





Audit-Related Fees: Consists of fees billed for assurance and related services that are reasonably related to the performance of the audit and review of Deep Down’s consolidated financial statements and are not reported under "Audit Fees."




39




Tax Fees: Consists of tax compliance, tax preparation and other tax services. Tax compliance and tax preparation consists of fees billed for professional services related to assistance with tax returns. Other tax services consist of fees billed for other miscellaneous tax consulting.





All Other Fees:  None.





Pre-Approval of Audit and Permissible Non-Audit Services of Independent Auditors





The Audit Committee of the Board of Directors pre-approves all audit and permissible non-audit services provided by KPMG. These services may include audit services, audit-related services, tax services and other services. The Audit Committee of the Board of Directors may also pre-approve particular services on a case-by-case basis and may delegate pre-approval authority to one or more directors. If so delegated, the director must report any pre-approval decision to the Board of Directors at its first meeting after the pre-approval was obtained.




40


PART IV





ITEM 15. EXHIBITS, FINANCIAL STATEMENT SCHEDULES





(a) Financial Statements and Schedules.  See the consolidated financial statements and related footnotes commencing on page F-1 of this report.





(b) Exhibits.





Exhibit Number

Description of Exhibit2.1

Agreement and Plan of Reorganization among MediQuip Holdings, Inc., Deep Down, Inc., and the majority shareholders of Deep Down, Inc. (incorporated by reference from Exhibit 2.1 to our Form 10-KSB/A filed with the Commission on May 1, 2008).3.1

Articles of Incorporation of Deep Down, Inc. (conformed to include the amendment of the Articles of Incorporation filed with the Secretary of State of the State of Nevada on September 29, 2008 (incorporated by reference from Exhibit A to our Schedule 14C filed on August 15, 2008).3.2

Amended and Restated By Laws of Deep Down, Inc. (incorporated by reference from Exhibit B to our Schedule 14C filed on August 15, 2008).3.3

Form of Certificate of Designations of Series D Redeemable Convertible Preferred Stock (incorporated herein by reference from Exhibit 3.4 to our Form 10-KSB/A filed with the Commission on May 1, 2008).3.4

Form of Certificate of Designations of Series E Redeemable Exchangeable Preferred Stock (incorporated herein by reference from Exhibit 3.5 to our Form 10-KSB/A filed with the Commission on May 1, 2008).3.5

Form of Certificate of Designations of Series F Redeemable Convertible Preferred Stock (incorporated herein by reference from Exhibit 3.6 to our Form 10-KSB/A filed with the Commission on May 1, 2008).3.6

Form of Certificate of Designations of Series G Redeemable Exchangeable Preferred Stock (incorporated herein by reference from Exhibit 3.7 to our Form 10-KSB/A filed with the Commission on May 1, 2008).4.1

Common Stock Purchase Warrant for 320,000 shares of common stock of Deep Down, Inc. issued to Dragonfly Capital Partners, LLC dated August 6, 2007 (incorporated herein by reference from Exhibit 4.2 to our Form 10-KSB filed with the Commission on April 1, 2008).4.2

Common Stock Purchase Warrant for 118,812 shares of common stock of Deep Down, Inc. issued to Dragonfly Capital Partners, LLC dated January 4, 2008 (incorporated herein by reference from Exhibit 4.3 to our Form 10-KSB filed with the Commission on April 1, 2008).4.3

Common Stock Purchase Warrant for 200,000 shares of common stock of Deep Down, Inc. issued to Subsea, LLC dated June 6, 2008 (incorporated herein by reference from Exhibit 4.1 to our Form 8-K/A (Amendment No. 2) filed with the Commission on June 9, 2008).4.4

Registration Rights Agreement, dated August 6, 2007, among Deep Down, Inc. and Prospect Capital Corporation (incorporated herein by reference from Exhibit 4.4 to our Form 10-KSB/A filed with the Commission on May 1, 2008).4.5

Securities Purchase Agreement, dated December 31, 2010, by and among Deep Down, Inc. and Flotation Investor, LLC (incorporated herein by reference from Exhibit 10.3 to our Form 8-K filed with the Commission on January 5, 2011).4.6

6% Subordinated Debenture of Deep Down, Inc. dated March 31, 2008 (incorporated herein by reference from Exhibit 4.1 to our Form 10-Q filed with the Commission on May 16, 2008).10.1

Amended and Restated Credit Agreement, entered into as of April 14, 2010, between Deep Down, Inc., as borrower, and Whitney National Bank, as lender, including the Guarantor’s Consent and Agreement as signed on behalf of ElectroWave USA, Inc., Flotation Technologies, Inc., Mako Technologies, LLC, Deep Down, Inc. and Deep Down International Holdings, LLC (incorporated herein by reference from Exhibit 10.31 to our Form 10-K filed with the Commission on April 15, 2010).10.2

First Amendment to Amended and Restated Credit Agreement, dated December 31, 2010, by and among Deep Down, Inc., as borrower, and Whitney National Bank, as lender, including the Guarantor’s Consent and Agreement as signed on behalf of ElectroWave USA, Inc., Flotation Technologies, Inc., Mako Technologies, LLC, Deep Down, Inc. and Deep Down International Holdings, LLC (incorporated herein by reference from Exhibit 10.4 to our Form 8-K filed with the Commission on January 5, 2011).10.3

Guaranty, dated as of November 11, 2008, by ElectroWave USA, Inc., Flotation Technologies, Inc., Mako Technologies, LLC and Deep Down, Inc. for the benefit of Whitney National Bank (incorporated herein by reference from Exhibit 10.2 to our Form 10-Q filed with the Commission on November 14, 2008).10.4

Joinder to Guaranty, dated as of February 13, 2009, by Deep Down International Holdings, LLC (incorporated herein by reference from Exhibit 10.5 to our Form 10-K filed with the Commission on March 16, 2009).
  41
 Exhibit Number

Description of Exhibit
 10.5

Security Agreement, dated as of November 11, 2008, among Deep Down, Inc., ElectroWave USA, Inc., Flotation Technologies, Inc., Mako Technologies, LLC and Deep Down, Inc. for the benefit of Whitney National Bank (incorporated herein by reference from Exhibit 10.3 to our Form 10-Q filed with the Commission on November 14, 2008).10.6

Joinder to Security Agreement, dated as of February 13, 2009, by Deep Down International Holdings, LLC (incorporated herein by reference from Exhibit 10.7 to our Form 10-K filed with the Commission on March 16, 2009).10.7

First Amendment to Security Agreement, dated as of December 18, 2008, by Deep Down, Inc., ElectroWave USA, Inc., Flotation Technologies, Inc., Mako Technologies, LLC and Deep Down, Inc. for the benefit of Whitney National Bank (incorporated herein by reference from Exhibit 10.3 to our Form 8-K filed with the Commission on December 19, 2008).10.8

Second Amendment to Security Agreement, executed as of May 29, 2009, by Deep Down, Inc., ElectroWave USA, Inc., Flotation Technologies, Inc., Mako Technologies, LLC and Deep Down, Inc., for the benefit of Whitney National Bank (incorporated by reference from Exhibit 10.4 to our Form 8-K filed on June 2, 2009).10.9

Deed of Trust, Security Agreement and UCC Financing Statement for Fixture Filing, executed as of May 29, 2009, by Deep Down, Inc., as grantor, in favor of Gary M. Olander, as trustee, for the benefit of Whitney National Bank, as beneficiary (incorporated by reference from Exhibit 10.2 to our Form 8-K filed on June 2, 2009).10.10

Ratification of Guaranty, Security Agreement, and Intercreditor Agreement, dated April 14, 2010, among Deep Down, Inc., a Nevada corporation, as borrower, and ElectroWave USA, Inc., Flotation Technologies, Inc., Mako Technologies, LLC, Deep Down, Inc., a Delaware corporation, each a guarantor, and Whitney National Bank, a national banking association, as lender (incorporated by reference from Exhibit 10.36 to our Form 10-K filed with the Commission on April 15, 2011).10.11

First Modification to Deed of Trust, dated April 14, 2010, executed by Deep Down, Inc., as grantor, for the benefit of Whitney National Bank, as lender (incorporated by reference from Exhibit 10.37 to our Form 10-K filed with the Commission on April 15, 2010).10.12

First Modification to Assignment of Leases and Rents, dated April 14, 2010, executed by Deep Down, Inc., as assignor, and Whitney National Bank, as assignee (incorporated by reference from Exhibit 10.38 to our Form 10-K filed with the Commission on April 15, 2010).10.13

ROV Term Note, dated April 14, 2010, executed by Deep Down, Inc. and paid to the order of Whitney National Bank (incorporated by reference from Exhibit 10.32 to our Form 10-K filed with the Commission on April 15, 2010).10.14

RE Term Note, dated April 14, 2010, executed by Deep Down, Inc. and paid to the order of Whitney National Bank (incorporated by reference from Exhibit 10.33 to our Form 10-K filed with the Commission on April 15, 2010).10.15

RLOC Term Note, dated April 14, 2010, executed by Deep Down, Inc. and paid to the order of Whitney National Bank (incorporated by reference from Exhibit 10.34 to our Form 10-K filed with the Commission on April 15, 2010).10.16

LC Note, dated April 14, 2010, executed by Deep Down, Inc. and paid to the order of Whitney National Bank (incorporated by reference from Exhibit 10.35 to our Form 10-K filed with the Commission on April 15, 2010).10.17

Office Building Lease, dated November 24, 2008, between Deep Down, Inc. and A-K-S-L 49 Beltway 8, L.P. (incorporated herein by reference from Exhibit 10.18 to our Form 10-K filed with the Commission on March 16, 2009).10.18†

Severance and Separation Agreement, dated September 1, 2009, by and between Strategic Capital Services, Inc. and Robert E. Chamberlain, Jr. (“Consultant”) and Deep Down, Inc. (incorporated herein by reference from Exhibit 10.3 to our Form 10-Q filed with the Commission on November 16, 2009).10.19

Loan Agreement entered into as of February 13, 2009, by and among Flotation Technologies, Inc., Deep Down, Inc., and TD Bank, N.A. (incorporated herein by reference from Exhibit 10.22 to our Form 10-K filed with the Commission on March 16, 2009).10.20

Mortgage and Security Agreement, entered into as of February 13, 2009, by Flotation Technologies, Inc. in favor of TD Bank, N.A. (incorporated herein by reference from Exhibit 10.23 to our Form 10-K filed with the Commission on March 16, 2009).
  42
  Exhibit Number

Description of Exhibit
 10.21

Collateral Assignment of Leases and Rents, entered into as of February 13, 2009, by Flotation Technologies, Inc. in favor of TD Bank, N.A. (incorporated herein by reference from Exhibit 10.24 to our Form 10-K filed with the Commission on March 16, 2009).10.22

Commercial Note, entered into as of February 13, 2009, by Flotation Technologies, Inc. in favor of TD Bank, N.A. (incorporated herein by reference from Exhibit 10.25 to our Form 10-K filed with the Commission on March 16, 2009).10.23

Debt Subordination Agreement, entered into as of February 13, 2009, by and among Flotation Technologies, Inc., Deep Down, Inc. and TD Bank, N.A. (incorporated herein by reference from Exhibit 10.26 to our Form 10-K filed with the Commission on March 16, 2009).10.24

Purchase and Sale Agreement, dated May 22, 2009, by and between Deep Down, Inc. and JUMA Properties, LLC (incorporated by reference from Exhibit 10.1 to our Form 8-K filed on June 2, 2009).10.25†

Employment Agreement, dated effective as of January 1, 2010, between Deep Down, Inc. and Eugene L. Butler (incorporated by reference from Exhibit 10.2 to our Form 8-K filed on January 15, 2010).10.26†

Amended and Restated Employment Agreement, dated effective as of January 1, 2010, between Deep Down, Inc. and Ronald E. Smith (incorporated by reference from Exhibit 10.1 to our Form 8-K filed on January 15, 2010).10.27†

Employment Agreement, dated effective as of February 17, 2010, between Deep Down, Inc. and Michael J. Newbury (incorporated by reference from Exhibit 10.30 to our Form 10-K filed with the Commission on April 15, 2010).10.28†

Employment Agreement, dated effective as of April 29 2010, between Deep Down, Inc. and Gay Stanley Mayeux (incorporated by reference from Exhibit 10.1 to our Form 8-K filed on May 5, 2010).10.29†

Stock Option, Stock Warrant and Stock Award Plan (incorporated by reference from Exhibit 4.10 to our Form S-1 Registration Statement (file no. 333-152435) filed with the Commission on July 21, 2008).10.30

Stock Purchase Agreement, dated May 3, 2010, among Deep Down, Inc., Cuming Corporation and the Selling Stockholders named therein (incorporated by reference from Exhibit 10.1 to our Form 8-K filed on May 5, 2010).10.31

Amendment No. 1 to Stock Purchase Agreement, dated July 13, 2010, among Deep Down, Inc., Cuming Corporation and the Selling Stockholders named therein (incorporated by reference from Exhibit 10.1 to our Form 8-K filed on July 14, 2010).10.32

Amendment No. 2 to Stock Purchase Agreement, dated October 4, 2010, among Deep Down, Inc., Cuming Corporation and the Selling Stockholders named therein (incorporated by reference from Exhibit 10.1 to our Form 8-K filed on October 4, 2010).10.33

Amendment No. 3 to Stock Purchase Agreement, dated effective as of October 31, 2010, among Deep Down, Inc., Cuming Corporation and the Selling Stockholders named therein (incorporated by reference from Exhibit 10.1 to our Form 8-K filed on November 8, 2010).10.34

Agreement and Amendment No. 4 to Stock Purchase Agreement, dated effective as of November 30, 2010, among Deep Down, Inc., Cuming Corporation and the Selling Stockholders named therein (incorporated by reference from Exhibit 10.1 to our Form 8-K filed on December 9, 2010).10.35

Waiver Agreement, dated April 28, 2010, by and between Whitney National Bank, as lender, and Deep Down, Inc., as borrower (incorporated by reference from Exhibit 10.2 to our Form 8-K filed on May 5, 2010).10.36

Contribution Agreement, dated December 31, 2010, by and among Deep Down, Inc., Flotation Technologies, Inc., Cuming Flotation Technologies, LLC and Flotation Investor, LLC (incorporated by reference from Exhibit 10.1 to our Form 8-K filed on January 5, 2011).10.37

Contract Assignment and Amendment Agreement, dated December 31, 2010, by and among Deep Down, Inc., Cuming Flotation Technologies, LLC and Cuming Corporation (incorporated by reference from Exhibit 10.2 to our Form 8-K filed on January 5, 2011).10.38

Amended and Restated Limited Liability Company Agreement of Cuming Flotation Technologies, LLC, dated December 31, 2010 (incorporated by reference from Exhibit 10.5 to our Form 8-K filed January 5, 2011).10.39

Management Services Agreement, dated effective as of January 1, 2011, by and among Deep Down, Inc. and Cuming Flotation Technologies, LLC (incorporated by reference from Exhibit 10.6 to our Form 8-K filed January 5, 2011).10.40

First Amendment to Management Services Agreement, dated effective as of March 1, 2011, by and among Deep Down, Inc. and Cuming Flotation Technologies, LLC (incorporated by reference from Exhibit 10.1 to our Form 8-K filed March 8, 2011).10.41*

Waiver, dated March 25, 2011, by and between Whitney National Bank, as lender, and Deep Down, Inc., as borrower.10.42*

Second Amendment to Amended and Restated Credit Agreement, dated April 14, 2011, by and among Deep Down, Inc., as borrower, and Whitney National Bank, as lender, including the Guarantor’s Consent and Agreement as signed on behalf of ElectroWave USA, Inc., Flotation Technologies, Inc., Mako Technologies, LLC, Deep Down, Inc. and Deep Down International Holdings, LLC.
  43
  Exhibit Number

Description of Exhibit
 14.1

Directors Code of Business Conduct (incorporated herein by reference from Exhibit 14.1 to our Form 10-K filed with the Commission on April 15, 2010).14.2

Financial Officer’s Code of Business Conduct (incorporated herein by reference from Exhibit 14.2 to our Form 10-K filed with the Commission on April 15, 2010).16.1

Letter, dated July 14, 2009, from Malone & Bailey, PC to the Securities and Exchange Commission (incorporated by reference from Exhibit 16.1 to our Form 8-K filed on July 14, 2009).16.2

Letter, dated June 30, 2010, from PricewaterhouseCoopers LLP to the Securities and Exchange Commission (incorporated by reference from Exhibit 16.1 to our Form 8-K filed July 7, 2010).21.1*

Subsidiary list.24.1*

Power of Attorney (set forth immediately following the registrant’s signatures to this report).31.1*

Rule 13a-14(a)/15d-14(a) Certification of the President and Chief Executive Officer of Deep Down, Inc.31.2*

Rule 13a-14(a)/15d-14(a) Certification of the Chief Financial Officer of Deep Down, Inc.32.1*

Section 1350 Certification of the President and Chief Executive Officer of Deep Down, Inc.32.2*

Section 1350 Certification of the Chief Financial Officer of Deep Down, Inc.


* Filed or furnished herewith.


† Exhibit constitutes a management contract or compensatory plan or arrangement.





44





SIGNATURES





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






DEEP DOWN, INC.

(Registrant)/s/ RONALD E. SMITHRonald E. Smith

President and Chief Executive Officer

Dated: April 15, 2011/s/ EUGENE L. BUTLEREugene L. Butler

Chief Financial Officer

Dated: April 15, 2011








POWER OF ATTORNEY





KNOWN ALL MEN BY THESE PRESENTS, that each person whose signature appears below constitutes and appoints RONALD E. SMITH and EUGENE L. BUTLER, and each of them, his or her true and lawful attorneys-in-fact and agents, with full power of substitution and re-substitution for him or her and in his or her name, place and stead, in any and all capacities, to sign any and all amendments to this Annual Report on Form 10-K, and to file the same, with all exhibits thereto, and other documents in connection therewith with the Securities and Exchange Commission, granting unto said attorneys-in-fact and agents, and each of them, full power and authority to do and perform each and every act and thing requisite and necessary to be done in and about the premises, as fully and to all intents and purposes as he might or could do in person hereby ratifying and confirming all that said attorneys-in-fact and agents, or his substitute or substitutes, may lawfully do or cause to be done by virtue hereof.





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





Signatures

Title

Date/s/ RONALD E. SMITH

President, Chief Executive Officer and Director

April 15, 2011Ronald E. Smith

(Principal Executive Officer)/s/ EUGENE L. BUTLER

Executive Chairman and Chief Financial Officer

April 15, 2011Eugene L. Butler

(Principal Financial Officer and PrincipalAccounting Officer)/s/ MARY L. BUDRUNAS

Vice-President, Corporate Secretary and Director

April 15, 2011Mary L. Budrunas/s/ MARK R. HOLLINGER

Director

April 15, 2011Mark R. Hollinger




45





EXHIBIT INDEX


Exhibit Number

Description of Exhibit2.1

Agreement and Plan of Reorganization among MediQuip Holdings, Inc., Deep Down, Inc., and the majority shareholders of Deep Down, Inc. (incorporated by reference from Exhibit 2.1 to our Form 10-KSB/A filed with the Commission on May 1, 2008).3.1

Articles of Incorporation of Deep Down, Inc. (conformed to include the amendment of the Articles of Incorporation filed with the Secretary of State of the State of Nevada on September 29, 2008 (incorporated by reference from Exhibit A to our Schedule 14C filed on August 15, 2008).3.2

Amended and Restated By Laws of Deep Down, Inc. (incorporated by reference from Exhibit B to our Schedule 14C filed on August 15, 2008).3.3

Form of Certificate of Designations of Series D Redeemable Convertible Preferred Stock (incorporated herein by reference from Exhibit 3.4 to our Form 10-KSB/A filed with the Commission on May 1, 2008).3.4

Form of Certificate of Designations of Series E Redeemable Exchangeable Preferred Stock (incorporated herein by reference from Exhibit 3.5 to our Form 10-KSB/A filed with the Commission on May 1, 2008).3.5

Form of Certificate of Designations of Series F Redeemable Convertible Preferred Stock (incorporated herein by reference from Exhibit 3.6 to our Form 10-KSB/A filed with the Commission on May 1, 2008).3.6

Form of Certificate of Designations of Series G Redeemable Exchangeable Preferred Stock (incorporated herein by reference from Exhibit 3.7 to our Form 10-KSB/A filed with the Commission on May 1, 2008).4.1

Common Stock Purchase Warrant for 320,000 shares of common stock of Deep Down, Inc. issued to Dragonfly Capital Partners, LLC dated August 6, 2007 (incorporated herein by reference from Exhibit 4.2 to our Form 10-KSB filed with the Commission on April 1, 2008).4.2

Common Stock Purchase Warrant for 118,812 shares of common stock of Deep Down, Inc. issued to Dragonfly Capital Partners, LLC dated January 4, 2008 (incorporated herein by reference from Exhibit 4.3 to our Form 10-KSB filed with the Commission on April 1, 2008).4.3

Common Stock Purchase Warrant for 200,000 shares of common stock of Deep Down, Inc. issued to Subsea, LLC dated June 6, 2008 (incorporated herein by reference from Exhibit 4.1 to our Form 8-K/A (Amendment No. 2) filed with the Commission on June 9, 2008).4.4

Registration Rights Agreement, dated August 6, 2007, among Deep Down, Inc. and Prospect Capital Corporation (incorporated herein by reference from Exhibit 4.4 to our Form 10-KSB/A filed with the Commission on May 1, 2008).4.5

Securities Purchase Agreement, dated December 31, 2010, by and among Deep Down, Inc. and Flotation Investor, LLC (incorporated herein by reference from Exhibit 10.3 to our Form 8-K filed with the Commission on January 5, 2011).4.6

6% Subordinated Debenture of Deep Down, Inc. dated March 31, 2008 (incorporated herein by reference from Exhibit 4.1 to our Form 10-Q filed with the Commission on May 16, 2008).10.1

Amended and Restated Credit Agreement, entered into as of April 14, 2010, between Deep Down, Inc., as borrower, and Whitney National Bank, as lender, including the Guarantor’s Consent and Agreement as signed on behalf of ElectroWave USA, Inc., Flotation Technologies, Inc., Mako Technologies, LLC, Deep Down, Inc. and Deep Down International Holdings, LLC (incorporated herein by reference from Exhibit 10.31 to our Form 10-K filed with the Commission on April 15, 2010).10.2

First Amendment to Amended and Restated Credit Agreement, dated December 31, 2010, by and among Deep Down, Inc., as borrower, and Whitney National Bank, as lender, including the Guarantor’s Consent and Agreement as signed on behalf of ElectroWave USA, Inc., Flotation Technologies, Inc., Mako Technologies, LLC, Deep Down, Inc. and Deep Down International Holdings, LLC (incorporated herein by reference from Exhibit 10.4 to our Form 8-K filed with the Commission on January 5, 2011).10.3

Guaranty, dated as of November 11, 2008, by ElectroWave USA, Inc., Flotation Technologies, Inc., Mako Technologies, LLC and Deep Down, Inc. for the benefit of Whitney National Bank (incorporated herein by reference from Exhibit 10.2 to our Form 10-Q filed with the Commission on November 14, 2008).10.4

Joinder to Guaranty, dated as of February 13, 2009, by Deep Down International Holdings, LLC (incorporated herein by reference from Exhibit 10.5 to our Form 10-K filed with the Commission on March 16, 2009).
 
 46
 Exhibit Number

Description of Exhibit
 10.5

Security Agreement, dated as of November 11, 2008, among Deep Down, Inc., ElectroWave USA, Inc., Flotation Technologies, Inc., Mako Technologies, LLC and Deep Down, Inc. for the benefit of Whitney National Bank (incorporated herein by reference from Exhibit 10.3 to our Form 10-Q filed with the Commission on November 14, 2008).10.6

Joinder to Security Agreement, dated as of February 13, 2009, by Deep Down International Holdings, LLC (incorporated herein by reference from Exhibit 10.7 to our Form 10-K filed with the Commission on March 16, 2009).10.7

First Amendment to Security Agreement, dated as of December 18, 2008, by Deep Down, Inc., ElectroWave USA, Inc., Flotation Technologies, Inc., Mako Technologies, LLC and Deep Down, Inc. for the benefit of Whitney National Bank (incorporated herein by reference from Exhibit 10.3 to our Form 8-K filed with the Commission on December 19, 2008).10.8

Second Amendment to Security Agreement, executed as of May 29, 2009, by Deep Down, Inc., ElectroWave USA, Inc., Flotation Technologies, Inc., Mako Technologies, LLC and Deep Down, Inc., for the benefit of Whitney National Bank (incorporated by reference from Exhibit 10.4 to our Form 8-K filed on June 2, 2009).10.9

Deed of Trust, Security Agreement and UCC Financing Statement for Fixture Filing, executed as of May 29, 2009, by Deep Down, Inc., as grantor, in favor of Gary M. Olander, as trustee, for the benefit of Whitney National Bank, as beneficiary (incorporated by reference from Exhibit 10.2 to our Form 8-K filed on June 2, 2009).10.10

Ratification of Guaranty, Security Agreement, and Intercreditor Agreement, dated April 14, 2010, among Deep Down, Inc., a Nevada corporation, as borrower, and ElectroWave USA, Inc., Flotation Technologies, Inc., Mako Technologies, LLC, Deep Down, Inc., a Delaware corporation, each a guarantor, and Whitney National Bank, a national banking association, as lender (incorporated by reference from Exhibit 10.36 to our Form 10-K filed with the Commission on April 15, 2011).10.11

First Modification to Deed of Trust, dated April 14, 2010, executed by Deep Down, Inc., as grantor, for the benefit of Whitney National Bank, as lender (incorporated by reference from Exhibit 10.37 to our Form 10-K filed with the Commission on April 15, 2010).10.12

First Modification to Assignment of Leases and Rents, dated April 14, 2010, executed by Deep Down, Inc., as assignor, and Whitney National Bank, as assignee (incorporated by reference from Exhibit 10.38 to our Form 10-K filed with the Commission on April 15, 2010).10.13

ROV Term Note, dated April 14, 2010, executed by Deep Down, Inc. and paid to the order of Whitney National Bank (incorporated by reference from Exhibit 10.32 to our Form 10-K filed with the Commission on April 15, 2010).10.14

RE Term Note, dated April 14, 2010, executed by Deep Down, Inc. and paid to the order of Whitney National Bank (incorporated by reference from Exhibit 10.33 to our Form 10-K filed with the Commission on April 15, 2010).10.15

RLOC Term Note, dated April 14, 2010, executed by Deep Down, Inc. and paid to the order of Whitney National Bank (incorporated by reference from Exhibit 10.34 to our Form 10-K filed with the Commission on April 15, 2010).10.16

LC Note, dated April 14, 2010, executed by Deep Down, Inc. and paid to the order of Whitney National Bank (incorporated by reference from Exhibit 10.35 to our Form 10-K filed with the Commission on April 15, 2010).10.17

Office Building Lease, dated November 24, 2008, between Deep Down, Inc. and A-K-S-L 49 Beltway 8, L.P. (incorporated herein by reference from Exhibit 10.18 to our Form 10-K filed with the Commission on March 16, 2009).10.18†

Severance and Separation Agreement, dated September 1, 2009, by and between Strategic Capital Services, Inc. and Robert E. Chamberlain, Jr. (“Consultant”) and Deep Down, Inc. (incorporated herein by reference from Exhibit 10.3 to our Form 10-Q filed with the Commission on November 16, 2009).10.19

Loan Agreement entered into as of February 13, 2009, by and among Flotation Technologies, Inc., Deep Down, Inc., and TD Bank, N.A. (incorporated herein by reference from Exhibit 10.22 to our Form 10-K filed with the Commission on March 16, 2009).10.20

Mortgage and Security Agreement, entered into as of February 13, 2009, by Flotation Technologies, Inc. in favor of TD Bank, N.A. (incorporated herein by reference from Exhibit 10.23 to our Form 10-K filed with the Commission on March 16, 2009).
 
 47
 
 Exhibit Number

Description of Exhibit
 10.21

Collateral Assignment of Leases and Rents, entered into as of February 13, 2009, by Flotation Technologies, Inc. in favor of TD Bank, N.A. (incorporated herein by reference from Exhibit 10.24 to our Form 10-K filed with the Commission on March 16, 2009).10.22

Commercial Note, entered into as of February 13, 2009, by Flotation Technologies, Inc. in favor of TD Bank, N.A. (incorporated herein by reference from Exhibit 10.25 to our Form 10-K filed with the Commission on March 16, 2009).10.23

Debt Subordination Agreement, entered into as of February 13, 2009, by and among Flotation Technologies, Inc., Deep Down, Inc. and TD Bank, N.A. (incorporated herein by reference from Exhibit 10.26 to our Form 10-K filed with the Commission on March 16, 2009).10.24

Purchase and Sale Agreement, dated May 22, 2009, by and between Deep Down, Inc. and JUMA Properties, LLC (incorporated by reference from Exhibit 10.1 to our Form 8-K filed on June 2, 2009).10.25†

Employment Agreement, dated effective as of January 1, 2010, between Deep Down, Inc. and Eugene L. Butler (incorporated by reference from Exhibit 10.2 to our Form 8-K filed on January 15, 2010).10.26†

Amended and Restated Employment Agreement, dated effective as of January 1, 2010, between Deep Down, Inc. and Ronald E. Smith (incorporated by reference from Exhibit 10.1 to our Form 8-K filed on January 15, 2010).10.27†

Employment Agreement, dated effective as of February 17, 2010, between Deep Down, Inc. and Michael J. Newbury (incorporated by reference from Exhibit 10.30 to our Form 10-K filed with the Commission on April 15, 2010).10.28†

Employment Agreement, dated effective as of April 29 2010, between Deep Down, Inc. and Gay Stanley Mayeux (incorporated by reference from Exhibit 10.1 to our Form 8-K filed on May 5, 2010).10.29†

Stock Option, Stock Warrant and Stock Award Plan (incorporated by reference from Exhibit 4.10 to our Form S-1 Registration Statement (file no. 333-152435) filed with the Commission on July 21, 2008).10.30

Stock Purchase Agreement, dated May 3, 2010, among Deep Down, Inc., Cuming Corporation and the Selling Stockholders named therein (incorporated by reference from Exhibit 10.1 to our Form 8-K filed on May 5, 2010).10.31

Amendment No. 1 to Stock Purchase Agreement, dated July 13, 2010, among Deep Down, Inc., Cuming Corporation and the Selling Stockholders named therein (incorporated by reference from Exhibit 10.1 to our Form 8-K filed on July 14, 2010).10.32

Amendment No. 2 to Stock Purchase Agreement, dated October 4, 2010, among Deep Down, Inc., Cuming Corporation and the Selling Stockholders named therein (incorporated by reference from Exhibit 10.1 to our Form 8-K filed on October 4, 2010).10.33

Amendment No. 3 to Stock Purchase Agreement, dated effective as of October 31, 2010, among Deep Down, Inc., Cuming Corporation and the Selling Stockholders named therein (incorporated by reference from Exhibit 10.1 to our Form 8-K filed on November 8, 2010).10.34

Agreement and Amendment No. 4 to Stock Purchase Agreement, dated effective as of November 30, 2010, among Deep Down, Inc., Cuming Corporation and the Selling Stockholders named therein (incorporated by reference from Exhibit 10.1 to our Form 8-K filed on December 9, 2010).10.35

Waiver Agreement, dated April 28, 2010, by and between Whitney National Bank, as lender, and Deep Down, Inc., as borrower (incorporated by reference from Exhibit 10.2 to our Form 8-K filed on May 5, 2010).10.36

Contribution Agreement, dated December 31, 2010, by and among Deep Down, Inc., Flotation Technologies, Inc., Cuming Flotation Technologies, LLC and Flotation Investor, LLC (incorporated by reference from Exhibit 10.1 to our Form 8-K filed on January 5, 2011).10.37

Contract Assignment and Amendment Agreement, dated December 31, 2010, by and among Deep Down, Inc., Cuming Flotation Technologies, LLC and Cuming Corporation (incorporated by reference from Exhibit 10.2 to our Form 8-K filed on January 5, 2011).10.38

Amended and Restated Limited Liability Company Agreement of Cuming Flotation Technologies, LLC, dated December 31, 2010 (incorporated by reference from Exhibit 10.5 to our Form 8-K filed January 5, 2011).10.39

Management Services Agreement, dated effective as of January 1, 2011, by and among Deep Down, Inc. and Cuming Flotation Technologies, LLC (incorporated by reference from Exhibit 10.6 to our Form 8-K filed January 5, 2011).10.40

First Amendment to Management Services Agreement, dated effective as of March 1, 2011, by and among Deep Down, Inc. and Cuming Flotation Technologies, LLC (incorporated by reference from Exhibit 10.1 to our Form 8-K filed March 8, 2011).10.41*

Waiver, dated March 25, 2011, by and between Whitney National Bank, as lender, and Deep Down, Inc., as borrower.10.42*

Second Amendment to Amended and Restated Credit Agreement, dated April 14, 2011, by and among Deep Down, Inc., as borrower, and Whitney National Bank, as lender, including the Guarantor’s Consent and Agreement as signed on behalf of ElectroWave USA, Inc., Flotation Technologies, Inc., Mako Technologies, LLC, Deep Down, Inc. and Deep Down International Holdings, LLC.
 48
 
 Exhibit Number

Description of Exhibit
 14.1

Directors Code of Business Conduct (incorporated herein by reference from Exhibit 14.1 to our Form 10-K filed with the Commission on April 15, 2010).14.2

Financial Officer’s Code of Business Conduct (incorporated herein by reference from Exhibit 14.2 to our Form 10-K filed with the Commission on April 15, 2010).16.1

Letter, dated July 14, 2009, from Malone & Bailey, PC to the Securities and Exchange Commission (incorporated by reference from Exhibit 16.1 to our Form 8-K filed on July 14, 2009).16.2

Letter, dated June 30, 2010, from PricewaterhouseCoopers LLP to the Securities and Exchange Commission (incorporated by reference from Exhibit 16.1 to our Form 8-K filed July 7, 2010).21.1*

Subsidiary list.24.1*

Power of Attorney (set forth immediately following the registrant’s signatures to this report).31.1*

Rule 13a-14(a)/15d-14(a) Certification of the President and Chief Executive Officer of Deep Down, Inc.31.2*

Rule 13a-14(a)/15d-14(a) Certification of the Chief Financial Officer of Deep Down, Inc.32.1*

Section 1350 Certification of the President and Chief Executive Officer of Deep Down, Inc.32.2*

Section 1350 Certification of the Chief Financial Officer of Deep Down, Inc.
 * Filed or furnished herewith.
 † Exhibit constitutes a management contract or compensatory plan or arrangement.
 
 49
 
 INDEX TO CONSOLIDATED FINANCIAL STATEMENTS








Reports of Independent Registered Public Accounting Firms
F-2Consolidated Balance Sheets
F-4Consolidated Statements of Operations
F-5Consolidated Statements of Changes in Stockholders’ Equity
F-6Consolidated Statements of Cash Flows
F-7Notes to the Consolidated Financial Statements
F-8





F-1




Independent Auditors’ Report
  The Board of Directors
 Deep Down, Inc.:
  We have audited the accompanying consolidated balance sheet of Deep Down, Inc. and subsidiaries as of December 31, 2010, and the related consolidated statement of operations, statement of changes in stockholders’ equity and cash flows for the year then ended. These consolidated financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these consolidated financial statements based on our audit.
  We conducted our audit in accordance with generally accepted auditing standards as established by the Auditing Standards Board (United States) and in accordance with the auditing standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. Our audit included consideration of internal control over financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion. An audit also includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audit provides a reasonable basis for our opinion.
  In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of Deep Down, Inc. and subsidiaries as of December 31, 2010, and the results of their operations and their cash flows for the year then ended in conformity with U.S. generally accepted accounting principles.
   /s/ KPMG LLP
  April 15, 2011




F-2





REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM





To the Board of Directors and Stockholders of Deep Down, Inc.





We have audited the accompanying consolidated balance sheet of Deep Down, Inc. and its subsidiaries as of December 31, 2009, and the related consolidated statement of operations, shareholders' equity and cash flows for the year ended December 31, 2009. These financial statements are the responsibility of the Company’s management.  Our responsibility is to express an opinion on these financial statements based on our audit.





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





In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of Deep Down, Inc. and their subsidiaries at December 31, 2009, and the results of their operations and their cash flows for the year ended December 31, 2009 in conformity with accounting principles generally accepted in the United States of America.





/s/ PRICEWATERHOUSE COOPERS LLP


Houston, Texas


April 15, 2010, except for the effects of the matter discussed in Note 2, as to which the date is April 15, 2011





F-3





DEEP DOWN, INC.


CONSOLIDATED BALANCE SHEETS





(In thousands, except par value amounts)

December 31, 2010


December 31, 2009ASSETSCurrent assets:Cash and cash equivalents

$
3,730


$
912Accounts receivable, net of allowance of $245 and $304, respectively


5,518



7,662Inventory


223



896Costs and estimated earnings in excess of billings on uncompleted contracts


-



267Prepaid expenses and other current assets


267



225Total current assets


9,738



9,962Property, plant and equipment, net


11,676



20,011Investment in joint venture


3,146



-Intangibles, net


2,908



12,342Goodwill


4,916



9,429Other assets


1,240



960Total assets

$
33,624


$
52,704LIABILITIES AND STOCKHOLDERS' EQUITYCurrent liabilities:Accounts payable and accrued liabilities

$
5,719


$
2,865Billings in excess of costs and estimated earnings on uncompleted contracts


446



4,984Deferred revenues


315



89Current portion of long-term debt


1,609



1,497Total current liabilities


8,089



9,435Long-term debt, net


2,443



5,379Total liabilities


10,532



14,814Commitments and contingencies (Note 13)Stockholders' equity:Common stock, $0.001 par value, 490,000 shares authorized, 207,399and 180,451 shares, respectively, issued and outstanding


207



180Additional paid-in capital


63,751



61,161Accumulated deficit


(40,866
)


(23,451
)Total stockholders' equity


23,092



37,890Total liabilities and stockholders' equity

$
33,624


$
52,704


The accompanying notes are an integral part of the consolidated financial statements.




F-4


DEEP DOWN, INC.


CONSOLIDATED STATEMENTS OF OPERATIONS


FOR THE YEARS ENDED DECEMBER 31, 2010 and 2009




Year Ended

December 31,(In thousands, except per share amounts)

2010


2009Revenues

$
42,471


$
28,810Cost of sales:Cost of sales


26,559



18,272Depreciation expense


2,327



1,616Total cost of sales


28,886



19,888Gross profit


13,585



8,922Operating expenses:Selling, general and administrative


13,964



14,371Depreciation and amortization


1,731



6,538Goodwill impairment


4,513



5,537Total operating expenses


20,208



26,446Operating loss


(6,623
)


(17,524
)Other income (expense):Interest expense, net


(510
)


(356
)Loss on contribution of net assets of wholly-owned subsidiary


(10,119
)


-Equity in net loss of joint venture


(254
)


-Other income, net


266



73Total other expense


(10,617
)


(283
)Loss before income taxes


(17,240
)


(17,807
)Income tax (expense) benefit


(175
)


1,026Net loss

$
(17,415
)

$
(16,781
)Net loss per share, basic and diluted

$
(0.09
)

$
(0.09
)Weighted-average common sharesoutstanding, basic and diluted


193,147



179,430




The accompanying notes are an integral part of the consolidated financial statements.




F-5




DEEP DOWN, INC.


STATEMENTS OF CHANGES IN STOCKHOLDERS’ EQUITY


FOR THE YEARS ENDED DECEMBER 31, 2010 and 2009




Common Stock


Additional

Paid-in


Accumulated(In thousands)

Shares (#)


Amount ($)


Capital


Deficit


TotalBalance at December 31, 2008


177,351


$
177


$
60,328


$
(6,670
)

$
53,835Net loss


-



-



-



(16,781
)


(16,781
)Restricted stock issued for service


3,100



3



(3
)


-



-Share-based compensation


-



-



836



-



836Balance at December 31, 2009


180,451


$
180


$
61,161


$
(23,451
)

$
37,890Net loss


-



-



-



(17,415
)


(17,415
)Issuance of common stock pursuant to aprivate placement


5,150



5



510



-



515Issuance of restricted stock


1,798



2



(27
)


-



(25
)Stock issued


20,000



20



1,380



-



1,400Share-based compensation


-



-



727



-



727Balance at December 31, 2010


207,399


$
207


$
63,751


$
(40,866
)

$
23,092


The accompanying notes are an integral part of the consolidated financial statements.




F-6




DEEP DOWN, INC.


CONSOLIDATED STATEMENTS OF CASH FLOWS


FOR THE YEARS ENDED DECEMBER 31, 2010 and 2009


Year Ended

December 31,(In thousands)

2010


2009Cash flows from operating activities:Net loss

$
(17,415
)

$
(16,781
)Adjustments to reconcile net loss to net cash provided by operating activities:Impairment of goodwill


4,513



5,537Equity in loss of joint venture


254



-Share-based compensation


727



836Stock issued for services


14



-Bad debt expense


72



192Depreciation and amortization


4,058



8,154(Gain) loss on disposal of property, plant and equipment


(190
)


78Deferred income taxes, net


-



(909
)Changes in assets and liabilities:Accounts receivable


1,669



2,918Inventory


79



466Costs and estimated earnings in excess of billings on uncompleted contracts


267



441Prepaid expenses and other current assets


233



409Other assets


189



(113
)Accounts payable and accrued liabilities


2,827



(1,454
)Deferred revenues


227



80Billings in excess of costs and estimated earnings on uncompleted contracts


(1,567
)


2,678Net cash (used in) provided by operating activities


(4,043
)


2,532Cash flows from investing activities:Purchases of property, plant and equipment


(2,634
)


(6,117
)Proceeds from sale of property, plant and equipment


251



148Investment in cost method securities


(25
)


(200
)Cash paid for equity investment in joint venture


(1,400
)


-Contribution of net assets of wholly-owned subsidiary


10,119



-Proceeds from final settlement of acquisition of Flotation


-



58Cash paid for capitalized software


(278
)


(614
)Proceeds from note receivable


(87
)


(22
)Change in restricted cash


-



136Net cash provided by (used in) investing activities


5,946



(6,611
)Cash flows from financing activities:Proceeds from sale of common stock


1,901



-Stock cancelled for payroll taxes


(25
)


-Borrowings of long-term debt


-



3,000Repayments of long-term debt


(961
)


(504
)Net cash provided by financing activities


915



2,496Change in cash and equivalents


2,818



(1,583
)Cash and cash equivalents, beginning of period


912



2,495Cash and cash equivalents, end of period

$
3,730


$
912Supplemental schedule of noncash operating, investing and financing activities:Cash paid for interest

$
519


$
373Prepaid insurance purchased with debt

$
305


$
-Fixed assets purchased with debt

$
-


$
2,100Fixed assets purchased with capital lease

$
253


$
92Fixed assets transferred to other assets

$
100


$
-Restricted stock issued for service

$
2


$
3




The accompanying notes are an integral part of the consolidated financial statements.





F-7





Notes to Consolidated Financial Statements for the Years ended December 31, 2010 and 2009
 (Amounts in thousands except per share amounts)


Note 1: Description of Business and Summary of Significant Accounting Policies





Description of Business





Deep Down, Inc., and its wholly-owned subsidiaries (“Deep Down”, “we”, “us” or the “Company”) isan oilfield services company serving the worldwide offshore exploration and production industry. Our services and technological solutions include distribution system installation support and engineering services, umbilical terminations, loose-tube steel flying leads, flotation and drill riser buoyancy, Remote Operated Vehicles (“ROVs”) and toolings. We support subsea engineering, installation, commissioning, and maintenance projects through specialized, highly experienced service teams and engineered technological solutions. Deep Down’s primary focus is on more complex deepwater and ultra-deepwater oil production distribution system support services and technologies, used between the platform and the wellhead.





As described below in Note 4 “Investment in Joint Venture”, effective December 31, 2010, we engaged in a transaction in which all of the operating assets and liabilities of our wholly-owned subsidiary, Flotation Technologies, Inc. ("Flotation"), were contributed, along with other contributions we made, to a joint venture entity named Cuming Flotation Technologies, LLC (“CFT”),  in return for a 20% common unit ownership interest in CFT.





In the notes to the consolidated financial statements, all dollar and share amounts are in thousands of dollars and shares, unless otherwise indicated.





Liquidity





As a deepwater service provider, our revenues, profitability, cash flows, and future rate of growth are substantially dependent on the condition of the global oil and gas industry generally, and our customers’ ability to invest capital for offshore exploration, drilling and production and maintain or increase levels of expenditures for maintenance of offshore drilling and production facilities.  Oil and gas prices and the level of offshore drilling and production activity have historically been characterized by significant volatility.  We enter into large, fixed-price contracts which may require significant lead time and investment.  A decline in offshore drilling and production activity could result in lower contract volume or delays in significant contracts which could negatively impact our earnings and cash flows.  Our earnings and cash flows could also be negatively affected by delay in payments by significant customers or delays in completion of our contracts for any reason.  While our objective is to enter into contracts with our customers that are cash flow positive, we may not always be able to achieve this objective.  We are dependent on our cash flows from operations to fund our working capital requirements and the uncertainties noted above create risks that we may not achieve our planned earnings or cash flow from operations, which may require us to raise additional debt or equity capital.  There can be no assurance that we could raise additional capital.





During our fiscal years ended December 31, 2010 and 2009, we have supplemented the financing of our capital needs through a combination of debt and equity financings.  Most significant in this regard has been our debt facility we have maintained with Whitney National Bank (“Whitney”). Our loans outstanding under the Amended and Restated Credit Agreement with Whitney (the “Restated Credit Agreement”) become due on April 15, 2012.  We will need to raise additional debt or equity capital or renegotiate the existing debt prior to such date.  We are currently in discussions with several lenders who have expressed interest in refinancing our debt. Our plan is to refinance the outstanding indebtedness under the Restated Credit Agreement or seek terms with Whitney that will provide an extension of such Restated Credit Agreement along with additional liquidity.  However, we cannot provide any assurance that any financing will be available to us on acceptable terms or at all.  If we are unable to raise additional capital or renegotiate our existing debt, this would have a material adverse impact on our business or would raise substantial doubt about our ability to continue as a going concern.  In addition to the foregoing, as of December 31, 2010, we were not in compliance with the financial covenants under the Restated Credit Agreement.  On March 25, 2011 we obtained a waiver for these covenants as of December 31, 2010.





Although the factors described above create uncertainty, if our planned financial results are achieved we believe that we will have adequate liquidity to meet our future operating requirements, and we believe we will be able to raise additional capital or renegotiate our existing debt.


F-8





Notes to Consolidated Financial Statements for the Years ended December 31, 2010 and 2009


(Amounts in thousands except per share amounts)




Summary of Significant Accounting Policies





Principles of consolidation





The consolidated financial statements include the accounts of Deep Down and its wholly-owned subsidiaries for the years ended December 31, 2010 and 2009. All intercompany transactions and balances have been eliminated.





Use of Estimates





The preparation of financial statements in conformity with generally accepted accounting principles requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.





Segments





For the fiscal years ended December 31, 2010 and 2009, our operating segments, Deep Down Delaware, Mako and Flotation have been aggregated into a single reporting segment. Effective December 31, 2010 we contributed all of Flotation’s operating assets and liabilities to CFT. While the operating segments have different product lines; they are very similar. They are all service-based operations revolving around our personnel’s expertise in the deepwater and ultra-deepwater industry, and any equipment is produced to a customer specified design and engineered using Deep Down personnel’s expertise, with installation and project management as part of our service revenue to the customer. Additionally, the segments have similar customers and distribution methods, and their economic characteristics are similar with regard to their gross margin percentages.  Our operations are located in the United States, though we occasionally make sales to multi-national customers.





Other comprehensive income





Deep Down has no items that comprise other comprehensive income for the years ended December 31, 2010 and 2009.





Reclassifications





Prior period information presented in these financial statements includes reclassifications which were made to conform to the current period presentation. Specifically, depreciation expense included in cost of sales has been presented as a separate line in the consolidated statements of operations.  Additionally, deferred revenues have been split out from billings in excess of costs and estimated earnings on uncompleted contracts on the face of the balance sheets.  These reclassifications had no effect on our previously reported gross profit, net loss or stockholders’ equity.





Cash and Cash Equivalents and Restricted Cash





We consider all highly liquid investments with maturities from date of purchase of three months or less to be cash equivalents. Cash and equivalents consist of cash on deposit with foreign and domestic banks and, at times, may exceed federally insured limits.





At December 31, 2008, we had restricted cash of $136 related to a letter of credit for a vendor, which was released due to completion of the project during 2009.




F-9


Notes to Consolidated Financial Statements for the Years ended December 31, 2010 and 2009
 (Amounts in thousands except per share amounts)


Fair Value of Financial Instruments





Fair value is defined as the exchange price that would be received for an asset or paid to transfer a liability (an exit price) in the principal or most advantageous market for the asset or liability in an orderly transaction between market participants on the measurement date.  We utilize a fair value hierarchy, which maximizes the use of observable inputs and minimizes the use of unobservable inputs when measuring fair value.  The fair value hierarchy has three levels of inputs that may be used to measure fair value:





Level 1 - Unadjusted quoted prices in active markets that are accessible at the measurement date for identical, unrestricted assets or liabilities.




Level 2 - Quoted prices in markets that are not active; or other inputs that are observable, either directly or indirectly, for substantially the full term of the asset or liability.




Level 3 - Prices or valuation techniques that require inputs that are both significant to the fair value measurement and unobservable.





Ourfinancial instruments consist primarily of cash equivalents, trade receivables and payables and debt instruments.The carrying values of cash, accounts receivable, accounts payable and notes payable approximate their fair values due to the short-term maturity of these instruments.





For discussion of assets and liabilities measured at fair value on a non-recurring basis, see Note 6 "Intangibles Assets and Goodwill."





Accounts Receivable





We provide an allowance for doubtful accounts on trade receivables based on historical collection experience, the level of past due accounts and a specific review of each customer’s trade receivable balance with respect to their ability to make payments and expectations of future conditions that could impact the collectability of accounts receivable.  When specific accounts are determined to be uncollectable, they are expensed as bad debt expense in that period. At December 31, 2010 and 2009, we estimated the allowance for doubtful accounts to be $245 and $304, respectively. Bad debt expense totaled $72 and $192 for the years ended December 31, 2010 and 2009, respectively.





Concentration of Credit Risk





As of December 31, 2010, five of our customers accounted for 19 percent, 18 percent, 16 percent, 12 percent and 8 percent of total accounts receivable, respectively. For the year ended December 31, 2009, four of our customers accounted for 22 percent, 9 percent, 8 percent and 5 percent of total accounts receivable, respectively.  For the year ended December 31, 2010, our five largest customers accounted for 24 percent, 11 percent, 9 percent, 9 percent and 7 percent of total revenues, respectively.  For the year ended December 31, 2009, our five largest customers accounted for 12 percent, 10 percent, 8 percent, 6 percent and 5 percent of total revenues, respectively.




F-10


Notes to Consolidated Financial Statements for the Years ended December 31, 2010 and 2009
 (Amounts in thousands except per share amounts)


Inventory and Work in Progress





Inventory is stated at lower of cost (first-in, first out) or net realizable value.




December 31, 2010


December 31, 2009Raw materials

$
167


$
765Work in progress


56



84Finished goods


-



47Total inventory

$
223


$
896




A portion of work in progress represents costs that have been incurred for time and materials that are not appropriate to be billed to customers at such date, according to the contractual terms.





Long-Lived Assets





Property, Plant and Equipment  Property, plant and equipment are stated at cost, net of accumulated depreciation. Depreciation and amortization are computed using the straight-line method over the estimated useful lives of the respective assets. Buildings are depreciated between seven and thirty-six years, and leasehold improvements are amortized over the shorter of the assets' useful lives or lease terms. Equipment lives range from two to fifteen years, computers and office equipment lives are generally from two to three years, and furniture and fixtures are two to eight years. Replacements and betterments are capitalized, while maintenance and repairs are expensed as incurred. It is our policy to include depreciation expense on assets acquired under capital leases with depreciation expense on owned assets. Additionally, we record depreciation expense related to revenue-generating assets as Cost of Sales on the accompanying statements of operations.




Other AssetsWe capitalize certain internal and external costs related to the acquisition and development of internal use software during the application development stages of projects.Such costs consist primarily of custom-developed and packaged software and the direct labor costs of internally-developed software and are included with Other Assets on the accompanying balance sheets.  Capitalized costs are amortized using the straight-line method over the estimated lives of the software, which range from three to five years.  The costs capitalized in the application development stage include the costs of design, coding, installation of hardware and testing. We capitalize costs incurred during the development phase of the project as permitted. Costs incurred during the preliminary project or the post-implementation/operation stages of the project are expensed as incurred.




Additionally, we recorded an investment in a nonmarketable equity security, in which we own less than 20 percent, at cost during the years ended December 31, 2010 and 2009 in the amount of $225. We review this investment on a regular basis to determine if there has been a decline in market value.




Long-lived intangible assets.Our intangible assets generally consist of assets acquired in the purchases of the Mako and Flotation subsidiaries and are comprised of customer lists, non-compete covenants with key employees and trademarks related to Mako’s ROVs and to Flotation’s branding, processes, materials and technology.  We amortize intangible assets over their useful lives ranging from six to twenty-five years on a straight-line basis.  We make judgments and estimates in conjunction with the carrying value of these assets, including amounts to be capitalized, depreciation and amortization methods, useful lives and the valuation of acquired long-lived intangible assets. All the intangible assets of Flotation were contributed to CFT effective December 31, 2010, see additional discussion at Note 4, “Investment in Joint Venture.”





We test for the impairment of long-lived assets upon the occurrence of a triggering event. We base our evaluation on impairment indicators such as the nature of the assets, the future economic benefit of the assets, any historical or future profitability measurements and other external market conditions or factors that may be present. If these impairment indicators are present or other factors exist that indicate the carrying amount of an asset may not be recoverable, we determine whether an impairment has occurred through the use of an undiscounted cash flows analysis of the asset at the lowest level for which identifiable cash flows exist. The undiscounted cash flow analysis consists of estimating the future cash flows that are directly associated with and expected to arise from the use and eventual disposition of the asset over its remaining useful life. These cash flows are inherently subjective and require significant estimates based upon historical experience and future expectations reflected in our budgets and internal projections. If the undiscounted cash flows do not exceed the carrying value of the long-lived asset, an impairment has occurred, and we recognize a loss for the difference between the carrying amount and the estimated fair value of the asset. The fair value of the asset is measured using quoted market prices or, in the absence of quoted market prices, is based on an estimate of discounted cash flows. Cash flows are generally discounted at an interest rate commensurate with our weighted average cost of capital for a similar asset.




F-11


Notes to Consolidated Financial Statements for the Years ended December 31, 2010 and 2009
 (Amounts in thousands except per share amounts)


There was no impairment of long-lived assets for the year ended December 31, 2010.  We assessed the market conditions and have concluded, as of December 31, 2009, that a triggering event had occurred that required an impairment analysis of long-lived intangible assets. For the year ended December 31, 2009, we recorded impairment charges totaling $4,616 to several long-lived intangible assets, which total impairment charges were recorded on the statement of operations as amortization expense. See further discussion in Note 6 "Intangible Assets and Goodwill" regarding the testing and conclusions.





Goodwill





Goodwill represents the cost in excess of the fair value of net assets acquired in business combinations. We evaluate the carrying value of goodwill annually on December 31 and between annual evaluations if events occur or circumstances change that would more likely than not reduce the fair value of the reporting unit below its carrying amount. Such circumstances could include a significant adverse change in legal factors or in business or the business climate or unanticipated competition. For purposes of our annual impairment test, our reporting units are the same as our operating segments discussed above.




The test for goodwill impairment is a two-step approach. The first step is to compare the estimated fair value of any reporting units within the Company that have goodwill with the recorded net book value (including the goodwill) of the reporting unit. If the estimated fair value of the reporting unit is higher than the recorded net book value, no impairment is deemed to exist and no further testing is required. If, however, the estimated fair value of the reporting unit is below the recorded net book value, then a second step must be performed to determine the goodwill impairment required, if any. In this second step, the estimated fair value from the first step is used as the purchase price in a hypothetical acquisition of the reporting unit. Purchase business combination accounting rules are followed to determine a hypothetical purchase price allocation to the reporting unit’s assets and liabilities. The residual amount of goodwill that results from this hypothetical purchase price allocation is compared to the carrying value of goodwill for the reporting unit, and the carrying value is written down to the hypothetical amount, if lower.




Equity Method Investments
  Equity method investments in joint ventures are reported as investments in joint venture in the consolidated balance sheets, and our share of earnings or losses is included in the statement of operations and reported as equity in net income or loss of joint venture in the consolidated statements of operations. At December 31, 2010, our accumulated deficit included $254 related to the undistributed equity in net loss of joint venture.





Lease Obligations





We lease land, buildings, vehicles and certain equipment under non-cancellable operating leases.  Since February 2009, we lease our corporate headquarters in Houston, Texas, under a non-cancellable operating lease. Mako leases office, warehouse and operating space in Morgan City, Louisiana, under a non-cancellable operating lease, and Flotation leases their manufacturing and warehousing locations in Biddeford, Maine under non-cancellable operating leases; this lease obligation was contributed to CFT effective December 31, 2010 as discussed in Note 4 “Investment in Joint Venture.” We also lease certain office and other operating equipment under capital leases; the related assets are included with Property, Plant and Equipment on the consolidated balance sheets.





At the inception of a lease, we evaluate each agreement to determine whether the lease will be accounted for as an operating or capital lease. The term of the lease used for such an evaluation includes renewal option periods only in instances in which the exercise of the renewal option can be reasonably assured and failure to exercise such option would result in an economic penalty.





Revenue Recognition




We recognize revenue once the following four criterions are met:  (i) persuasive evidence of an arrangement exists, (ii) delivery of the equipment has occurred or services have been rendered, (iii) the price of the equipment or service is fixed and determinable and (iv) collectability is reasonably assured. Service revenue is recognized as the service is provided, and “time and material” contracts are billed on a bi-weekly or monthly basis as costs are incurred. Customer billings for shipping and handling charges are included in revenue.





From time to time, we enter into large fixed price contracts which we determine that recognizing revenues for these types of contracts is appropriate using the percentage-of-completion method, which compares the percentage of costs incurred to date to the estimated total costs for the contract.  This method is appropriate because management considers total costs the best available measure of progress.




F-12


Notes to Consolidated Financial Statements for the Years ended December 31, 2010 and 2009
 (Amounts in thousands except per share amounts)


Total costs include all direct material and labor costs plus all indirect costs related to contract performance, such as supplies, equipment repairs, employee travel and supervisor time. Selling, general and administrative costs are charged to expense as incurred.  Provisions for estimated losses on uncompleted contracts (if any) are made in the period in which such losses are determined.  Changes in job performance, job conditions, and total contract values may result in revisions to costs and income and are recognized in the period in which the revisions are determined.  Unapproved change orders are accounted for in revenue and cost when it is probable that the costs will be recovered through a change in the contract price. In circumstances where recovery is considered probable but the revenues cannot be reliably estimated, costs attributable to change orders are deferred pending determination of contract price.





Costs and estimated earnings in excess of billings on uncompleted contracts arise when revenues are recorded on a percentage-of-completion basis but cannot be invoiced under the terms of the contract. Such amounts are invoiced upon completion of contractual milestones. Billings in excess of costs and estimated earnings on uncompleted contracts arise when milestone billings are permissible under the contract, but the related costs have not yet been incurred.All contract costs are recognized currently on jobs formally approved by the customer and contracts are not shown as complete until virtually all anticipated costs have been incurred and the items are shipped to the customer.





Assets and liabilities related to costs and estimated earnings in excess of billings on uncompleted contracts, as well as billings in excess of costs and estimated earnings on uncompleted contracts, have been classified as current. The contract cycle for certain long-term contracts may extend beyond one year, thus complete collection of amounts related to these contracts may extend beyond one year, though such long-term contracts include contractual milestone billings as discussed above.





All intercompany revenue balances and transactions were eliminated in consolidation.





Income Taxes





We follow the asset and liability method of accounting for income taxes.  This method takes into account the differences between financial statement treatment and tax treatment of certain transactions. 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 tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effect of a change in tax rates is recognized as income or expense in the period that includes the enactment date. Our effective tax rates for 2010 and 2009 were (1.0) percent, and 5.98 percent, respectively.





We record a valuation allowance to reduce the carrying value of our deferred tax assets when it is more likely than not that some or all of the deferred tax assets will expire before realization of the benefit or that future deductibility is not probable. The ultimate realization of the deferred tax assets depends upon our ability to generate sufficient taxable income of the appropriate character in the future. This requires management to use estimates and make assumptions regarding significant future events such as the taxability of entities operating in the various taxing jurisdictions. In evaluating our ability to recover our deferred tax assets, we consider all reasonably available positive and negative evidence, including our past operating results, the existence of cumulative losses in the most recent years and our forecast of future taxable income. In estimating future taxable income, we develop assumptions, including the amount of future state, and federal pretax operating income, the reversal of temporary differences and the implementation of feasible and prudent tax planning strategies. These assumptions require significant judgment. When the likelihood of the realization of existing deferred tax assets changes, adjustments to the valuation allowance are charged, in the period in which the determination is made, either to income or goodwill, depending upon when that portion of the valuation allowance was originally created.




F-13


Notes to Consolidated Financial Statements for the Years ended December 31, 2010 and 2009
 (Amounts in thousands except per share amounts)


We record an estimated tax liability or tax benefit for income and other taxes based on what we determine will likely be paid in the various tax jurisdictions in which we operate.  We use our best judgment in the determination of these amounts.  However, the liabilities ultimately realized and paid are dependent upon various matters, including resolution of tax audits, and may differ from amounts recorded.  An adjustment to the estimated liability would be recorded as a provision or benefit to income tax expense in the period in which it becomes probable that the amount of the actual liability or benefit differs from the recorded amount.





Our future effective tax rates could be adversely affected by changes in the valuation of our deferred tax assets or liabilities or changes in tax laws or interpretations thereof.  If and when our deferred tax assets are no longer fully reserved, we will begin to provide for taxes at the full statutory rate.  In addition, we are subject to the examination of our income tax returns by the Internal Revenue Service and other tax authorities.  We regularly assess the likelihood of adverse outcomes resulting from these examinations to determine the adequacy of our provision for income taxes.





Share-based Compensation





We record share-based payment awards exchanged for employee services at fair value on the date of grant and expense the awards in the consolidated statements of operations over the requisite employee service period.  Share-based compensation expense includes an estimate for forfeitures and is generally recognized over the expected term of the award on a straight-line basis.  At December 31, 2010, we had two types of share-based employee compensation: stock options and restricted stock.





Key assumptions used in the Black-Scholes model for stock option valuations include (1) expected volatility (2) expected term (3) discount rate and (4) expected dividend yield. Since we do not have a sufficient trading history to determine the volatility of our own stock, we based our estimates of volatility on a representative peer group consisting of companies in the same industry, with similar market capitalizations and similar stage of development.  Additionally, we continue to use the simplified method related to employee option grants.





The fair value of each stock option grant is estimated on the date of the grant using the Black-Scholes model and is based on the following key assumptions for the years ended December 31, 2010 and 2009:




December 31, 2010

December 31, 2009Dividend yield
0%

0%Risk free interest rate
2.08% - 2.49%

1.69% - 2.33%Expected life of options
3.5 years

3 yearsExpected volatility
94.7% - 97.4%

88.5% - 92.8%





Earnings/(Loss) per Common Share





Basic EPS is calculated by dividing net income/(loss) by the weighted average number of common shares outstanding for the period. Diluted EPS is calculated by dividing net income/(loss) by the weighted average number of common shares and dilutive common stock equivalents (stock awards and stock options) outstanding during the period. Dilutive EPS reflects the potential dilution that could occur if options and warrants to purchase common stock were exercised for shares of common stock. The following is a reconciliation of the number of shares (denominator) used in the basic and diluted EPS computations:




Year EndedDecember 31,2010


2009Numerator:Net income (loss)

$
(17,415
)

$
(16,781
)Denominator:Weighted average number ofcommon shares outstanding


193,147



179,430Effect of dilutive securities


-



-Denominator for diluted earnings per share


193,147



179,430Net loss per common share outstanding,basic and diluted

$
(0.09
)

$
(0.09
)Diluted net loss per common share

$
(0.09
)

$
(0.09
)


There were no potentially dilutive securities for the years ended December 31, 2010 and 2009 which were excluded from the computation of diluted earnings per share because their effect would have been anti-dilutive.




F-14




Notes to Consolidated Financial Statements for the Years ended December 31, 2010 and 2009
 (Amounts in thousands except per share amounts)


Recently Issued Accounting Standards





In January 2010, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2010-06, Improving Disclosures about Fair Value Measurements (“ASU 2010-06”). This update provides amendments to Subtopic 820-10 and requires new disclosures for 1) significant transfers in and out of Level 1 and Level 2 and the reasons for such transfers and 2) activity in Level 3 fair value measurements to show separate information about purchases, sales, issuances and settlements. In addition, this update amends Subtopic 820-10 to clarify existing disclosures around the disaggregation level of fair value measurements and disclosures for the valuation techniques and inputs utilized (for Level 2 and Level 3 fair value measurements). The provisions in ASU 2010-06 are applicable to interim and annual reporting periods beginning subsequent to December 15, 2009, with the exception of Level 3 disclosures of purchases, sales, issuances and settlements, which will be required in reporting periods beginning after December 15, 2010. The adoption of ASU 2010-06 did not impact our operating results, financial position or cash flows.




In April 2010, the FASB issued accounting guidance for the milestone method of revenue recognition. This guidance allows entities to make a policy election to use the milestone method of revenue recognition and provides guidance on defining a milestone and the criteria that should be met for applying the milestone method. The scope of this guidance is limited to transactions involving milestones relating to research and development deliverables. The guidance includes enhanced disclosure requirements about each arrangement, individual milestones and related contingent consideration, information about substantive milestones and factors considered in the determination. This guidance is effective prospectively to milestones achieved in fiscal years, and interim periods within those years, beginning after June 15, 2010. Early application and retrospective application are permitted. We have evaluated this new guidance and have determined that it will not currently have a significant impact on the determination or reporting of our financial results.








F-15




Notes to Consolidated Financial Statements for the Years ended December 31, 2010 and 2009
 (Amounts in thousands except per share amounts)


Note 2: Revision of 2009 Consolidated Financial Statements





As discussed in our Form 10Q/A for the quarter ended September 30, 2010, filed with the SEC on March 8, 2011, in conjunction with an internal review meeting of Flotation, our management reviewed the status of one of our long-term fixed price contracts (the “Contract”) that we entered into in November 2008 which is scheduled to be completed in the third quarter of 2011. As a result of this review, our management identified errors in the percentage-of-completion accounting model for revenue recognition pertaining to this Contract. We considered the effect of the error to be immaterial to the consolidated financial statements as of and for the year ended December 31, 2009. The audited consolidated balance sheet and statements of operations, cash flows and stockholders’ equity for the year ended December 31, 2009 included in this Form 10-K have been adjusted to correct the immaterial effects of the error.





The 2009 consolidated balance sheet reflects the increase of $639 to the amounts of billings in excess of costs and estimated earnings on uncompleted contracts and accumulated deficit. On the consolidated statement of operations, revenues and gross profit for the year ended December 31, 2009 were reduced by $639, which resulted in a corresponding $639 increase to operating loss, loss before income taxes and net loss. On the consolidated statement of cash flows, the revision increased net loss by $639 which was offset to billings in excess of costs and estimated earnings on uncompleted contracts, for a net impact to cash flows provided by operations of $0. On the consolidated statement of stockholders’ equity, the revision increased accumulated deficit by $639.




Note 3: Costs and Estimated Earnings in Excess of Billings on Uncompleted Contracts and Deferred Revenue





The components of costs and estimated earnings in excess of billings on uncompleted contracts are summarized below:




December 31, 2010


December 31, 2009Costs incurred on uncompleted contracts

$
319


$
3,319Estimated earnings on uncompleted contracts


151



2,304470



5,623Less: Billings to date on uncompleted contracts


(916
)


(10,340
)$
(446
)

$
(4,717
)Included in the accompanying consolidatedbalance sheets under the following captions:Costs and estimated earnings in excess of billingson uncompleted contracts

$
-


$
267Billings in excess of costs and estimated earningson uncompleted contracts


(446
)


(4,984
)$
(446
)

$
(4,717
)




At December 31, 2009, the asset balance of $267 was related to two contracts that were completed during fiscal 2010. The balances in billings in excess of costs and estimated earnings on uncompleted contracts at December 31, 2010 and December 31, 2009, were $446 and $4,984, respectively, and consisted of significant milestone billings, primarily related to a large fabrication project, plus several smaller contracts. In connection with the contribution of net assets and liabilities of Flotation to CFT, $2,972 in billings in excess of costs and estimated earnings on uncompleted contracts was contributed at December 31, 2010.  See further discussion in Note 4 “Investment in Joint Venture.”





As discussed in Note 2, “Revision of 2009 Consolidated Financial Statements”,the December 31, 2009 balances reflect the correction of an immaterial error that resulted in an increase of $639 to the amounts of billings in excess of costs and estimated earnings on uncompleted contracts, which is comprised of a decrease in costs incurred on uncompleted contracts of $731, offset by an increase in estimated earnings on uncompleted contracts of $92.





At December 31, 2010 and 2009, we reported deferred revenue liability balances of $315 and $89, respectively. These balances represented prepayments or deposits on time and material and rental projects for which work has not yet been performed. We expect to recognize the deferred revenue at December 31, 2010 during fiscal 2011.




F-16




Notes to Consolidated Financial Statements for the Years ended December 31, 2010 and 2009
 (Amounts in thousands except per share amounts)


Note 4: Investment in Joint Venture





On December 31, 2010, the Company and its wholly-owned subsidiary Flotation, entered into a Contribution Agreement by and among the Company, Flotation, Cuming Flotation Technologies, LLC, a Delaware limited liability company (“CFT”), and Flotation Investor, LLC, a Delaware operating limited liability company (“Holdings”), pursuant to which Flotation contributed all of its assets and liabilities (except for one intercompany corporate overhead payable) to CFT in exchange for common units of CFT.  Pursuant to the Contribution Agreement, we contributed to CFT $1,400 in cash and all of our rights and obligations under that certain Stock Purchase Agreement, dated May 3, 2010, as amended (the “Cuming SPA”), by and among the Company, Cuming Corporation, a Massachusetts corporation (“Cuming”), and the stockholders of Cuming, in exchange for common units of CFT.  Concurrently with the closing of the transactions described above, CFT contributed the assets and liabilities it acquired from Flotation to Flotation Tech, LLC, a Delaware limited liability company and wholly-owned subsidiary of CFT.
 On December 31, 2010, we entered into a Contract Assignment and Amendment Agreement by and among the Company, CFT and Cuming, pursuant to which we assigned all of our rights and obligations under the Cuming SPA to CFT.  Concurrent with our entry into such Contract Assignment and Amendment Agreement, we entered into a Securities Purchase Agreement, by and among the Company and Holdings (the “Securities Purchase Agreement”), pursuant to which we sold and issued to Holdings 20,000 shares of our common stock for an aggregate purchase price of $1,400.  The Securities Purchase Agreement provides Holdings with registration rights for such 20,000 shares only in the event we fail to maintain current public filings.
 
 In connection with the consummation of the foregoing described transaction, on December 31, 2010, the Company and Flotation entered into an Amended and Restated Limited Liability Company Agreement (the “JV LLC Agreement”) of CFT by and among us, Flotation and Holdings, each as a member of the CFT, to provide for the respective rights and obligations of the members of CFT.  We and Flotation collectively hold 20% of the common units of CFT.  Holdings holds 80% of the common units and 100% of the preferred units, which are entitled to a preferred return until the holder thereof receives a full return of its initial capital contribution.  The preferred units have no voting rights.  Pursuant to the terms of the JV LLC Agreement, we and Flotation collectively have the right to appoint one director to CFT’s board of directors and Holdings has the right to appoint the other 4 directors.  The JV LLC Agreement provides that, without the prior approval of Deep Down and Flotation, certain actions cannot be taken by CFT, including:  increasing the number of members of CFT’s board of directors; amending the JV LLC Agreement or the certificate of formation of CFT in a manner that disproportionately adversely affects Deep Down or Flotation; engaging in activities other than the business of CFT; declaring or paying dividends or distributions not in accordance with the JV LLC Agreement; repurchasing or redeeming CFT units; causing a material change in the nature of CFT’s business; engaging in activity that disproportionately affects Deep Down or Flotation as holders of units of CFT; liquidating, dissolving or effecting a recapitalization or reorganization of CFT; prior to November 2, 2012, authorizing or issuing any equity securities or other securities with equity features or convertible into equity securities except with regard to incentive plans for management; making loans, advancements, guarantees or investments except under certain circumstances; granting an exclusive license in all or substantially all of the intellectual property rights of CFT; amending any provision of, or entering into a resolution of any dispute with the parties under the Cuming SPA; entering into a transaction with an officer, director or other person who is an affiliate of CFT; incurring any funded indebtedness other than for the purpose of retiring CFT’s indebtedness to Holdings until such time as such indebtedness is fully repaid; or agreeing or committing or causing any subsidiary to agree to or commit to any of the above.
 
 Concurrent with the closing of the joint venture transaction on December 31, 2010, we entered into a Management Services Agreement to be effective as of January 1, 2011, with CFT, pursuant to which we provide CFT the services of certain officers and management personnel.  We have amended this Management Services Agreement effective as March 1, 2011 to, among other things, alter the minimum monthly fee we are paid by CFT (due partly to a change in the staffing levels for services and personnel we provide to CFT).


F-17


Notes to Consolidated Financial Statements for the Years ended December 31, 2010 and 2009
 (Amounts in thousands except per share amounts)


Below is a summary of the net assets contributed to CFT as of December 31, 2010:




December 31, 2010Cash and cash equivalents

$
1Accounts receivable


403Inventory


594Prepaid expenses and other current assets


25Property, plant and equipment, net


8,405Intangibles, net


8,035Other assets


23Total assets contributed

$
17,486Accounts payable and accrued expenses


277Billings in excess of costs on uncompleted contracts


2,972Deferred revenue


1Long term debt


2,117Total liabilities contributed

$
5,367Net assets contributed

$
12,119




Below is an unaudited condensed consolidated balance sheet of CFT as of December 31, 2010:


December 31, 2010Current assets

$
53,784Property, plant & equipment


17,896Intangible assets


14,719Other assets


60Total assets

$
86,459Current liabilities

$
59,962Long-term debt


2,019Preferred units - Holdings


8,750Common units - Holdings


13,600Common units - DDI/Flotation


3,400Accumulated deficit


(1,272
)Total liabilities and equity

$
86,459




F-18




Notes to Consolidated Financial Statements for the Years ended December 31, 2010 and 2009
 (Amounts in thousands except per share amounts)
 
 A gain or loss is recognized on the difference between the determined fair value of our investment in CFT and the book value of the net assets contributed. Below is a calculation of the loss we recognized on the contribution of net assets to CFT:
 
 December 31, 2010Book value of Flotation net assets

$
12,119Cash contribution by Deep Down to CFT


1,400Total book value of contributions to CFT


13,519Less:  Fair value of  Investment in CFT


(3,400
)Loss on contribution of Flotation


(10,119
)
 
 The components of our Investment in joint venture as of December 31, 2010 are as follows:
 
 December 31, 2010Contribution to CFT

$
3,400Equity in net loss of CFT for the year ended December 31, 2010


(254
)Investment in joint venture

$
3,146





Due to the above-described transaction, effective December 31, 2010 we will no longer aggregate the contributed operations of Flotation as an operating segment for fiscal periods beginning after such date.





Note 5: Property, Plant and Equipment





Property, plant and equipment consisted of the following as of December 31, 2010 and 2009:




December 31, 2010


December 31, 2009


Range of

Asset LivesLand

$
1,492


$
1,954



-Buildings and improvements


1,540



5,458


7 - 36 yearsLeasehold improvements


221



313


2 - 5 yearsEquipment


9,709



13,773


2 - 15 yearsFurniture, computers and office equipment


930



1,154


2 - 8 yearsConstruction in progress


1,605



954



-Total property, plant and equipment


15,497



23,606Less: Accumulated depreciation


(3,821
)


(3,595
)Property, plant and equipment, net

$
11,676


$
20,011




Included in property and equipment are assets under capital lease of $870 and $648 atDecember 31, 2010 and 2009, respectively, with related accumulated depreciation of $332 and $230 at December 31, 2010 and 2009, respectively.





Depreciation expense, excluded from “Cost of sales” in the accompanying statements of operations, was $329 and $343 for the years ended December 31, 2010 and 2009, respectively. Depreciation expense, included in “Cost of sales” in the accompanying statements of operations, was $2,327 and $1,616 for the years ended December 31, 2010 and 2009, respectively.Net property, plant and equipment totaling $8,405 was contributed to CFT by Flotation effective December 31, 2010 as discussed in Note 4 “Investment in Joint Venture.”





At December 31, 2010 and 2009, construction in progress represents assets that are not ready for service or are in the construction stage. We will begin depreciating these assets once they are placed in service. The 2009 balance included approximately $954 for equipment in progress that was placed in service in 2010.




F-19


Notes to Consolidated Financial Statements for the Years ended December 31, 2010 and 2009
 (Amounts in thousands except per share amounts)


On May 29, 2009, we consummated a purchase transaction with JUMA Properties, LLC (“JUMA”), a company owned by Ronald E. Smith, President, CEO and Director of Deep Down, and wife Mary L. Budrunas, Corporate Secretary and Director of Deep Down.  Pursuant to a Purchase and Sale Agreement dated May 22, 2009, we acquired certain property and improvements located in Channelview, Texas, where certain of our operations are currently located (the “Channelview Property”). The Channelview Property consists of 8.203 acres and was purchased for $2,600. The transaction was conducted on an arms-length basis, with the purchase price being determined primarily on the basis of an independent appraisal, and in accordance with normal terms and conditions. Prior to May 29, 2009, we leased the Channelview Property from JUMA at a base rate of $15 per month.  In connection with the purchase of the Channelview Property, the lease between us and JUMA was terminated.   We incurred no early termination penalties from JUMA in connection with this termination.




Note 6: Intangible Assets and Goodwill




Goodwill




Goodwill represents the excess of the cost over the net tangible and identifiable intangible assets of acquired businesses.




The change in the carrying value of goodwill during the years ended December 31, 2010 and 2009 is set forth below:




Carrying amount as of December 31, 2008

$
15,024Adjustments to previously reporting purchase price


(58
)Goodwill impairment


(5,537
)Carrying amount as of December 31, 2009

$
9,429Goodwill impairment


(4,513
)Carrying amount as of December 31, 2010

$
4,916




The decreases in 2010 and 2009, respectively, were primarily due to the non-cash impairment charge as discussed below, plus an adjustment to reduce the purchase price of Flotation by $58 as of December 31, 2009, net of legal fees, due to the resolution of a dispute concerning the working capital adjustment for the purchase price calculation.




Because quoted market prices for our individual reporting units are not available, management must apply judgment in determining the estimated fair value of our reporting units for purposes of performing the annual goodwill impairment test. Management uses all available information to make these fair value determinations, including the discounting of reporting units’ projected cash flow, publicly traded company multiples and recent merger and acquisition transaction values as a multiple of earnings.  A key component of these fair value determinations is an assessment of the fair value using discounted cash flows and other market-related valuation models in relation to our market capitalization.




The accounting principles regarding goodwill acknowledge that the observed market prices of individual trades of a company’s stock (and thus its computed market capitalization) may not be representative of the fair value of the entity as a whole. Substantial value may arise from the ability to take advantage of synergies and other benefits that flow from control over another entity. Consequently, measuring the fair value of a collection of assets and liabilities that operate together in a controlled entity is different from measuring the fair value of that entity’s individual common stock. In most industries, including Deep Down’s, an acquiring entity typically is willing to pay more for equity securities that give it a controlling interest than an investor would pay for a number of equity securities representing less than a controlling interest. Therefore, the above fair value calculations using discounted cash flows and other market-related valuation models are compared to market capitalization plus a control premium.




F-20




Notes to Consolidated Financial Statements for the Years ended December 31, 2010 and 2009


(Amounts in thousands except per share amounts)




At December 31, 2010 and 2009, our management completed the annual impairment test of goodwill. There was no impairment indicated at December 31, 2010. Management’s calculations indicated as of December 31, 2009, due to a number of factors, including the global economic environment, increased costs of capital and the decrease in our market capitalization, that the calculations for the reporting units of Deep Down Delaware, Mako and Flotation each indicated their respective net book value exceeded its fair value and, accordingly, we estimated the implied fair value of the goodwill for each reporting unit. We used the estimated fair value of each reporting unit from the first step as the purchase price in a hypothetical acquisition of the respective reporting unit. We recognized a goodwill impairment of $3,056 for Deep Down Delaware, $2,481 for Mako and $0 for Flotation reporting units for the year ended December 31, 2009. After adjusting the Flotation carrying value of intangible assets to fair value, there was no goodwill impairment for that reporting unit.  See detailed discussion of intangible asset below. The impairment was recorded in operating expenses in the consolidated statement of operations for the year ended December 31, 2009. This non-cash charge did not impact our liquidity position, debt covenants or cash flows.




We estimated the fair value of the reporting units using discounted cash flows and earnings multiples of comparable publicly traded companies. The key discounted cash flow assumptions used to determine the fair value of our reporting units included: a) cash flow periods of six years with a four percent estimated annual growth rate, b) terminal values based on the terminal cash flow growth rate and the capitalization rate (weighted average cost of capital – terminal growth rate) and c) a weighted average cost of capital of 20.8 percent. The remaining goodwill by reporting unit was $4,472, $2,874 and $2,083 for the Delaware, Mako and Flotation reporting units, respectively, as of December 31, 2009. As a result of the adjustments discussed above, approximately $7,346 of our goodwill was recorded at fair value as of December 31, 2009, based upon Level 3 inputs.





Additionally, we assessed the market conditions and concluded, as of September 30, 2010, that a triggering event had occurred that required an impairment analysis of goodwill for each reporting unit.  Management’s calculations indicated, due to a number of factors, including the global economic environment, increased costs of capital and the decrease in our market capitalization, that the calculations for the reporting units of Mako and Flotation each indicated their respective net book value exceeded its fair value and, accordingly, we estimated the implied fair value of the goodwill for each reporting unit. The calculation for Deep Down Delaware did not indicate any impairment of goodwill.  We used the estimated fair value of each reporting unit from the first step as the purchase price in a hypothetical acquisition of the respective reporting unit. We recognized a goodwill impairment of $2,430 for Mako and $2,083 for Flotation reporting units for the nine months ended September 30, 2010.  The impairment was recorded in operating expenses in the consolidated statement of operations for the year ended December 31, 2010. This non-cash charge did not impact our liquidity position, debt covenants or cash flows.





We estimated the fair value of the reporting units using discounted cash flows and earnings multiples of comparable publicly traded companies. The key discounted cash flow assumptions used to determine the fair value of our reporting units included: a) cash flow periods of six years with various annual revenue growth rates as estimated by management, b) terminal values based on the terminal cash flow growth rate and the capitalization rate (weighted average cost of capital – terminal growth rate) and c) a weighted average cost of capital of 26.2 percent and 27.9 percent for Flotation and Mako, respectively. The remaining goodwill by reporting unit was $4,472, $444 and $0 for the Delaware, Mako and Flotation reporting units, respectively, as of September 30, 2010.




Determining the fair value of a reporting unit is judgmental in nature and requires the use of significant estimates and assumptions, including revenue growth rates and operating margins, discount rates and future market conditions, among others. Unanticipated changes in revenue, gross margin, long-term growth factor or discount rate could result in a material impact on the estimated fair values of our reporting units which could result in additional goodwill impairment in future periods.




F-21


Notes to Consolidated Financial Statements for the Years ended December 31, 2010 and 2009
 (Amounts in thousands except per share amounts)


Intangible Assets




Identifiable intangible assets acquired in business combinations are recorded based upon fair market value at the date of acquisition.Amounts allocated to intangible assets are amortized on a straight-line basis over their estimated useful lives. Estimated intangible asset values, net of recognized amortization expense include the following:




December 31, 2010


December 31, 2009Estimated

Useful Life

Gross Carrying

Amount


Accumulated

Amortization


Net Carrying

Amount


Gross Carrying

Amount


Accumulated

Amortization


Net Carrying

AmountCustomer relationship
6 Years

$
2,845


$
(1,092
)

$
1,753


$
3,515


$
(786
)

$
2,729Non-compete covenant
5 Years


455



(415
)


40



1,334



(893
)


441Trademarks and other
17-25 Years


1,247



(132
)


1,115



3,286



(174
)


3,112Technology



-



-



-



11,209



(5,149
)


6,060Total


$
4,547


$
(1,639
)

$
2,908


$
19,344


$
(7,002
)

$
12,342


There was no triggering event or impairment to intangible assets at December 31, 2010. We previously assessed the market conditions and concluded, as of September 30, 2010, that a triggering event had occurred that required an impairment analysis of long-lived intangible assets. For the nine months ended September 30, 2010, the analysis determined that there was no impairment of long-lived assets as of September 30, 2010.  Fair values for technology and customer relationships were based upon an excess earnings methodology. Fair value for non-compete agreements was based on the expected differential cash flow of the reporting unit between “with non-compete agreements” and “without” non-compete agreements scenarios.





We assessed the current market conditions and concluded, as of December 31, 2009, that a triggering event had occurred that required an impairment analysis of long-lived intangible assets. Specifically, developments in technology shortened the estimated useful life (and related projected cash flows) of certain intangible assets. Fair values for technology and customer relationships were based upon an excess earnings methodology. Fair value for non-compete agreements was based on the expected differential cash flow of the reporting unit between “with non-compete agreements” and “without” non-compete agreements scenarios.





For the year ended December 31, 2009, we recorded impairment charges totaling $4,616 to the following long-lived intangible assets: $4,401 reduction in the carrying value of the technology intangibles primarily due to a change in the estimated useful life from twenty-five years to ten years based on recent technology developments in the buoyancy industry, which shorter life lessened the projected cash flows generated by this asset, and $215 reduction in the non-compete covenants. As a result, approximately $6,110 of long-lived intangible assets were recorded at fair value based upon Level 3 inputs at December 31, 2009. We recorded the adjustment as amortization expense on the statement of operations.  Additionally, we reduced the estimated useful lives of the following intangible assets based upon current market trends and estimated future cash flows: customer lists from a range of eight to twenty-five years to a range of six to fourteen years, and technology from twenty-five to ten years. The estimated amortization expense below reflects the adjusted carrying values and useful lives.





As of December 31, 2010, net intangible assets of Flotation totaling $8,035 were contributed to CFT as discussed in Note 4 “Investment in Joint Venture.”





Estimated amortization expense for each of the five subsequent fiscal years is expected to be:




Years ended December 31,:2011

$
4142012


4142013


4142014


4142015


404Thereafter


848$
2,908




F-22




Notes to Consolidated Financial Statements for the Years ended December 31, 2010 and 2009
 (Amounts in thousands except per share amounts)


Note 7: Long-Term Debt





At December 31, 2010 and 2009 long-term debt consisted of the following:




December 31, 2010


December 31, 2009Secured credit agreement - Whitney Bank

$
2,917


$
3,694Secured credit agreement - TD Bank


-



2,125Other bank loans


-



63Total bank debt


2,917



5,8826% Subordinated debenture


500



500Capital lease obligations


635



494Total debt


4,052



6,876Less: Current portion of long-term debt


(1,609
)


(1,497
)Long-term debt, net of current portion

$
2,443


$
5,379




Whitney Credit Agreement





We originally entered into a credit agreement with Whitney in November 2008.  The credit agreement originally provided a commitment to lend to us the lesser of $2,000 or 80 percent of eligible receivables.  All of this commitment was also available for Whitney to issue letters of credit (“L/C”) for our benefit.  In December 2008, we then entered into an amendment of the credit agreement that provided for us to receive a term loan in the principal amount of $1,150.  Then, in May 2009, we entered into another amendment to the credit agreement providing for us to receive another term loan in the principal amount of $2,100.  We used the proceeds from the December 2008 term loan to purchase a piece of equipment (a remotely operated vehicle) and we used the proceeds of the May 2009 term loan to purchase real property in Channelview, Texas.  There was $850 outstanding under the revolving credit line available on December 31, 2009.  We also used the credit agreement to have Whitney issue an irrevocable transferable standby L/C in the ordinary course of business, with an annual commission rate of 2.4 percent for $1,107 during the year ended December 31, 2009 (which such L/C related to a large contract we expect to have completed during 2011).  The Restated Credit Agreement does not obligate Whitney to issue new L/Cs. However on September 1, 2010, Whitney did renew the aforementioned L/C under the same terms for a period of one year to expire on August 31, 2011.  We paid the annual commission in advance, and the L/C will remain in effect until it expires.




On April 14, 2011, we entered into a Second Amendment to the Restated Credit Agreement with Whitney, pursuant to which Whitney extended the maturity dates of the respective term loans and the letter of credit facility under the Restated Credit Agreement to April 15, 2012.





Under the original credit agreement with Whitney, we were obligated to repay the December 2008 term loan on the basis of monthly installments of $35, with the initial payment on February 1, 2009 and a final payment on January 2, 2012.  Outstanding amounts of principal of the December 2008 term loan accrue interest at a rate of 6.5 percent per annum.  Under the terms of the Restated Credit Agreement, the monthly installment payments and interest rate of the December 2008 term loan remain the same. As of December 31, 2010, the outstanding principal amount of the December 2008 term loan was $443.





Under the original credit agreement with Whitney, we were obligated to repay the May 2009 term loan on the basis of monthly installments of $18, with the initial payment on June 1, 2009 and a final payment on May 1, 2024.  Outstanding amounts of principal of the May 2009 term loan accrue interest at a rate of 6.5 percent per annum.  Under the terms of the Restated Credit Agreement, the monthly installment payments and interest rate of the May 2009 term loan remain the same, and the final balloon payment of $1,834 is now due on April 15, 2012.  As of December 31, 2010, the outstanding principal amount of the May 2009 term loan was $1,944.





Upon execution of the Restated Credit Agreement in April 2010, our indebtedness in the amount of $850 outstanding under the revolving credit line of the credit agreement was converted to a term loan.  This term loan requires us to make monthly installments in the amount of $40 plus the amount of accrued and unpaid interest beginning on May 1, 2010 with a final payment due February 1, 2012.  Outstanding amounts of principal of the April 2010 term loan accrue interest at a rate of 6.5 percent per annum.  As of December 31, 2010, the outstanding principal amount of the April 2010 term loan was $530.




F-23


Notes to Consolidated Financial Statements for the Years ended December 31, 2010 and 2009
 (Amounts in thousands except per share amounts)


Whitney possesses a lien on all of our assets to secure the outstanding indebtedness under the Restated Credit Agreement.  Furthermore, each of our subsidiaries has guaranteed our obligations under the Restated Credit Agreement, and as such, our obligations in connection with the Restated Credit Agreement are generally secured by a first priority lien on all of our subsidiaries’ assets.  With regard to the Channelview Property purchased with the proceeds of the May 2009 term loan, we also entered into a Deed of Trust, Security Agreement and UCC Financing Statement for Fixture Filing, creating a lien on such property.





On December 31, 2010, we entered into a First Amendment to Amended and Restated Credit Agreement with Whitney, pursuant to which Whitney provided its consent concerning our contribution of Flotation’s assets to CFT and our issuance of shares to Holdings and using the proceeds thereof for a further cash contribution to CFT.  This amendment allowed the Company to complete the acquisition of Cuming Corporation and form the JV, which we contributed all of the assets, liabilities and bank debt of the Flotation subsidiary to the JV for our 20% ownership in the JV.  However, as a result of this transaction occurring on December 31, 2010, we are required to expense all acquisition costs and write down the value of the contributed assets in order to establish a fair value of our investment in the JV.  These expenses and write down caused us to be not in compliance with certain financial covenants under the Restated Credit Agreement.  On March 25, 2011 we obtained a waiver for these covenants as of December 31, 2010.





Under the Restated Credit Agreement, as amended and restated, beginning with the quarter ended June 30, 2010, and for each quarter thereafter, we have been obligated to comply with the following financial covenants: (i) total debt to consolidated earnings before interest, taxes, depreciation and amortization (“EBITDA”) of not greater than 3.0 to 1.0 (“Leverage Ratio”), consolidated EBITDA to consolidated net interest expense and principal payments on the total debt greater than 1.5 to 1.0 (“Fixed Charge Coverage Ratio”), and consolidated net worth after deducting other assets as are properly classified as “Intangible Assets”, plus 50 percent of net income, after provision for taxes (“Tangible Net Worth”) in excess of $15,000.  The calculation of EBITDA, with regards to the Leverage Ratio and Fixed Charge Coverage Ratio, allows us to deduct certain non-cash items, specifically asset impairment charges as of December 31, 2009 and going forward.  As of both September 30, 2010 and December 31, 2010, we were not in compliance with the Leverage Ratio and the Fixed Charge Coverage Ratio and, as noted above, such circumstance entitles Whitney at its option to accelerate and immediately require all amounts outstanding under the Restated Credit Agreement to become immediately due. Under the Restated Credit Agreement, we continue to have obligations for other covenants, including limitations on issuance of common stock, liens, transactions with affiliates, additional indebtedness and permitted investments, among others.





The Restated Credit Agreement removed a provision from the prior credit agreement with Whitney that permitted us to obtain additional indebtedness from a third party in the event Whitney declined to increase its commitment of indebtedness to us.  As such, we expect to have to refinance the indebtedness outstanding under the Restated Credit Agreement at any such time as we seek to obtain new financing from a third party.





TD Bank Loan Agreement





During fiscal 2009, Flotation, our wholly-owned subsidiary, obtained loan proceeds from TD Bank, N.A. in the principal amount of $2,160 (the “TD Bank Loan”).  Under the terms of the TD Bank Loan, we were obligated to make payments in monthly installments of $15, with an initial payment on March 13, 2009 and a final payment of the unpaid principal and accrued interest in February 2029.  The interest rate on the TD Bank Loan was 5.75 percent.





The TD Bank Loan was secured by Flotation’s operating premises in Biddeford, Maine under a mortgage and security agreement and a collateral assignment of leases and rents.  The TD Bank loan required us to enter into a debt subordination agreement that subordinated any debt Flotation owed to Deep Down, other than accounts payable between them arising in the ordinary course of business.  Additionally, the TD Bank Loan required a “negative pledge” that prohibited Flotation and Deep Down from granting security interests in Flotation’s personal property, other than such security interests granted in respect of our credit agreement with Whitney, as appropriate.




F-24


Notes to Consolidated Financial Statements for the Years ended December 31, 2010 and 2009
 (Amounts in thousands except per share amounts)


Under the TD Bank Loan, we were required to meet certain covenants and restrictions.  The financial covenants were reportable annually beginning with the year ended December 31, 2009, and were specific to the Flotation subsidiary financials.  At December 31, 2009, we were not in compliance with the financial covenants, and on April 15, 2010, we obtained a waiver for these covenants as of December 31, 2009.





In connection with Flotation’s contribution of all of its assets to CFT on December 31, 2010, CFT assumed the obligations of Flotation under the TD Bank Loan and we were released from the obligations under such loan.




Other Debt
 
 We have a subordinated debenture with a principal amount of $500 which originated from the exchange of preferred stock in a prior year. The debenture has a fixed interest rate of 6.0 percent per annum, which is required to be paid annually beginning March 31, 2009 through maturity on March 31, 2011, when the unpaid principal balance is due.




Note 8: Share-Based Compensation





We have a share-based compensation plan, the “2003 Directors, Officers and Consultants Stock Option, Stock Warrant and Stock Award Plan” (the “Plan”). Share based compensation is recognized as provided under the applicable authoritative guidance which requires all share-based payments to employees, including grants of employee stock options, to be recognized as compensation expense over the requisite service period (generally the vesting period) in the financial statements based on their fair values. The impact of forfeitures that may occur prior to vesting is also estimated and considered in the amount recognized. In addition, the realization of tax benefits in excess of amounts recognized for financial reporting purposes will be recognized as a financing activity. The options granted under the Plan have vesting periods that range from immediate vesting to vesting over five years, and the contract terms of the options granted are up to ten years. Under the Plan, the total number of options permitted is 15 percent of issued and outstanding common shares.





During the year ended December 31, 2010, we granted 2,250 options and 2,000 shares of restricted stock, and cancelled or forfeited 6,133 options under the Plan. Based on the shares of common stock outstanding at December 31, 2010, there were approximately 11,468 options available for grant under the Plan as of that date.





Restricted Stock





In May 2010, we granted 1,000 restricted shares, par value $0.001 per share for a total of $1, to an executive.  The shares were valued at $0.0875 per share and vest over three years in equal tranches on the grant date anniversary, with continued employment; we are amortizing the related share-based compensation of $87.5 over the three-year requisite service period. In January, 2011, this executive resigned from the Company, and all shares were forfeited.





In May 2010, we granted 1,000 restricted shares, par value $0.001 per share for a total of $1, to an outside director.  The shares were valued at $0.0875 per share and vest over three years in equal tranches on the grant date anniversary, with continued service on our Board of Directors; we are amortizing the related share-based compensation of $87.5 over the three-year requisite service period.





On March 23, 2009, we granted 2,350 restricted shares, par value $0.001 per share for a total of $2, to executives and employees which vest on March 23, 2011, with continued employment. The shares had a fair value grant price of $0.12 per share based on the closing price of common stock on March 20, 2009. The shares vest on the second anniversary of the grant date, and we are amortizing the related share-based compensation of $291 over the two-year requisite service period.





On September 1, 2009, we granted 750 restricted shares, par value $0.001 per share for a total of $1, to an executive in connection with his Severance and Separation Agreement. The shares had a fair value grant price of $0.10 per share based on the closing price of common stock on September 1, 2009. The shares vest on the anniversary of the grant date, and we are amortizing the related share-based compensation of $75 over the one-year requisite service period.





In connection with the departure of two executives during the third quarter of 2009, we accelerated the vesting of 850 shares of restricted stock granted on March 23, 2009, and 350 shares granted in February 2008, and recognized the related share-based compensation of $106.  During the year ended December 31, 2010 and 2009, we recognized a total of $182 and $464, respectively, in share-based compensation related to all outstanding shares of restricted stock. The unamortized portion of the estimated fair value of restricted stock was $179 at December 31, 2010.




F-25


Notes to Consolidated Financial Statements for the Years ended December 31, 2010 and 2009
 (Amounts in thousands except per share amounts)


The following table summarizes our restricted stock activity for the years ended December 31, 2009 and 2010. The aggregate intrinsic value is based upon the closing price of $0.08 of our common stock on December 31, 2010.




Restricted Shares


Weighted- Average Fair Value Grant Price


Aggregate

Intrinsic ValueOutstanding at December 31, 2008


1,200


$
0.42Vested


(1,200
)


0.21Granted


3,100



0.12Outstanding at December 31, 2009


3,100


$
0.20


$
37Vested


(1,600
)


0.27Granted


2,000



0.09Outstanding at December 31, 2010


3,500


$
0.23


$
-




Summary of Stock Options





During the years ended December 31, 2010 and 2009, we granted 2,250 and 14,475 options, respectively. Based on the shares of common stock outstanding at December 31, 2010, there were approximately 11,468 options available for grant under the Plan as of that date. We expense all stock options on a straight-line basis, net of forfeitures, over the requisite expected service periods. Additionally, during the year ended December 31, 2009, we revised the estimated rate of forfeitures to 30 percent from 0 percent based on the history of stock option cancellations and management’s estimates of expected future forfeiture rates, resulting in a reduction of share-based compensation expense of $116 for the year ended December 31, 2009. The total share-based compensation expense recognized for stock options for the years ended December 31, 2010 and 2009 was $545 and $372, respectively.  As of December 31, 2010, the unamortized portion of the estimated fair value of outstanding stock options was $689.





The following table summarizes our stock option activity for the years ended December 31, 2009 and 2010. The aggregate intrinsic value is based on the closing price of $0.08 on December 31, 2010.




Shares Underlying Options


Weighted- Average Exercise Price


Weighted- Average Remaining Contractual Term (in years)


Aggregate Intrinsic Value (In-The-Money)Outstanding at December 31, 2008


8,067


$
0.96



2.3


$
-Grants


14,475



0.11Cancellations & Forfeitures


(2,517
)


0.90Outstanding at December 31, 2009


20,025


$
0.35



2.5


$
323Grants


2,250



0.10Cancellations & Forfeitures


(6,133
)


0.83Outstanding at December 31, 2010


16,142


$
0.13



2.9


$
-Exerciseable at December 31, 2010


4,817


$
0.17



2.1


$
-




The following summarizes our outstanding options and their respective exercise prices at December 31, 2010:




Exercise Price


Shares

Underlying

Options$0.09 - 0.49



15,684$0.50 - 0.69



25$0.70 - 0.99



33$1.00 - 1.15



40016,142




F-26




Notes to Consolidated Financial Statements for the Years ended December 31, 2010 and 2009
 (Amounts in thousands except per share amounts)




The fair value of each stock option grant is estimated on the date of the grant using the Black-Scholes model and is based on the following key assumptions for the year ended December 31, 2010:




December 31, 2010Dividend yield
0%Risk free interest rate
2.08% - 2.49%Expected life of options
3.5 yearsExpected volatility
94.7% - 97.4%




Note 9: Warrants





We have issued warrants related to various transactions in previous years; a summary of warrant transactions follows. The aggregate intrinsic value is based on the closing price of $0.08 on December 31, 2010.




Shares Underlying Warrants


Weighted- Average Exercise Price


Weighted- Average Remaining Contractual Term (in years)


Aggregate Intrinsic Value (In-The-Money)Outstanding and exercisableat December 31, 2009


639


$
0.78



2.3


$
-Outstanding and exercisableat December 31, 2010


639


$
0.78



1.3


$
-




The following summarizes our outstanding warrants and their respective exercise prices at December 31, 2010 :




Exercise Price


Shares

Underlying

Warrants$ 0.70 - 0.99



520$ 1.01



119639


Note 10: Common Stock





Shares issued in connection with Securities Purchase Agreement





As discussed in Note 4 “Investment in Joint Venture”, on December 31, 2010, concurrent with our entry into the Contract Assignment and Amendment Agreement, we entered into the Securities Purchase Agreement, by and among the Company and Holdings, pursuant to which we sold and issued to Holdings 20,000 shares of our common stock for an aggregate purchase price of $1,400.We then contributed these proceeds to CFT in return for common units of CFT.  The Securities Purchase Agreement provides Holdings with registration rights for such 20,000 shares only in the event we fail to maintain current public filings.





Private Placement, Fiscal Year 2010





Between April 25 and April 30, 2010, we sold 5,150 shares of our common stock in a private placement to accredited investors at a per-share price of $0.10 resulting in total proceeds of $501, net of $14 applied to an outstanding vendor invoice for services provided, which we used for working capital purposes.




F-27


Notes to Consolidated Financial Statements for the Years ended December 31, 2010 and 2009
 (Amounts in thousands except per share amounts)


Note 11: Income Taxes





The provision for income taxes on income from continuing operations is comprised of the following for the years ended December 31, 2010 and 2009.  The provision for income taxes differs from the amount computed by applying the U.S. statutory income tax rate to income from continuing operations before income taxes for the reasons set forth below for the years ended December 31, 2010 and 2009.





December 31, 2010


December 31, 2009Federal:Current

$
-


$
603Deferred


-



(1,474
)Total Federal

$
-


$
(871
)State:Current

$
175


$
50Deferred


-



(205
)Total State

$
175


$
(155
)Total income tax benefit

$
175


$
(1,026
)
  Year endedDecember 31, 2010


December 31, 2009Income tax expense at federal statutory rate


34.00%



34.00%State taxes, net of federal expense


-0.41%



0.98%Goodwill impairment


-4.72%



-10.27%Valuation allowance


-32.32%



-15.44%State rate differential


2.10%



-Permanent differences


-0.28%



-2.50%Other, net


0.63%



-0.79%Total effective rate


-1.00%



5.98%





Income tax expense was $175 for the year ended December 31, 2010 compared to benefit of $1,026 for the year ended December 31, 2009.





Deferred income taxes reflect the net tax effects of temporary differences between the carrying amounts of assets and liabilities for financial reporting purposes and the amounts used for income tax purposes, as well as operating loss and tax credit carry forwards.  The tax effects of the temporary differences and carry forwards are as follow at December 31, 2010 and 2009:




December 31, 2010


December 31, 2009Deferred tax assets:Allowance for bad debt

$
85


$
106Net operating loss


4,091



4,034Stock based compensation


121



546Section 263 (A) adjustment


-



52Investment in joint venture


7,200



-Intangible amortization


-



314Other


15



48Total deferred tax assets

$
11,512


$
5,100Deferred tax liabilities:Depreciation on property and equipment

$
(1,649
)

$
(1,874
)Intangible amortization


(984
)


-Total deferred tax liabilities

$
(2,633
)

$
(1,874
)Less: valuation allowance


(8,879
)


(3,226
)Net deferred tax liabilities

$
-


$
-




We have $11,390 in net operating loss (“NOL”) carry forwards available to offset future or prior taxable income.  These federal NOL’s will expire in 2028. We have no uncertain tax positions at December 31, 2010.


A valuation allowance is established when it is more likely than not that some of the deferred tax assets will not be realized.  Management analyzed its current operating results and future projections and determined that a full valuation allowance was needed due to our cumulative losses in recent years.





F-28




Notes to Consolidated Financial Statements for the Years ended December 31, 2010 and 2009
 (Amounts in thousands except per share amounts)


Note 12: Related Party Transactions





Ronald E. Smith, President, CEO and Director of Deep Down and Eugene Butler, Executive Chairman, CFO and Director of Deep Down, were investors in Ship and Sail, Inc. (“Ship and Sail”), a former vendor of Deep Down. During the year ended December 31, 2010, we made payments of $10 to Ship and Sail, and we expensed the prepaid balance of $38 as of December 31, 2009 during the first quarter of 2010. The payments and expense to Ship and Sail related to services provided by that entity for the support of the development of marine technology which is currently being marketed. Ship and Sail discontinued operations in mid-2010, thus there is no longer a related party relationship. As disclosed in the 2009 Form 10-K, we made a deposit for a boat in the amount of $100, which was written off in connection with the discontinued operations of Ship and Sail.





In January 2010, we loaned South Texas Yacht Services, a vendor of Deep Down, $100.  The owner of South Texas Yacht Services was in a business alliance with Ship and Sail. The note receivable, included in other assets on the consolidated balance sheet, bears interest at a rate of 5.5 percent per annum and monthly principal and interest payments in the amount of $2 commenced in April 2010. The final principal and interest payment is due March 24, 2015. As of March 31, 2011, the payments on this note were current. Additionally, as of September 30, 2010, South Texas Yacht Services is no longer a related party as they are no longer in a business alliance with Ship and Sail.





Additionally, during the year ended December 31, 2010, we recorded expenses to JUMA, a company owned by Ronald E. Smith, and his wife Mary L. Budrunas, Corporate Secretary and Director of Deep Down, in the amount of $35; there is no balance due as of December 31, 2010.  Payments related to the monthly rental of a boat owned by JUMA, in connection with the development of marine technology as discussed above. The board of directors approved the arrangement between JUMA and Deep Down with a termination date of December 31, 2010.




F-29


Notes to Consolidated Financial Statements for the Years ended December 31, 2010 and 2009
 (Amounts in thousands except per share amounts)


Note 13: Commitments and Contingencies





Litigation





We are from time to time involved in legal proceedings arising from the normal course of business. As of the date of this Report, we are not currently involved in any material legal proceedings.





Leases





We lease certain offices, facilities, equipment and vehicles under non-cancellable operating and capital leases expiring at various dates through 2016.





At December 31, 2010, future minimum contractual obligations were as follows:




Years ended December 31,:

Capital Leases


Operating Leases2011

$
195


$
2952012


180



2312013


172



1942014


82



1502015


58



150Thereafter


-



25Total minimum lease payments

$
687


$
1,045Residual principal balance


105Amount representing interest


(158
)Present value of minimum lease payments

$
634Less current maturities of capital lease obligations


129Long-term contractal obligations

$
505




Rent expense totaled $596 and $711 for the years ended December 31, 2010 and 2009, respectively.





Letters of Credit





Certain customers could require us to issue a standby letter of credit in the normal course of business to ensure performance under terms of the contract and with associated vendors and subcontractors. In the event of default, the creditor could demand payment from the issuing bank for the amount of the L/C. Our Restated Credit Agreement with Whitney provides for L/Cs, as discussed in Note 7, “Long-Term Debt”. During the year ended December 31, 2009, we issued a $1,107 irrevocable transferrable standby L/C in the normal course of business, with an annual commission rate of 2.4 percent. This L/C was renewed on September 1, 2010 for one year under the same terms and remains outstanding under the Restated Credit Agreement as of December 31, 2010.