UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-K

(Mark One)

x
x
Annual Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

For the fiscal year ended December 31, 2014

2016

or

¨Transition Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

For the transition period from             to             

Commission File Number 001-34279

GULF ISLAND FABRICATION, INC.

(Exact name of registrant as specified in its charter)

Louisiana 72-1147390

(State or other jurisdiction

of incorporation or organization)

 

(I.R.S. Employer

Identification Number)

16225 Park Ten Place,

Suite 280

Houston, Texas

 77084
(Address of principal executive offices) (Zip code)

(713) 714-6100

(Registrant’s telephone number, including area code)

Securities registered pursuant to Section 12(b) of the Act:

Title of each class

 

Name of each exchange on which registered

Common Stock, no par value 

The Nasdaq Stock Market LLC

(Nasdaq Global Select Market)

Securities registered pursuant to Section 12(g) of the Act:

None

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

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

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.    Yes   x    No  ¨

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

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

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

Large accelerated filer  ¨
 
Accelerated filer  x
Non-accelerated filer  ¨    (Do not  check if a smaller reporting company)
 
Smaller reporting company  ¨

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

The aggregate market value of the voting and non-voting common equity held by non-affiliates of the registrant at June 30, 20142016 was approximately $290,522,819.

$99,152,000.

The number of shares of the registrant’s common stock, no par value per share, outstanding as of March 5, 20152, 2017 was 14,738,900.

14,850,154.

DOCUMENTS INCORPORATED BY REFERENCE

Portions of the registrant’s definitive Proxy Statement prepared for use in connection with the registrant’s 20152017 Annual Meeting of Shareholders to be held April 23, 2015 have been incorporated by reference into Part III of this Form 10-K.



GULF ISLAND FABRICATION, INC.

ANNUAL REPORT ON FORM 10-K FOR

THE FISCAL YEAR ENDED DECEMBER 31, 2014

2016

TABLE OF CONTENTS

 Page

PART I

2

Items 1 and 2. Business and Properties

2

Item 1A. Risk Factors

14
10

Item 1B. Unresolved Staff Comments

19
18

Item 3. Legal Proceedings

20
18

Item 4. Mine Safety Disclosures

20
18

Item 4A. Executive Officers of the Registrant

18
 20 

PART II

21
19

Item 5. Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities

21
19

Item 6. Selected Financial Data

23
21

Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations

25
23

Item 7A. Quantitative and Qualitative Disclosures About Market Risk

33
38

Item 8. Financial Statements and Supplementary Data

34
38

Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure

34
38

Item 9A. Controls and Procedures

34
38

Item 9B. Other Information

41
 36 

PART III

36
42

Item 10. Directors, Executive Officers and Corporate Governance

36
42

Item 11. Executive Compensation

36
42

Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters

36
42

Item 13. Certain Relationships and Related Transactions, and Director Independence

37
42

Item 14. Principal Accounting Fees and Services

43
 37 

PART IV

38
44

Item 15. Exhibits, Financial Statement Schedules

38
44

GLOSSARY OF CERTAIN TECHNICAL TERMS

G-1

FINANCIAL STATEMENTS

F-1

SIGNATURES

S-1

EXHIBIT INDEX

E-1


i




Forward-Looking Information

Certain statements included in this report and in oral statements made from time to time by management of the Company that are not statements of historical fact are forward-looking statements. In this report, forward-looking statements are included primarily in the sections entitled “Business and Properties,” “Legal Proceedings,” and “Management’s Discussion and Analysis of Financial Condition and Results of Operations.” The words “expect,” “believe,” “anticipate,” “project,” “plan,” “estimate,” “predict” and similar expressions often identify forward-looking statements. All such statements are subject to certain risks and uncertainties that could cause actual results and outcomes to differ materially from the results and outcomes predicted in the statements and investors are cautioned not to place undue reliance upon them. Important factors that may cause our actual results to differ materially from expectations or projections include those described in the section titled “Risk Factors.” Forward-looking statements speak only as to the date of this report, and we undertake no obligation to update or revise such statements to reflect new circumstances or unanticipated events or circumstances.



PART I

Items 1 and 2. Business and Properties


Certain technical terms are defined in the “Glossary of Certain Technical Terms” beginning on page G-1.


General

We are


Gulf Island Fabrication, Inc. ("Gulf Island"), and together with its subsidiaries ("the Company," "we" or "our"), is a leading fabricator of complex steel platformsstructures and othermarine vessels used in energy extraction and production, petrochemical and industrial facilities, power generation and alternative energy projects and shipping and marine transportation operations. We also provide related installation, hookup, commissioning, repair and maintenance services with specialized structures primarilycrews and integrated project management capabilities. We are currently fabricating complex modules for customersthe construction of a new petrochemical plant, completing newbuild construction of two technologically advanced offshore support and two multi-purpose service vessels and recently fabricated wind turbine pedestals for the first offshore wind power project in the offshore oil and gas and marine industries. The company was incorporated in 1985, and began operations at our fabrication yard onUnited States. We also constructed one of the Houma Navigation Canal in southern Louisiana, approximately 30 miles fromlargest liftboats servicing the Gulf of Mexico. Effective January 31, 2006, we acquiredMexico ("GOM"), one of the facilities, machinerydeepest production jackets in the GOM and equipment of Gulf Marine Fabricators, L.P. (“Gulf Marine”) located on 372 acresthe first SPAR fabricated in San Patricio County, Texas. In October 2013, we moved ourthe United States. Our customers include U.S. and, to a lesser extent, international energy producers, petrochemical, industrial, power and marine operators. Our corporate headquarters tois located in Houston, Texas.

Gulf Island Fabrication, Inc. (“Gulf Island”) serves as a holding companyTexas, with fabrication facilities located in Houma, Jennings and conducts all of its operations through its subsidiaries, which include Gulf Island, L.L.C.Lake Charles, Louisiana, and Gulf Marine (both of which perform fabrication of offshore drillingAransas Pass and production platforms and other specialized structures used in the development and production of oil and gas reserves), Gulf Island Marine Fabricators, L.L.C. (which performs marine fabrication and construction services), Dolphin Services, L.L.C. (which performs offshore and onshore fabrication and construction services), Dolphin Steel Sales, L.L.C. (which sells steel plate and other steel products) and Gulf Island Resources, L.L.C. (which hires laborers with similar rates and terms as those provided by contract labor service companies).

Web siteIngleside, Texas.


Website and Electronic Posting Disclosures


Our web sitewebsite address is www.gulfisland.com. We make available on or through our web site,website, without charge, as soon as reasonably practicable after such materialmaterials are electronically filed with or furnished to the Securities and Exchange Commission (“SEC”), our annual reports on Form 10-K, quarterly reports onForm 10-Q, current reports on Form 8-K and amendments to those reports. The SEC also maintains an Internet site that contains reports, proxy and information statements, and other information regarding issuers that file electronically with the SEC. The SEC’s web sitewebsite address is www.sec.gov. Our web sitewebsite and the information contained therein or connected thereto are not intended to be incorporated into this annual report on Form 10-K.


LEEVAC Transaction

On January 1, 2016, we acquired substantially all of the assets and assumed certain specified liabilities of LEEVAC Shipyards, L.L.C. and its affiliates (“LEEVAC”). The purchase price for the acquisition was $20.0 million, subject to a working capital adjustment whereby we received a dollar-for-dollar reduction for the assumption of certain net liabilities of LEEVAC and settlement payments applied from sureties on certain ongoing fabrication projects that were assigned to us in the transaction. After taking into account these adjustments, we received approximately $1.6 million in cash at closing. During the fourth quarter, we finalized our working capital true-up with the seller and received $1.4 million in cash for additional working capital. Strategically, the LEEVAC transaction expands our marine fabrication and repair and maintenance presence in the Gulf South market. We acquired approximately $121.2 million of newbuild construction backlog inclusive of approximately $9.2 million of purchase price fair value allocated to four newbuild construction projects to be delivered in 2017 and 2018 for two customers. Additionally, we hired 380 employees representing substantially all of the former LEEVAC employees.

Description of Operations

Our primary activity isOperations


In connection with the fabricationLEEVAC transaction described above, we restructured the operation of our business units into three divisions which we believe meet the criteria of reportable segments under generally accepted accounting principles in the United States (GAAP). These divisions consist of Fabrication, Shipyards and Services.

Fabrication Division

Our Fabrication division primarily fabricates structures such as offshore drilling and production platforms and other steel structures for customers in the oil and gas and marine industries,industry including jackets and deck sections of fixed production platforms, hull, tendon, and/or deck sections of floating production platforms (such as TLPs, SPARs, FPSOs and MinDOCs), piles, wellhead protectors, subsea templates, and various production, compressor, and utility modules. We also produce and repairmodules along with pressure vessels used in the oil and gas industry, refurbish existing platforms, fabricate various other types of steel structures, including processing modules used in petro-chemical plants, fabricate living quarters for installation on such platforms ranging in size from 4 to 250 beds, provide onshore and offshore scaffolding and piping insulation services, perform heavy lifts such as ship integration and TLP module integration and load and offload jack-up drilling rigs, semi-submersible drilling rigs, TLPs, SPARs or other similar cargo. In addition, we fabricate towboats, barges, lift boats, dry docks, offshore support vessels, other marine vessels, and mid-body sections for offshore supply vessels. Our Houma dry dock hasFabrication division also fabricates structures for alternative energy customers (such as the capacity to lift 9,000 tonsfive jackets and is used to maintain and repair third party marine vessels, as well as to launch vessels fabricated at our facilities. We perform all projects at our Houma and Texas facilities based on availability of space and equipment. We currently provide our customers with whatpiles we believe to be the largest group of fabrication facilities serving the Gulf of Mexico market.

We use modern welding and fabrication technology, and all of our projects are manufactured in accordance with industry standards, specifications and regulations, including those published by the American Petroleum Institute, the American Welding Society, the American Society of Mechanical Engineers, the American Bureau of Shipping and the United States Coast Guard. The quality management systems of our operating subsidiaries are certified as ISO 9001-2008 quality assurance programs. For additional information, see “Safety and Quality Assurance” below.

We fabricate the structural components of fixed platforms. A fixed platform is the traditional type of platform usedconstructed for the first offshore development and production of oil and gas reserves, although recently there has been an increase in the use of floating production platforms as a result of increased drilling and production activities in deeper waters. Most fixed platforms built today can accommodate both drilling and production operations. These combination platforms are large and generally more costly than single-purpose structures.

The most common type of fixed platform consists of a jacket (a tubular steel, braced structure extending from the mud line on the seabed to a point above the water surface) which supports the deck structure located above the level of storm waves and is secured with tubular pilings driven deep into the seabed. The deck structure is designed to accommodate multiple functions, including drilling, production, separating, gathering, piping, compression, well support, and crew quartering. Platforms can be joined by bridges to form complexes of platforms for very large developments or to improve safety by dividing functions among specialized platforms. Jacket-type platforms are generally the most viable solution for water depths of 1,000 feet or less. Although there is no height limit to the jackets that can be fabricated at our Houma facilities, the dimensions of the Houma Navigation Canal prevent the transportation to the Gulf of Mexico of most jackets and hulls designed for water depths exceeding 800 feet. Our south yard in Texas, which is located on the Gulf Intercoastal Waterway and the 45-foot-deep Corpus Christi Ship Channel, provides direct and unrestricted access to the Gulf of Mexico, which allows for fabrication or assembly of any size jacket or other structure currently in use for the development and production of oil and gas in the Gulf of Mexico for deepwater drilling. In some instances, we may fabricate jackets, deck sections, living quarters and/or piles for a platform at our Houma facility, with the hulls and/or jackets for the platform designed for water depths in excess of 800 feet fabricated at our Texas facility.

Most of the steel used in our operations arrives at our fabrication yards as steel plate. The plate is cut and rolled into tubular sections at rolling mills in our fabrication yards. The tubular sections (which vary in diameter up to 23 feet) are welded together in long straight tubes to become legs or into shorter tubes to become part of the network of bracing that support the legs. Various cuts and welds in the fabrication process are made by computer-controlled equipment that operates from data developed during the design of the structure. Our ability to fabricate and assemble large tubular sections needed for jackets built for use in water depths over 300 feet distinguish us from all but one of our domestic competitors.

Jackets are built on skidways (which are long parallel rails along which the jacket will slide when it is transferred to a barge for towing out to sea) and are generally built in sections. As each section of legs and bracing is complete, large crawler cranes pick up an entire side and “roll up” the section, joining it to another uprighted section. When a jacket is complete, it is pulled along the skidway onto a launch barge. Using ocean-going tugs, the barge is transported to the offshore installation site.

Decks are built either as single structures or in sections and are installed on location on fixed and floating platforms by construction contractors. The composition and quantity of petroleum in the well stream generally determine the makeup of the production deck on a processing platform. Typical deck equipment includes crude oil pumps, oil and gas separators and gas compressors. Unlike large jackets, which are transported in a horizontal position, decks are transported upright and, as a result, are not subject to the width restrictions of the Houma Navigation Canal.

TLPs consist of a deck that sits atop one or more column-shaped hulls, which are positioned on site with vertical tendons running from the hulls to the seabed. The tendons hold the hulls partially submerged and are

highly tensioned using the buoyancy of the hulls. This system develops a restoring force against wave, wind and current actions in proportion to the lateral displacement of the vessel. Wells for a TLP are often pre-drilled through a subsea template. Long, flexible production risers, which carry the petroleum to the deck of the TLP, are supported in tension by mechanical tensioner machines on the platform’s deck and are directly subject to wave, wind and current forces. TLPs can be used in any water depth and are generally better suited than fixed platforms for water depths greater than 1,000 feet.

The size of a TLP depends on a number of factors, including the intended scope of production of the platform, the length of the production risers connected to the platform, the size of the deck to be installed on the platform and the water depth for which the platform is designed. We fabricate deck sections and hulls for use with TLPs of any size. TLPs, MinDOCs, SPARS, and other floating concepts are the alternatives of choice for deepwater drilling and production platforms. In November 2009, we completed fabrication and delivered a MinDOC hull, the first deepwater dry tree drilling and production platform built in the United States. We completed the fabrication of the first SPAR to be builtpower project in the United States and delivered it in the first quarter of 2014.

We fabricate subsea templates used in connection with TLPs. Subsea templates are structures installed on the seabed before development drilling begins. As exploration and drilling move into the deepwater of the Gulf of Mexico, we believe that there will be increased opportunities to fabricate subsea templates,during 2015) as well as decks and other structures,modules for use in connection with TLPs.

In addition, we fabricate piles and other rolled goods, bridges for connecting offshore platforms, wellhead protectors, various production, compressor and utility modules and other structures used in offshore oil and gas production and development activities. Allpetrochemical facilities. We perform these activities out of our products are installed by construction contractors.

We provide interconnect piping services on offshore platformsfabrication yards in Houma, Louisiana, and inshore steel structures. Interconnect piping services involve sending employee crews to offshore platforms in the Gulf of Mexico to perform weldingAransas Pass and other activities required to connect production equipment, service modulesIngleside, Texas.




Shipyards Division

Our Shipyards division primarily manufactures newbuild and other equipment to a platform prior to its becoming operational. We also contract with oil and gas companies that have platforms and other structures located in the inland lakes and bays throughout the southeast for various on-site construction and maintenance activities. In addition, we fabricate pressure vessels and large and small packaged skid units and provide various municipal and drainage projects, such as pump stations, levee reinforcement, bulkheads and other levee and drainage projects, to state and local governments.

We manufacture and repairrepairs various steel marine vessels in the United States including offshore supply vessels;vessels, anchor handling vessels;vessels and lift boatsliftboats to support the construction and ongoing operation of offshore oil and gas production platforms;platforms, tug boats, and towboats, for towing and pushing barges that support transportation of various types of products and materials; mooring and positioning, dredging assistance, tanker escort, port management, shipping, piloting, coastal flood protection barge gates, inland and offshore barges and fire-fighting and salvageother marine vessels. We also construct dry docks to lift marine vessels out of the water. Our marine repair activities include steel repair, blasting and painting services, electrical systems repair, machinery and piping system repairs, and propeller, shaft, and rudder reconditioning. In addition, we perform conversion projects that consist of lengthening vessels, modifying vessels to permit their use for a different type of activity, and other modifications to enhance the capacity or functionality of a vessel. In the first quarter 2012, we deliveredOur Houma dry dock has a 335-Classcurrent lift boatcapacity of 9,000 tons and is used to Montco Offshore, Inc.,maintain and repair third party marine vessels, as well as to launch vessels fabricated at our facilities. We are in the fourth quarter, 2014, we completedprocess of enhancing our Houma dry dock to increase this capacity to 15,000 tons. We perform these activities out of our shipyards in Houma, Jennings and deliveredLake Charles, Louisiana.


Services Division

Our Services division primarily provides interconnect piping services on offshore platforms and inshore structures along with onshore and offshore scaffolding and piping insulation services. Interconnect piping services involve sending employee crews to the customer a second 335-Class lift boat. These two vessels are the largest lift boats to be usedoffshore platforms in the Gulf of Mexico.

Mexico to perform welding and other activities required to connect production equipment, service modules and other equipment on a platform. We also contract with oil and gas companies that have platforms and other structures located in the inland lakes and bays throughout the southeastern United States for various on-site construction and maintenance activities. In addition, our Services division fabricates packaged skid units and provides various municipal and drainage projects, such as pump stations, levee reinforcement, bulkheads and other public works projects for state and local governments. We perform these activities at the customer's location or in our yard in Houma, Louisiana.


Facilities and Equipment

Facilities

We perform all projects at our Louisiana Operationsand Texas facilities based on availability of space and equipment. Although our division operations are generally segregated, we move labor and resources among our divisions from time to time to maximize our consolidated profitability.
Fabrication Division
Houma Fabrication Yard

-In Louisiana, our main fabrication yard is located on the east bank of the Houma Navigation Canal in Houma, Louisiana, approximately 30 miles from the Gulf of Mexico. This facility is situatedOur Houma Fabrication Yard includes:

163 acres located on approximately 140 acres,the east bank of the Houma Navigation Canal, of which 100 acres are developed for fabrication, and includesincluding several buildings totaling 49,00054,000 square feet of administrative offices, 267,000 square feet of covered fabrication area, over 47,00052,300 square feet of warehouse storage area and 8,000 square feet of training and medical facilities. The main yardIt also has approximately 2,8004,650 linear feet of water frontage, which includes 1,5001,880 feet of steel bulkheads that permit docking of vessels and the load out of heavy structures.

Ourstructures; and

437 acres, located on the west yard is located acrossbank of the Houma Navigation Canal from the main yard on 437 acres, 130Canal,130 acres of which are developed for fabrication and over 300 acres of which are unimproved land that could be used for expansion. The west yard spansIt includes 6,750 linear feet of the Houma Navigation Canal,water frontage, including 2,350 feet of steel bulkhead, and has approximately 151,600 square feet of covered fabrication area, 21,000 square feet of warehouse storage area, and two buildings providing an additional 8,000 square feet for administrative offices.

Our

Some of our significant Houma north yard operates onFabrication Yard equipment that we own and operate includes:
three plate bending rolls that have the east bankcapability to roll and weld steel into approximately 50,000 tons of tubular pipe sections per year;
computerized Vernon brace coping machines that can handle pipe up to 1,500 pounds per foot and 54-inch outer diameter, and 1,000 pounds per foot and 48-inch outer diameter;
a computerized numeric controlled plasma-arc cutting system that cuts and bevels steel up to one inch thick at a rate of 200 inches per minute and can also etch into steel for piece markings and layout markings at a rate of 300 inches per minute;
a state of the art, fully enclosed, and environmentally friendly blast and coating facility that allows us to provide blast and paint services to the shipbuilding industry in the GOM;


12 crawler cranes, which range in tonnage capacity from 230 to 500 tons each;
12 rubber-tired, hydraulic modular transporters (KAMAG – Type 2406) that allow fabricated deck sections that weigh as much as 2,400 tons to be transported around our facilities. The transporters allow easier load-out of smaller decks and provide more agility for the movement of deck sections. Each of these transporters have a 200-ton weight capacity, are easily relocated, and can be used in tandem; and
two grit blast systems, a hydraulic plate shear, a hydraulic press brake, and various other equipment needed to build offshore structures and fabricate steel components.
Our Fabrication Facilities in Ingleside and Aransas Pass, Texas:

On February 23, 2017, our Board of Directors approved a recommendation of management to consolidate all of our fabrication operations in south Texas with our fabrication operations in Houma, Navigation Canal adjacentLouisiana, and place our properties located in Aransas Pass and Ingleside, Texas (collectively, our South Texas properties), up for sale. These properties are currently underutilized and represent excess capacity within our Fabrication division. We are working to wind down all fabrication activities at these locations and re-allocate remaining backlog and workforce to our Houma main fabrication yard. The facility covers 23 acresFabrication operations as necessary. We do not expect the sale of these properties to impact our ability to service our deepwater customers or operate our Fabrication division. For additional information, see also "Potential Sale of Our South Texas Properties" in Item 7. Management's Discussion and includes a two-story, 5,000 square foot administration building with an attached 5,300 square foot warehouse. The property has approximately 1,850 linear feetAnalysis and our Risk Factors listed in Item 1A of water frontage, including a 380 linear foot steel bulkhead that permits dockingthis Report. A description of vesselsour Texas South Yard in Ingleside, Texas and the load out of structures.

Located approximately a quarter of a mile from Gulf Island’s main yard on a channel adjacent to the Houma Navigation Canal, we operate a 63-acre facility that includes buildings totaling 14,500 square feet of administrative offices, 40,800 square feet of covered fabrication area, 29,600 square feet of warehouse storage area, a 10,000 square foot blasting and coating facility and approximately 1,320 linear feet of water frontage, including 660 feet of steel bulkhead.

Gulf Island owns a 9,000 ton dry dock, supplementing our marine construction operationsTexas North Yard in Houma. The dry dock is 240 feet long by 160 feet wide and 140 feet wide between the wing walls. The bottom is 10 feet deep with 30 foot walls. The dry dock is used for maintenance and repairs to third party marine vessels, as well as launch vessels being fabricated at our Houma facility.

Aransas Pass, Texas Operationsfollows.


Texas South Yard - Our south yardTexas South Yard in Ingleside, Texas, is located on the northwest corner of the intersection between the GulfU.S. Intracoastal Waterway and the Corpus Christi Ship Channel. The 45-foot deep Corpus Christi Ship Channel provides direct and unrestricted access to the Gulf of Mexico, which allows for fabrication or assembly of any size jacket or other structure currently in use for the development and production of oil and gas in the Gulf of Mexico. This facility is situated on approximately 212 acres developed for fabrication and assembly, and includes a fabrication shop with 5,000 square feet of covered fabrication area, 10,000 square feet of warehouse storage area and 2,700 square feet of training facilities. The yard includes approximately 2,650 linear feet of water frontage, all of which is reinforced by steel bulkhead. In addition, there is a dredge area 86 feet deepthat is permitted to an 86-foot depth within 500 feet of the bulkhead and is used in conjunction with heavy lift vessels. This area measures 800 feet by 200 feet at the base and can accommodate the largest existing semi-submersible transport vessels.


In addition, the south yardTexas South Yard contains a graving dock which measures 700 feet long by 250 feet wide and 40 feet deep. The graving dock has a reinforced concrete slab floor, sheet-pile walls and pile supported relieving platforms around the perimeter to take the surcharge load applied by cranes. The south end of the graving dock, which opens to the Corpus Christi Ship Channel, can use either a removable sheet piled wall supported by steel

struts or a portable gate that can be removed and attached to seal the dock from the water in the channel, depending upon the nature of the project. The graving dock gate is a steel barge-like structure consisting of a steel reinforced wall and a buoyancy tank. The floating structure is 240 feet long x 35 feet wide x 40 feet deep and weighs approximately 950 tons. The gate structure has rubber seals that engage the walls and the graving dock floor. Although the de-ballastingdeep.


Some of the dock requires pumps,significant fabrication equipment that we own and operate at the gate is equipped with pipingTexas South Yard includes:

a panel line system. We expect to allow the gaterelocate this equipment to our other facilities;
10 crawler cranes, which range in tonnage capacity from 230 to 1055 tons. Certain of these cranes are expected to be flooded withoutsold with the useSouth Texas properties discussed above. Others will be relocated to our other facilities; and
six rubber-tired, hydraulic modular transporters (KMAG – Type 2406), located at our Texas South Yard that allow fabricated deck sections that weigh as much as 1,200 tons to be transported throughout the facility. These transporters allow easier load-out of pumps. When flooded,small decks and provide more agility for the graving dock hasmovement of deck sections than cranes. All of our transporters can easily be relocated to or from our Louisiana and Texas facilities and, when used in tandem, have a minimumcapacity of 30 feet of water over the concrete floor.

3,600 tons. We do not expect to sell this equipment.

Texas North Yard - Our Texas north yardNorth Yard in Aransas Pass, Texas, is located along the U.S. Intracoastal Waterway and is approximately three miles north of the Corpus Christi Ship Channel. This facility is situated on approximately 160 acres, of which 85 acres are dedicated to fabrication activities and 55 acres are used for the storage of steel, prefabricated elements, equipment, and spare parts. Several buildings are located on our Texas north yard with 328,000 square feet of covered fabrication area, 22,000 square feet of administrative office space, 61,750 square feet of warehouse storage area, 20,000 square feet of climate controlled staging area, a paint booth 16 feet by 14 feet by 125 feet and 16,000 square feet of training and medical facilities. The yard also


has approximately 3,000 linear feet of water frontage, including approximately 1,000 feet of steel bulkhead.

We own all Some of the foregoing properties.

Equipment. Gulf Island’s Houma main yard houses its Bertsch Model 34significant fabrication equipment that we own and Model 20 plate bending rolls, operate at the Texas North Yard includes:


a computerized Vernon brace coping machine usedpipe mill equipped with a quad roll for cutting steel in complex geometric sections, two grit blast systems, a hydraulic plate shear, a hydraulic press brake,diameters ranging from one foot six inches to ten feet, and various other equipment needed to build offshore structures and fabricate steel components. Our Houma west yard has a Bertsch Model 38one large diameter plate bending roll machine;
a computerized Vernon brace coping machine,quad roll, for diameters ranging from three feet to 23 feet; and various other equipment
two Romar CNC-controlled flame planers which are used in our fabrication business. The brace coping machines can handle pipeto cut steel plate up to 1,500 pounds per foot12 feet wide and 54-inch outer diameter,65 feet long.

Shipyards Division Facilities
Owned Facilities and 1,000 pounds per foot and 48-inch outer diameter, respectively. The brace coping machine inEquipment:
Houma Shipyard - Our Houma Shipyard shares space with our Houma Fabrication Yard located on the west bank of the Houma west yard provides additional efficiencies as it can cut 360 degrees without repositioning itself. Gulf IslandNavigation Canal which is described above. Our Houma dry dock has a computerized numeric controlled plasma-arc cutting system that cutscurrent lift capacity of 9,000 tons and bevels steel upis used to one inch thick at a rate of two hundred inches per minute. The system can also etch into steel for piece markingsmaintain and layout markings at a rate of 300 inches per minute. We own 15 crawler cranes, located in our Louisiana facilities, which range in tonnage capacity from 230repair third party marine vessels, as well as to 500 tons each. We may rent additional cranes on a monthly basis in times of very high activity levels. We have 12 rubber-tired, hydraulic modular transporters (KAMAG – Type 2406) locatedlaunch vessels fabricated at our Houma Louisiana facilities that allow fabricated deck sections that weigh as much as 2,400Shipyard. The dry dock is 240 feet long by 160 feet wide and 140 feet wide between the wing walls. The bottom is ten feet deep with 30 foot walls. We are in the process of enhancing our Houma dry dock to increase this capacity to 15,000 tons to be transported around our facilities. The transporters allow easier load-out of smaller decks and provide more agility for the movement of deck sections. Each of these transporters have a 200 ton weight capacity, are easily relocated, and can be used in tandem. 320 feet.
We own a deck barge which gives us the ability to move material and equipment to and from our facilities more conveniently and efficiently. We perform routine repairs and maintenance on all of this equipment.

Gulf Island’s plate bending rolls allow it to roll and weld steel into approximately 50,000 tons of tubular pipe sections per year. Gulf Island hasoperate a state of the art, fully enclosed, and environmentally friendly blast and coating facility that can operate twenty-four hours a day. The facility is automated and provides blasting and coating activities in support of our Houma fabrication projects. The design output of the facility also allows us to provide blast and paint services to the Gulf south shipbuilding industry. The use of this equipment provides Gulf Island a competitive advantage by reducing labor costs.

Gulf Island’s panel line system located in theat our Houma west yard,Shipyard that consists of six individual in-linea fully automated systemssystem utilized to cut, weld, and assemble panels to be used in marine vessel construction.

Leased Facilities:

Prospect Shipyard - We lease a 35-acre complex 26 miles from the Gulf of Mexico near Houma, Louisiana, from the former owner of LEEVAC Shipyards, currently the Senior Vice President of our Shipyards division. The first station consistsleased yard includes 2,700 feet of bulkhead water frontage and 110,000 square feet of covered construction area. The lease expires 90 days following the completion of either of the two vessels currently under construction at the facility, but no later than August 31, 2017. We expect to move the machinery and equipment at this shipyard to our remaining Shipyard Division facilities prior to or at expiration of the lease.

Jennings Shipyard -Our Jennings Shipyard is an ESAB Avenger 3 Plasma cutting table for high speed cutting180-acre complex five miles east of Jennings, Louisiana, on the west bank of the Mermentau River approximately 25 miles north of the Intracoastal waterway that we lease from a third party. The Jennings Shipyard includes over 100,000 square feet of covered fabrication area including a panel line, pipe shop and beveling3,000 feet of water frontage with two launch ways and four covered construction bays. The lease, including exercisable renewal options, extends through January 2045.

Lake Charles Shipyard - Our Lake Charles Shipyard is a ten-acre complex 17 miles from the Gulf of Mexico on the Calcasieu River near Lake Charles, Louisiana, that we sublease from a third party. The Lake Charles Shipyard includes 1,100 feet of bulkhead water frontage with a water depth of 40 feet located one mile from the main ship channel and the Gulf Intracoastal Waterway. The sublease, including exercisable renewal options (subject to sublessor renewals), extends through July 2038.

We own the machinery and equipment at our leased facilities. These include a new plasma cutter installed in 2013, eight crawler cranes ranging from 65 to 230 tons, eight track cranes, ten overhead cranes, six dry docks ranging from 1,500 to 3,500 tons, and a 200-ton module transporter.

Services Division Facilities
Houma Services Yard -Our Houma Services Yard is a 63-acre facility that includes buildings totaling 14,500 square feet of administrative offices, 40,800 square feet of covered fabrication area, 29,600 square feet of warehouse storage area, a 10,000 square foot blasting and coating facility and approximately 1,320 linear feet of water frontage, including 660 feet of steel plates and shapes. The second station incorporates an Ogden Model OSWS-5600 single sided welder complete with an electromagnetic plate holding system whereby two steel plates are automatically welded together inbulkhead. It is located approximately a single pass utilizing a multiple sub arc welding process. This process can be repeated up to four times with a resultquarter of a single panel having an overall dimension of 40 by 50 feet. An ESAB Avenger 3-13 plate marking and cutting machine is positioned at the third station which lays out the welded panels, marks the applicable locations for

stiffeners installation, and cuts the plate to required configurations. The fourth station utilizes an Ogden Model SF-5600 stiffener fitting system to properly align and tack in place the plate stiffeners. The fifth station consists of an Ogden Model SW-5600-3 multiple stiffener welding system whereby three longitudinal plate stiffeners can be automatically welded (both sides) inmile from our Houma Fabrication Yard on a single operation performing continuous or intermittent welding of the stiffeners. There is also an automated conveyor system that operates along the panel line which transfers the panels from station to station. The sixth station is a vertical lifting system that elevates the fabricated panelschannel adjacent to the required height for transportation to the field.

Houma Navigation Canal. We own three spud barges for use in connection with our inshore construction activities. Each barge is equipped with a crane with a lifting capacity of 60 to 100 tons. In addition, we own a 26 foot long by 16 foot wide tug boat with two 300 horsepower engines used in connection with our three spud barges, reducing costs on tug boat rentals. We also own 10nine cranes, which range in tonnage capacity from 60 to 230 tons each.

We own 11 crawler cranes, which range in tonnage capacity from 230 to 825 tons each and are located at our Texas facility. The pipe mill at our Texas facility is equipped with a Haeusler Quad Roll, and Bertsch Model 30, Model 34 and Model 36 plate bending roll machines for diameters ranging from 1 foot 6 inches to 10 feet, and one large diameter plate bending roll machine, the Haeusler Quad Roll, for diameters ranging from 3 feet to 23 feet. The two Romar CNC-controlled flame planers, each with four torch stations (two torches per station), are used to cut steel plate up to 12 feet wide and 65 feet long. Our Texas facility is equipped with a panel line system, a Pangborn shot blast machine, 20,000 square feet of climate controlled staging area and a 16 feet by 14 feet by 125 feet paint booth that can operate 24 hours a day. We own an additional six rubber-tired, hydraulic modular transporters (KMAG – Type 2406), located at our Texas facility that allow fabricated deck sections that weigh as much as 1,200 tons to be transported throughout the facility. These transporters allow easier load-out of small decks and provide more agility for the movement of deck sections than cranes. All of our transporters can easily be relocated to or from our Louisiana and Texas facilities and, when used in tandem, have a capacity of 3,600 tons.

Materials and Supplies

The principal materials and supplies we use in the fabricationour business are standard steel shapes, steel plate, steel pipe, welding gases, fuel, oil, gasoline and paint, all of which are currently available from many sources. We do not depend upon any single supplier


or source. Demand forMost of the steel has remained steady both domesticallyused in our operations arrives at our fabrication yards as steel plate. The plate is cut and abroad overrolled into tubular sections at rolling mills in our fabrication yards. The tubular sections (which vary in diameter up to 23 feet) are welded together in long straight tubes to become legs or into shorter tubes to become part of the last yearnetwork of bracing that support the legs. Various cuts and welds in the fabrication process are performed by computer-controlled equipment that operates from data developed during the design of the structure. We use modern welding and fabrication technology, and all of our projects are manufactured in accordance with prices remaining fairly constant. industry standards, specifications and regulations, including those published by the American Petroleum Institute, the American Welding Society, the American Society of Mechanical Engineers, the American Bureau of Shipping and the United States Coast Guard. The quality management systems of our operating subsidiaries are certified as ISO 9001-2008 quality assurance programs. For additional information, see “Safety and Quality Assurance” below.
Standard delivery from domestic steel mills is runningtakes about 5about five to 6six weeks onfor as-rolled steels versus anywhere from 8eight to 12 weeks for heat treated steels. Due to the inability of domestic mills to produce our customers’ required steel grades, we are often forced to procure material from foreign steel mills. The delivery from these foreign mills, including transit time, is currently running approximately 16 to 20 weeks. To mitigate our risk of increasing cost of materials, we often negotiate escalation clauses in our contract termscustomer contracts to increase the contract price with a corresponding increaseto offset increases in cost of materials purchased during the life of the contract.

Safety and Quality Assurance

Management is committed to the safety and health of our employees. We believe that a strong safety culture is a critical element of our success. We continue to improve and maintain a stringent safety assurance program designed to mitigate the risk, and ultimately to eliminate accidents within our operations. Our Health, Safety, and Environment (“HSE”) department develops guidelines to ensure the safety of our employees and to allow us to remain in compliance with all applicable federal and state mandated safety regulations. We are committed to maintaining a well trained workforce and providing timely instruction to our workforce to ensure our workers have the knowledge and skills to perform their work safely while maintaining the highest standards of quality possible. We provide continuous quality safety education and training to both employees and subcontractors to ensure our people are ready for the challenges inherent in all fabrication projects. Our employees and subcontractors begin their training on their first day of employment with a comprehensive orientation class that addresses Company policies and procedures and provides clear expectations for working safely. The Company

maintains a zero tolerance approach to drugs and alcohol in the workplace. We support this policy through the use of a comprehensive drug and alcohol screening program that includes initial screenings for all employees and periodic random screenings throughout employment. Our employees are given opportunities to be a part of a dedicated safety committee which is comprised of peer-elected craft employees and members of management to assist in supporting theirour efforts to continuously improve our safety performance. This committee meets once a month to discuss safety issues and initiatives to prevent accidents within our organization.

We believe it is important to recognize and promote a positive and safe work culture. To this end, we hold a quarterly Safety Recognition Award Program. Our management team emphasises open lines of communication and conducts quarterly employee meetings throughout our various facilities in order to keep our workforce updated on safety concerns. We also use this time to conduct demonstrations in safety education and quality improvement. Since 2012, a safety component has been included in our annual incentive program guidelines for our executive officers and other key employees to recognize the importance that we and our customers place on safety.

We fabricate to the standards and regulations of the American Petroleum Institute, the American Welding Society, the American Society of Mechanical Engineers, the American Bureau of Shipping, the United States Coast Guard, the United States Navy, and customer specifications. We use welding and fabrication procedures in accordance with the latest technology and industry requirements. We have in place training programs for technical fitting and welding instruction in order to upgrade our skilled labor workforce and maintain high standards of quality. In addition, we maintain on-site facilities for the non-destructive testing of all welds, a process performed by an independent contractor.

Our quality management systems are certified as ISO 9001-2008 programs. ISO 9001-2008 is an internationally recognized verification system for quality management overseen by the International Standard Organization based in Geneva, Switzerland. The certification is based on a review of our programs and procedures designed to maintain and enhance quality production and is subject to semi-annual review and full recertification every three years.

Customers and Contracting

Our principal customers include major and large independent oil and gas companies and their contractors, petrochemical companies and marine service companies, offshore support companies, offshore and inland barge and support vessel operators, offshore construction contractors, diving companies,alternative energy companies the U.S. Army,(including offshore wind), diving companies, the U.S. Army Corps of Engineers, the U.S. Coast Guard, the U.S. Navy and the state and local governmental agencies and their contractors. Over the past five years, sales of structures and related services used in the Gulf of Mexico by oil and gas exploration and production companies accounted for approximately 69.4% of our revenue. Our international sales fluctuate from year to year depending on whether and to what extent our customers require installation of fabricated structures outside of the United States. Sales of fabricated structures installed outside the United States comprised between 3%6% and 16%14% of revenue during each of the last five years, and accounted for 10%14%, 6%, and 9%10% of revenue for the years ended December 31, 2016, 2015 and 2014, 2013 and 2012, respectively.

A large portion of our revenue has historically been generated by only a few customers, although not necessarily the same customers from year to year. OurThe loss of a significant customer in any given year for any reason, including a sustained decline in


that customer’s capital expenditure budget or competitive factors, can result in a substantial loss of revenue and could have a material adverse effect on our operating performance.
For the year ended December 31, 2016, revenue from our largest customer accounted for 23% of our revenue and related to the newbuild construction of two large offshore supply vessels. For the years ended December 31, 2015 and 2014, revenue from our two largest customers (those which individually accounted for 10% or more of revenue in a given year) accounted18% and 12% for 51% of revenue in 2014 (32% for Walter Oil & Gas Corporation2015, and 32% and 19% for Anadarko Petroleum Corporation), 60% of revenue in 2013 (36% for Williams Field Services – Gulf Coast Company, L.P. and 24% for Chevron Corporation), and 61% of revenue in 2012 (37% for Chevron Corporation and 24% for Williams Field Services – Gulf Coast Company, L.P.). Substantially all of the revenue represented by our largest customers (those which individually accounted for 10% or more of revenue in a given year) in the last three years relates2014, respectively related to work performed on large deepwater fabrication projects.

The shift in the mix of our largest customers from deepwater oil and gas customers to customers within the marine industry is the result of a combination of the reduced capital spending by our offshore oil and gas exploration and production customers and our diversification efforts to capitalize on the expansion of our shipbuilding capabilities following the LEEVAC transaction.

At December 31, 2014, 97.3%2016, 80.5% of our remaining backlog which consistedconsists of work remaining and commitments received through February 26, 2015, was attributable to 35 projects involving 12 customers. Of our backlog at December 31, 2014, projects for our three largest customers consisted of (i) jackets, piles, and topside for a

deepwater Gulf of Mexico project for one customer, (ii) five jackets and piles for a shallow water wind turbine project located off the coast of Rhode Island, and (iii) three tow boats for an inland towing customer.

two customers:

(i)two large multi-purpose supply vessels for one customer in our Shipyards division, which was acquired in the LEEVAC transaction and will be completed during the first and second quarter of 2018; and
(ii)the fabrication of four modules associated with a U.S. ethane cracker project in our Fabrication division to be completed in late 2017.
While customers may consider other factors, including the availability, capability, reputation and safety record of a contractor, we believe price and the ability to meet a customer’s delivery schedule are the principal factors weighed by customers in awarding contracts. Our contracts generally vary in length from one month to 24 months depending on the size and complexity of the project. Generally, our contracts and projects are subject to termination or reduction in scope at any time prior to completion, at the option of the customer. Upon termination or reduction in scope, however, the customer is generally required to pay us for work performed and materials purchased through the date of termination.

Generally our projects are subject to the same bid procedures and are accounted for using the percentage-of-completion accounting method. Projects are generally awarded on a fixed-price, unit rate, alliance/partnering or cost-plus basis. Under fixed-price contracts, we receive the price fixed in the contract, subject to adjustment only for change-orders approved by the customer. As a result, we retain all cost savings but are also responsible for all cost overruns. Under a unit rate contract, material items or labor tasks are assigned unit rates of measure. The unit rates of measure will generally be an amount of dollars per ton, per foot, per square foot or per item installed. A typical unit rate contract may contain hundreds to thousands of unit rates of measure. Profit margins are built in to the unit rates and, similar to a fixed price contract, we retain all cost savings but are also responsible for all cost overruns. Under typical alliance/partnering arrangements, the parties agree in advance to a target price that includes specified levels of labor and material costs and profit margins. If the project is completed at less cost than that targeted in the contract, the contract price is reduced by a portion of the savings. If the cost of completion is greater than that targeted in the contract, the contract price is increased, but generally to the target price plus the actual incremental cost of materials and direct labor costs. Accordingly, under alliance/partnering arrangements, we have some protection from cost overruns but also share a portion of any cost savings with the customer. Under cost-plus arrangements, pursuant to which we receive a specified fee in excess of our direct labor and material costs, we are protected against cost overruns but do not benefit directly from cost savings. Because we generally price materials as pass-through items on our contracts, the cost of our labor force is the primary factor affecting our operating costs. Consequently, it is essential that we control the cost and productivity of the direct labor hours worked on our projects.

Seasonality

Although high activity levels in the oil and gas industry and capacity limitations can somewhat diminish the seasonal effects on our operation, our

Our operations have historically been subject to seasonal variations in weather conditions and daylight hours. Since most of our construction activities take place outdoors, the number of direct labor hours worked generally declines during the winter months due to an increase in rain, cold temperatures, and a decrease in daylight hours. In addition, our oil and gas customers often schedule the completion of their projects during the summer months in order to take advantage of the mildermore favorable weather during such months for the installation of their platforms. In recent years, seasonality has had less of an impact on productivity mainly due togiven our ongoing investment in machinery and equipment and covered fabrication areas.

Competition

The offshore platform fabrication industry is

All three of our operating divisions are highly competitive and largely influenced by events largelyoil and gas prices, which are outside of the control of offshore platform fabrication companies. Platform fabrication companiesour customers. We compete intensely for available projects, which are generally awarded on a competitive bid basis with customers usually requesting bids on projects one to three months prior to commencement. Our marketing team approaches engineering companies, oil and gas companies, and marine companies with potential fabrication projects to allow us an opportunity to bid for the projects. Although we believe price and the contractor’s ability to meet a customer’s delivery schedule are the principal factors in determining which qualified fabricator is awarded a contract for a project, customers also consider, among other things, the availability of technically capable personnel and facility space, a fabricator’s efficiency, condition of equipment, reputation, safety record and customer relations.



We currently have one domestic competitor, Kiewit Offshore Services, for the fabrication of deepwater projects such as large topsides and tendons. However, an increasing number of foreign shipyards,yards, many of which have lower fixed costs than theirus and our United States competitors, also compete for larger deepwater projects destined for both the Gulf of Mexico and international waters. We compete with numerous domestic fabricators, including State Services Co., Inc. and Kiewit Offshore Services, for platform jackets for intermediate water depths from 150 feet to 300 feet. Numerous domestic and foreign shipyards and service companies compete with our Shipyards and Services divisions for marine projects.

We believe that our competitive pricing, expertise in fabricating offshore structures and the certification of our facilities as ISO 9001-2008 fabricators will enable us to continue to compete effectively for projects destined for the Gulf of Mexico and international waters. We recognize, however, that foreign governments often use subsidies and incentives to create local jobs where oil and gas production is being developed. In addition, as a result of recent technological innovations, decreased transportation costs incurred by our customers when exporting structures from foreign locations to the Gulf of Mexico may hinder our ability to successfully bid for projects in the Gulf of Mexico against foreign competitors.competitors for projects. Because of subsidies, import duties and fees, taxes on foreign operators, lower wage rates in foreign countries, fluctuations in the value of the U.S. dollar, the possible imposition of tariffs on raw materials imported into the United States, and other factors, we may not be able to remain competitive with foreign contractors for large deepwater projects.

Backlog

Our backlog is based on management’s estimate of the direct labor hours required to complete, and the remaining revenue to be recognized with respect to those projects for which a customer has authorized us to begin work or purchase materials or services pursuant to written contracts, letters of intent or other forms of authorization. However, management’s estimates are often based on preliminary engineering and design specification by the customer. As engineering and design plans are finalized or changes to existing plans are made, management’s estimate of the direct labor hours required to complete a project and the price of a project at completion is likely to change.

All projects currently included in our backlog generally are subject to suspension, termination, or a reduction in scope at the option of the customer, although the customer is generally required to pay us for work performed and materials purchased through the date of termination. In addition, customers have the ability to delay the execution of projects.

Some of our contracts contain provisions that require us to pay liquidated damages if we are responsible for the failure to meet specified contractual milestone dates and the applicable customer asserts a claim under those provisions. Those contracts define the conditions under which our customers may make claims against us for liquidated damages. In 2014, we had one asserted liquidated damages claim in the amount of $0.3 million that was fully settled, related to the fabrication of an offshore supply vessel. Other than the aforementioned claim, as of March 5, 2015, we were not aware of any asserted liquidated damages claims by any of our customers.

As of December 31, 2014, we had a revenue backlog of $184.7 million and a labor backlog of approximately 1.7 million man-hours remaining to work, including commitments received through February 26, 2015, compared to revenue backlog of $358.7 million and a labor backlog of 3.3 million man-hours reported as of December 31, 2013. We exclude suspended projects from contract backlog because resumption of work and timing of backlog revenues are difficult to predict. As of December 31, 2014, we had one suspended project related to the fabrication of a shallow water jacket. The project was 44% complete at December 31, 2014 and remaining backlog was $2.6 million. We were paid in full for all work completed for this project.

Of our backlog at December 31, 2014,

64.2% was for three customers as compared to 69.1% for three customers at December 31, 2013.

$70.1 million, or 38.0%, represented projects destined for deepwater locations compared to $224.5 million, or 62.6%, at December 31, 2013.

$5.3 million, or 2.9%, represented projects destined for foreign locations compared to $28.7 million, or 8.0%, at December 31, 2013.

Projects for our three largest customers consisted of (i) jackets, piles, and topside for a deepwater Gulf of Mexico project for one customer, which commenced in the second and fourth quarters of 2013, respectively; (ii) five jackets and piles for a shallow water wind turbine project located off the coast of Rhode Island that commenced in the fourth quarter of 2014; and (iii) three tow boats for an inland towing customer that commenced in the third quarter of 2014. The deepwater project is scheduled to be completed during the third quarter of 2015; two of the jackets, piles and deck projects are scheduled to be completed during the second quarter of 2015 and the last three jackets, piles and deck projects are scheduled to be completed during the third quarter of 2015; the first tow boat is expected to be completed during the third quarter of 2015, the second tow boat is expected to be completed during the first quarter of 2016, and the third tow boat is expected to be completed during the third quarter of 2016.

Depending on the size of the project, the termination, postponement, or reduction in scope of any one project could significantly reduce our backlog, and could have a material adverse effect on revenue, net income and cash flow. For additional information, see Note 1 in the Notes to Consolidated Financial Statements – Organization and Summary of Significant Accounting Policies-, “Assets held for sale” and Item 1A. Risk Factors – “Our backlog is subject to change as a result of changes to management’s estimates, suspension or termination of projects currently in our backlog or our failure to secure additional projects. Our revenue, net income and cash flow could be adversely affected as a result of changes to our backlog.”

As of December 31, 2014, we expect to recognize revenues from our backlog of approximately

$176.7 million, or 95.7%, during the calendar year 2015, and

$8.0 million, or 4.3%, during the calendar year 2016.

The timing of our recognition of the revenue backlog as presented above is based on management estimates of the application of the direct labor hours during the current projected timelines to complete the projects in our backlog. Certain factors and circumstances, as mentioned above, could cause changes in the period when the backlog is recognized as revenue.

Based on the activity of the major oil and gas companies and certain engineering companies, we expect bids for deepwater projects to be available in the second half of 2015, with a higher level of bidding activity in the fourth quarter of 2015. Bidding activity for non-traditional Gulf of Mexico (GOM) marine related projects, GOM shallow water projects, and ancillary work associated with deepwater structures is expected to increase in the second half of 2015.

Government and Environmental Regulation

Many aspects of our operations and properties are materially affected by federal, state and local regulations, as well as certain international conventions and private industry organizations. The exploration and development of oil and gas properties located on the outer continental shelf of the United States is regulated primarily by the Bureau of Ocean Energy, Management and Enforcement (“BOEM”) of the Department of Interior (“DOI”). The Secretary of the Interior, through the BOEM, is responsible for the administration of federal regulations under the Outer Continental Shelf Lands Act requiring the construction of offshore platforms located on the outer continental shelf to meet stringent engineering and construction specifications. Violations of these regulations and related laws can result in substantial civil and criminal penalties as well as injunctions curtailing operations. We believe that our operations are in compliance with these and all other regulations affecting the fabrication of platforms for delivery to the outer continental shelf of the United States. In addition, we depend on the demand for our services from the oil and gas industryand marine industries and, therefore, can be affected by changes in taxes, price controls and other laws and regulations relating to the oil and gas industry.affecting these industries. Offshore construction and drilling in certain

areas has also been opposed by environmental groups and, in certain areas, has been restricted. To the extent laws are enacted or other governmental actions are taken that prohibit or restrict offshore construction and drilling or impose environmental protection requirements that result in increased costs to the oil and gas industry in general and the offshore construction industry in particular, our business and prospects could be adversely affected. We cannot determine to what extent future operations and earnings may be affected by new legislation, new regulations or changes in existing regulations.

The Houma Navigation Canal provides the onlyshortest means of access from our LouisianaHouma facilities to open waters. With respect to our Texas facilities,North and South yards, the IntercoastalU.S. Intracoastal Waterway provides access between our Texas North and South Texas yards. From our Texas South yard,Yard, the Corpus Christi Ship Channel provides access to the Gulf of Mexico. These waterways are considered to be navigable waterways of the United States and, as such, are protected by federal law from unauthorized obstructions that would hinder water-borne traffic. Federal law also authorizes maintenance of these waterways by the U.S. Army Corps of Engineers. These waterways are dredged from time to time to maintain water depth and, while federal funding for dredging has historically been provided, there is no assurance that Congressional appropriations sufficient for adequate dredging and other maintenance of these waterways will be continued indefinitely. If sufficient funding were not appropriated for that purpose, some or all of these waterways could become impassable by barges or other vessels required to transport many of our projects and could have a material adverse effectSee also "Our business is highly dependent on our operations and financial position.

ability to utilize the navigation canals adjacent to our facilities." within our Risk Factors listed in Item 1A of this Report.

Our operations and properties are subject to a wide variety of increasingly complex and stringent foreign, federal, state and local environmental laws and regulations, including those governing discharges into the air and water, the handling and disposal of solid and hazardous wastes, the remediation of soil and groundwater contaminated by hazardous substances and the health and safety of employees. These laws may provide for “strict liability” for damages to natural resources and 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 revocationSee also "The nature of permits, corrective action orders, administrative or civil penalties and criminal prosecution. Certain environmental laws provide for strict, joint and several liability for remediation of spills and other releases of hazardous substances, as well as damage to natural resources. In addition, we may be subject to claims alleging personal injury or property damage as a result of alleged exposure to hazardous substances. Such laws and regulations may also exposeour industry subjects us to liability for the conduct of or conditions caused by others, or for acts that were in compliance with all applicable laws at the time we performed them.

regulatory and environmental laws." within our Risk Factors listed in Item 1A of this Report.

The Comprehensive Environmental Response, Compensation, and Liability Act of 1980, as amended and similar laws provide for responses to and liability for releases of hazardous substances into the environment. Additionally, the Clean Air Act, the Clean Water Act, the Resource Conservation and Recovery Act, the Safe Drinking Water Act, the Emergency Planning and Community Right to Know Act, each as amended, and similar foreign, state or local counterparts to these federal laws, regulate air emissions, water discharges, hazardous substances and wastes, and require public disclosure related to the use of various hazardous substances. Compliance with such environmental laws and regulations may require the acquisition of permits or other authorizations for certain


activities and compliance with various standards or procedural requirements. We believe that our facilities are in substantial compliance with current regulatory standards.

Our operations are also governed by laws and regulations relating to workplace safety and worker health, primarily the Occupational Safety and Health Act and regulations promulgated thereunder. In addition, various other governmental and quasi-governmental agencies require us to obtain certain permits, licenses and certificates with respect to our operations. The kinds of permits, licenses and certificates required by our operations depend upon a number of factors. We believe that we have all material permits, licenses and certificates necessary for the conduct of our existing business.

Our compliance with these laws and regulations has entailed certain additional expenses and changes in operating procedures; however, we believe that compliance efforts will not have a material adverse effect on our business or financial condition. 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 by us, which expenditures may be material.

Our employees may engage in certain activities, including interconnect piping and other service activities conducted on offshore platforms, activities performed on the spud barges owned or chartered by us, marine vessel fabrication and repair activities performed at our facilities, and operating vessels owned by us, that are covered in either the provisions of the Jones Act or U.S. Longshoreman and Harbor Workers Act (“USL&H”). These laws operate to make the liability limits established under state workers’ compensation laws inapplicable to these employees and, instead, permit them or their representatives to pursue actions against us for damages or job related injuries, with generally no limitations on our potential liability. Our ownership and operation of vessels and our fabrication and repair of customer vessels can give rise to large and varied liability risks, such as risks of collisions with other vessels or structures, sinkings, fires and other marine casualties, which can result in significant claims for damages against us for, among other things, personal injury, death, property damage, pollution and loss of business.

In addition, our operations are subject to extensive government regulation by the United States Coast Guard, as well as various private industry organizations such as the American Petroleum Institute, American Society of Mechanical Engineers, American Welding Society and the American Bureau of Shipping.

Our compliance with these laws and regulations has entailed certain additional expenses and changes in operating procedures; however, we believe that compliance efforts have not resulted in a material adverse effect on our business or financial condition. 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 by us, which could potentially adversely impact our future results of operations and financial position.
Insurance

We maintain insurance against property damage caused by fire, flood, explosion and similar catastrophic events that may result in physical damage or destruction to our facilities. All policies are subject to deductibles and other coverage limitations. We also maintain a builder’s risk policy for construction projects, general liability insurance and maritime employer’s liability insurance, which are also subject to deductibles and coverage limitations. The Company is self-insured for workers’ compensation and USL&H claims except for losses in excess of a per occurrence threshold amount. Although management believes that our insurance is adequate, there can be no assurance that we will be able to maintain adequate insurance at rates which management considers commercially reasonable, nor can there be any assurance that such coverage will be adequate to cover all claims that may arise.

Employees
Employees

Our workforce varies based on the level of ongoing fabrication activity at any particular time. As of December 31, 20142016 and 2013,2015, we had approximately 1,7001,178 and 1,9001,255 employees, respectively. Additionally, we will use contract labor when required to meet customer demand. The number of contract laborers we used decreasedincreased to 24792 in 20142016 as compared to 46771 in 2013.2015. In connection with our acquisition of LEEVAC, on January 1, 2016, we increased our employee count by 380 employees. None of our employees are employed pursuant to a collective bargaining agreement, and we believe our relationship with our employees is good.

We have reduced our skilled workforce during 2016 in response to decreases in utilization of our facilities. Our ability to remain productiveproductivity and profitableprofitability depends substantially on our ability to attract and retain skilled construction workers, primarily welders, fitters and equipment operators. In addition, our ability to expand our operations depends not only upon customer demand but also on our ability to increase our labor force. The demand for such workers is high and the supply can be limited, especially during periods of high activity in the oil and gas industry. While we believe our relationship with our skilled labor force is good, a significant increase in the wages paid by a wide range of other employers seeking similar skill sets could result in a reduction in our skilled labor force, increases in the wage rates we pay, increase in our use of contract labor, or all of these. Additionally, reductionsReductions made from time to time, in our labor force may make it more difficult for us to increase our labor force to desirable levels during periods of increasedrapid expanding customer demand. Also, when demand for these workers is high, the supply becomes increasingly limited resulting in increased market rates for these workers. During periods of high activity in past years, we have enhanced several incentive programs and expanded our services. If any of these occurredtraining facility in the near-term, the profits expected from work in progress could be reduced or eliminated and to the extent such wage increases could not be passed on to our customers, our production capacity and growth potential could be diminished. In an effort to maintain our current workforce and attract new employeesemployees. See also "We might be unable to employ a sufficient number of skilled workers." in periodsour Risk Factors listed in Item 1A of high activity, we have enhanced several incentive programs and expanded our training facility.

this Report.



Item 1A.Risk Factors

Item 1A. Risk Factors
Cautionary Statement


Our business is subject to significant risks. We caution readers that the following important factors could affect our actual consolidated results and could cause our actual consolidated results in the future to differ materially from the goals and expectations expressed in the forward-looking statements contained in this report and in any other forward-looking statements made by us or on our behalf.


We are subject to the cyclical nature of the oil and gas industry.

Our


Historically, our business depends primarilyhas depended significantly on the level of capital expenditures by offshore oil and gas and marine companies in the Gulf of Mexico and along the Gulf Coast. This level of activity has traditionally been volatile, primarily as a result of fluctuations in oil and gas prices. Projects for which we are engaged may be deferred or delayed by our customers based, in part, onOil and gas prices have remained significantly depressed since the latter half of 2014. In addition to the price of oil and gas. Thegas, the levels of our customers’ capital expenditures are influenced by, among other things:

oil and gas prices and industry perceptions of future prices;


the cost of exploring for, producing and delivering oil and gas;

the ability of oil and gas companies to generate capital;

the sale and expiration dates of offshore leases in the United States and overseas;

the discovery rate of new oil and gas reserves in offshore areas;

local, federal and international political and economic conditions;

technological advances; and

uncertainty regarding the United States energy policy, particularly any revision, reinterpretation or creation of environmental and tax laws and regulations that would negatively impact the industry.

Although activity


The above factors have not favored increased capital spending by offshore oil and gas companies in recent years. This had an adverse effect on our overall backlog levels and created challenges with respect to our ability to operate our fabrication facilities at desired utilization levels throughout 2015 and 2016, resulting in productiondecreased revenues and development sectorslower margins. As a result, there are fewer project awards to replace completed projects, and pricing of newer contracts remains increasingly competitive. In some cases, our customers have, in part, delayed or temporarily suspended both the completion of projects currently in process and the awards of future projects. We believe that the downturn in the oil and gas industry has also adversely impacted our Shipyards division as many of our marine customers' businesses are less volatile thanimpacted by changes in the exploration sector, producers generally react to declining oil and gas prices by reducing expenditures. This hasindustry. See also "We are exposed to the credit risks of our customers, and a general increase in the pastnonpayment and may in the future adversely affectnonperformance by customers could have an adverse impact on our business. cash flows, results of operations and financial condition."

We are unable to predict future oil and gas prices or the level of oil and gas industry activity in the Gulf of Mexico regionregion. Higher oil and internationally. A prolonged low level of activitynatural gas prices in the future may not necessarily translate into increased activity, and even during periods of relatively high oil prices, our customers may cancel or curtail programs, or reduce their levels of capital expenditures for offshore exploration and gas industry will adversely affect the demand forproduction. Advances in onshore exploration and development technologies, particularly with respect to large, onshore shale finds, could result in our productscustomers allocating a higher percentage of their capital expenditure budgets to onshore exploration and services,production activities and less to offshore activities. These factors could cause our revenues and margins to continue to remain depressed and limit our future growth prospects and, therefore, could have a material adverse effect on our financial condition andposition, results of operations.

operations and cash flows.


Our backlog is subject to change as a result of changes to management’s estimates, suspension or termination of projects currently in our backlog or our failure to secure additional projects. Our revenue, net income and cash flow could be adversely affected as a result of changes to our backlog.


We have reported revenue backlog of $133.0 million and a labor backlog of approximately 1.3 million man-hours. Our backlog is based on management’s estimate of the direct labor hours required to complete, and the remaining revenue to be recognized with respect to, thosecustomer projects as to which aeither already in progress or for projects where the customer has authorized us to begin work or purchase materials or services pursuant to written contracts, letters of intent or other forms of authorization. However, management’s estimates are often based on preliminary engineering and design specifications by the customer. Asas engineering and design plans are finalized or changes to existing plans are made, management’s estimate of the direct labor hours required to complete and the price at completion is likely to change.


All projects currently included in our backlog generally are subject to suspension, termination, or a reduction in scope at the option of the customer, although the customer is generally required to pay us for work performed and materials purchased through the date of termination. In addition, customers have the ability to delay the execution of projects. Depending on the size of the project, the termination, postponement, or change in

scope of any project could significantly change the expected timing



of revenue to be recognized, reduce backlog, and could have a material adverse effect on revenue, net income and cash flow. Accordingly, our backlog as of any particular date is an uncertain indicator of future earnings.

Deepwater


Our future results of operations depend upon the award of new contracts and the timing of those awards.

Our revenues are derived primarily from contracts awarded on a project-by-project basis. Generally, it is difficult to predict whether and when we will be awarded a new contract due to the complex bidding and selection processes, changes in existing or forecasted market conditions, governmental regulations, permitting and environmental matters. Because our revenues are derived from contract awards, our results of operations and cash flows can fluctuate materially from period to period.

The uncertainty associated with the timing of contract awards may reduce our short-term profitability as we balance our current capacity with expectations of future contract awards. If an expected contract award is delayed or not received, we could incur costs to maintain an idle workforce that may have a material adverse effect on our results of operations. Alternatively, we may decide that our long-term interests are best served by reducing our workforce and incurring increased costs associated with termination benefits, which also could have a material adverse effect on our results of operations in the period incurred. Reducing our workforce could also impact our results of operations if customers are hesitant to award new contracts to us based upon our staffing levels or if we are unable to adequately increase our labor force and staff projects that are awarded subsequent to a workforce reduction.

Competitive pricing common in the fabrication industry may not provide sufficient protection from cost overruns.

As is common in the fabrication industry, a substantial number of our projects are performed on a fixed-price or unit-rate basis. Under fixed-price or unit-rate contracts, we receive the price fixed in the contract, subject to adjustment only for change-orders placed by the customer. Under a unit rate contract, material items or labor tasks are assigned unit rates of measure. The unit rates of measure will generally be an amount of dollars per ton, per foot, per square foot or per item installed. A typical unit rate contract can contain hundreds to thousands of unit rates of measure. Profit margins are built into the unit rates and, similar to a fixed price contract, we retain all cost savings but are also responsible for all cost overruns.

The revenue, costs and gross profit realized on a contract will often vary from the estimated amounts on which such contracts were originally estimated due to the following:

We rely heavily on steel purchased from domestic and foreign steel mills as well as outside services for the installation of electrical and mechanical equipment. We generally mitigate this risk with typical alliance/partnering arrangements to provide some protection against cost overruns. While such mechanisms are in place to reduce this risk, we may not be able to adequately cover increases in costs and our margins could be negatively impacted.
Our vendors may be unable to deliver materials or contracted services on schedule or at the agreed upon price. We generally have historically representedmechanisms in place to indemnify us with respect to damages that we may incur; however, we may be unable to enforce such indemnification or obtain the materials / services from an alternate vendor on a timely basis or at a comparable price which could result in delays and/or increased costs.
Our execution and productivity could deteriorate from the original estimates as a a result of poor execution and / or weather conditions.
We may be unable to obtain compensation for additional work we perform or expenses we incur from our customers;
We may incur payment of liquidated damages upon a failure to meet scheduled delivery requirements.
Our projects may be terminated, temporarily suspended or significantly reduced in scope by our customers. Our contracts generally provide for reimbursement of all costs plus the portion of the contract earned to date; however, they do not replace future overhead or labor costs when such terminations, delays or reductions in scope result in decreased utilization of the yard and an idle labor force.

These variations and risks are inherent within our industry and may result in revenue and gross profits different from those originally estimated and reduce profitability or create losses on projects. Depending on the size of a project, variations from estimated contract performance can have a significant partimpact on our operating results for any particular fiscal quarter or year. In addition, substantially all of our backlog. Ascustomer contracts require us to continue work in accordance with the contractually agreed schedule (and thus, continue to incur expenses for labor and materials) notwithstanding the occurrence of December 31, 2014, we had a revenue backlog of $184.7 million and a labor backlog of approximately 1.7 million man-hours. With respect to backlog at December 31, 2014, $70.1 million, disagreement with customers over increased pricing and/or approximately 38.0%, represents projects destined for deepwater locations. Since the scope of work and contract prices on most deepwater projects typically represent a substantial portion of overall backlog, a suspension, termination, orunresolved change in scope of any of these projects is likely to have a more significant adverse impact on revenue, net income and cash flow as compared to other projects. orders.

For example, in 2013,during the third and fourth quarters of 2015, we recognized estimatedrecorded contract losses of $29.6$24.5 million onrelated to a large deepwater project as a result ofdecrease in the contract price due to final weight re-measurements and our inability to recover certain costs on disputed change orders related to a large deepwater project which was delivered in 2015. In the second quarter of 2016, we initiated legal action to recover


our costs from these disputed change orders. We can give no assurance that our actions will be successful or that we will recover all or any portion of these contract losses from our customer.

Our decision to explore the sale of our South Texas properties presents risks that could have a material adverse effect on our business, results of operations, financial condition and cash flows. Any sales we consummate may not produce desired results.

We continually evaluate opportunities to dispose of assets that are not expected to provide sufficient long-term value. On February 23, 2017, our Board of Directors approved a recommendation of management to place our South Texas properties located in Aransas Pass and Ingleside, Texas, up for sale. These properties are currently underutilized and represent excess capacity within our Fabrication division. We are working to wind down all fabrication activities at these locations and re-allocate remaining backlog and workforce to our Houma Fabrication Yard as necessary. We do not expect the sale of these properties to impact our ability to service our deepwater customers or operate our Fabrication division.

Our efforts to sell the South Texas properties expose us to a number of risks, including the diversion of management and employee attention from operation of the business, significant costs and expenses, the loss of customer relationships, the loss of key employees, a decrease in revenues and earnings associated with holding these assets for sale, effects on our reported results of operations from disposition-related charges, amortization of expenses related to intangibles and charges for impairment of long-term assets, and the de-scopingdisruption of operations.

We cannot assure you that we will be able to consummate any such sales on commercially reasonable terms or at all, or that we will actually realize any anticipated benefits from such sales. Dispositions of real estate and other specialized assets of this nature may be difficult in the current economic environment, as financing alternatives may be limited for potential buyers. Even if we are able to find purchasers, we may not be able to obtain attractive terms and conditions for such sales, including attractive pricing.

The uncertainty associated with the timing of a sale or sales of these assets may reduce our short-term profitability as we re-allocate assets and workforce to perform current backlog and future contract awards at our Houma Fabrication Yard. Even if we are successful in consummating the sale of the project, whereby remaining completionSouth Texas properties and integrationrelated equipment, such disposition may result in losses, which could negatively affect operating results for the period in which such sales occur. Additionally, any decisions we may make regarding our deployment or use of any sales proceeds we receive in any sale involves risks and uncertainties. As a result, our decisions with respect to such cash may not lead to increased long-term stockholder value.

Our credit agreement contains operating and financial restrictions that may restrict our business and financing activities.

The operating and financial restrictions and covenants in our credit agreement and any future financing agreements could restrict our ability to finance future operations or capital needs or to engage, expand or pursue our business activities. For example, our credit agreement restricts our ability to:

grant liens;
make certain loans or investments;
incur additional indebtedness or guarantee other indebtedness in excess of specified levels;
make any material change to the nature of our business or undergo a fundamental change;
make any material dispositions;
acquire another company or all or substantially all of its assets;
enter into a merger, consolidation, or sale leaseback transaction; or
declare and pay dividends if any potential default or event of default occurs.

Our ability to comply with the covenants and restrictions contained in our credit agreement may be affected by events beyond our control, including prevailing economic, financial and industry conditions. If market or other economic conditions deteriorate, our ability to comply with these covenants may be impaired. If we violate any of the restrictions or covenants in our credit agreement, any outstanding indebtedness under the credit agreement would become immediately due and payable, and our lenders' commitment to make further loans to us may terminate. We might not have, or be able to obtain, sufficient funds to make these accelerated payments. In addition, our obligations under our credit agreement are secured by substantially all of our assets (other than real estate), and if we are unable to repay our indebtedness under our credit agreement, the lenders could seek to foreclose on such assets. See also "Liquidity and Capital Resources" in Item 7 of this Report.



We depend on significant customers.

We derive a significant amount of our revenue from a small number of major and independent oil and gas and marine companies. Because the level of fabrication that we may provide to any particular customer depends, among other things, on the size of that customer’s capital expenditure budget and our ability to meet the customer’s delivery schedule, customers that account for a significant portion of our revenue in one fiscal year may represent an immaterial portion of revenue in subsequent years. For example, for the year ended December 31, 2016, revenue from our largest customer accounted for 23% of our revenue and related to the newbuild construction of two large offshore supply vessels. For the years ended December 31, 2015 and 2014, revenue from our two largest customers accounted for 18% and 12% for 2015, and 32% and 19% for 2014, respectively related to work was performed on large deepwater fabrication projects. The loss of a significant customer in any given year for any reason, including a sustained decline in that customer’s capital expenditure budget or competitive factors, can result in a substantial loss of revenue and could have a material adverse effect on our operating performance.

Our customers are facing significant challenges and a period of consolidation within their industry that may impact our results of operations.

The oil and gas industry is facing significant challenges due to the prolonged period of depressed oil and gas prices resulting in significantly decreased revenues, lower margins and decreased cash flows. This has also negatively impacted the marine industry that supports offshore exploration and production. The result is that many companies are unable to compete and, in some cases, unable to pay their liabilities as they become due. This has resulted in many companies within the both industries seeking bankruptcy protection and or seeking consolidation via acquisition by other companies. We expect this trend to continue.

Customers that acquire other companies may result in reduced capital spending and the decreased demand for our products and services, especially if they acquire a company that provides similar services as us. We cannot assure you that we will be able to maintain our level of sales to a customer that has consolidated or replace that revenue with increased business activity with other customers. Acquisition of one or more of our primary customers by a different integration contractor.company that is not a customer may also have a significant negative impact on our results of operations, financial position or cash flows. We are unable to predict what effect consolidations in the industry may have on price, capital spending by our customers, our selling strategies, our competitive position, our ability to retain customers or our ability to negotiate favorable agreements with our customers.

We are exposed to the credit risks of our customers, and a general increase in the nonpayment and nonperformance by customers could have an adverse impact on our cash flows, results of operations and financial condition.

Our business is subject to risks of loss resulting from nonpayment or nonperformance by our customers. Certain of our customers finance their activities through cash flow from operations, the incurrence of debt or the issuance of equity. As discussed above, our customers are facing significant challenges. As a result, our customers are facing decreased cash flow, a reduction in borrowing bases and a reduction in our customers’ liquidity and ability to pay or otherwise perform on their obligations to us. Furthermore, some of our customers may be highly leveraged and subject to their own operating and regulatory risks, which increases the risk that they may default on their obligations to us. Any increase in the nonpayment and nonperformance by our customers could have an adverse impact on our operating results and could adversely affect our liquidity.

On October 21, 2016, a customer of our Shipyards division announced it had received limited waivers from its lenders and noteholders through November 11, 2016, which was extended through March 3, 2017 with respect to noncompliance with certain financial covenants included in the customer’s debt agreements. The customer also announced its debt agreements will require further negotiation and amendment. In 2012,the event our customer is unsuccessful in these efforts, the customer has publicly stated that it will consider other options including a possible reorganization under Chapter 11 of the Federal bankruptcy laws. At December 31, 2016, we enteredhad two vessels under construction for this customer with no contracts receivable outstanding and deferred revenue exceeded our contracts in progress. See also "Liquidity and Capital Resources" within Item 7 of this Report.

We may not fully integrate acquisitions into a contract with another deepwater customerour operations as quickly as we anticipated, and therefore, not yield anticipated returns.
On January 1, 2016, LEEVAC Shipyards, L.L.C. and its related affiliates sold substantially all of their assets, including leasehold interests in marine fabrication facilities in Houma, Jennings, and Lake Charles, Louisiana, and substantially all of their machinery and equipment, to suspend work on one of our majorsubsidiaries. We have integrated this acquisition into our operations, but future projects have not materialized to date. See further discussion of our acquisition of the LEEVAC assets in Item 1 - “Business and Properties - LEEVAC Transaction.”


The acquisition of the LEEVAC assets and any potential future acquisitions may expose us to the following risks, any of which, could adversely affect our financial condition, results of operation, cash flows and the customer’s failuretrading price of our common stock:
We may not be able to paysecure additional projects or work for the outstanding balance of $31.3 million onnew assets acquired due to downturns in our markets.
We may be unsuccessful in managing current projects acquired, which could result in future potential losses.
Cash flows and profits derived from the contract onacquired assets may not be accretive to our consolidated operations.
We may be unable to efficiently integrate personnel and systems within our operations resulting in increased costs.
Acquired assets and leases could subject us to liabilities with limited or before March 31, 2013, terminated the contract with our customer.

no recourse that could potentially include, but are not limited to, environmental contamination and claims by customers and/or vendors.


We might be unable to employ a sufficient number of skilled workers.


We have reduced our skilled workforce during 2016 in response of decreases in utilization of our facilities. Our ability to remain productiveproductivity and profitableprofitability depends substantially on our ability to attract and retain skilled construction workers, primarily welders, fitters and equipment operators. In addition,Reductions made in our labor force may make it more difficult for us to increase our labor force to desirable levels during periods of rapid expanding customer demand. Our ability to expand our operations depends not only uponin tandem with customer demand but alsodepends on our ability to increase our labor force. Theforce when necessary with the appropriate skilled construction workers. Also, when demand for suchthese workers is high, and the supply is extremelybecomes increasingly limited especially duringresulting in increased market rates for these workers. During periods of high activity in the oilpast years, we have enhanced several incentive programs and gas industry. Whileexpanded our training facility in an effort to maintain our current workforce and attract new employees.
Even if we believeare able to increase our relationship with our skilled labor force is good, aworkforce in times of higher demand, significant increase in the wages paid by a wide range of other employers seeking similar skill sets could result in a reduction in our skilled labor force, increases in the wage rates we pay, increase in our use of contract labor, or all of these. Additionally, reductions made, from time to time, inWhile we believe our relationship with our skilled labor force may make it more difficult for us to increase our labor force to desirable levels during periods of increased customer demand for our services. If any of these occurred in the near-term,is good, the profits expected from work in progress and future projects could be reduced or eliminated and to the extent suchwe are unable to properly increase our workforce or if potential wage increases could not be passed on to our customers, our production capacity could be diminished and our growth potential could be impaired.

limited if we were to experience a rapid expansion of demand.

The dangers inherent in our operations and the limits on our insurance coverage could expose us to potentially significant liability costs and materially interfere with the performance of our operations.


The fabrication of large steel structuresour facilities involves operating hazards that can cause personal injury or loss of life, severe damage to and destruction of property and equipment and suspension of operations. The failure of such structures during and after installation can result in similar injuries and damages. In addition, our employees may engage in certain activities, including interconnect piping and other service activities conducted on offshore platforms, activities performed on the spud barges owned or chartered by us, marine vessel fabrication and repair activities performed at our facilities and operating vessels owned by us, that are covered in either the provisions of the Jones Act or USL&H. These laws operate to make the liability limits established under state workers’ compensation laws inapplicable to these employees and, instead, permit them or their representatives to pursue actions against us for damages or job related injuries, with generally no limitations on our potential liability.


Our ownership and operation of vessels can give rise to large and varied liability risks, such as risks of collisions with other vessels or structures, sinkings, fires and other marine casualties, which can result in significant claims for damages against both us and third parties. Litigation arising from any such occurrences may result in our being named as a defendant in lawsuits asserting large claims. In addition, due to the proximity to the Gulf of Mexico, our facilities are subject to the possibility of physical damage caused by hurricanes or flooding.


Although we believe that our insurance coverage is adequate, there can be no assurance that we will be able to maintain adequate insurance in the future at rates we consider reasonable or that our insurance coverage will be adequate to cover future claims that may arise. Claims for which we are not fully insured may adversely affect our working capital and profitability. In addition, changes in the insurance industry have generally led to higher insurance costs and decreased availability of coverage. The availability of insurance that covers risks we and our competitors typically insure against may decrease, and the insurance that we are able to obtain may have higher deductibles, higher premiums and more restrictive policy terms.


Our industry is highly competitive.


The offshore and marine fabrication industry isindustries are highly competitive and influenced by events largely outside of our control. Contracts for our services are generally awarded on a competitive bid basis, and our customers consider many factors when awarding a job. These factors include price, the contractor’s ability to meet the customer’s delivery schedule, the availability and capability of equipment, and the reputation, experience, and safety record of the contractor. Although we believe that our reputation


for safety and quality service is good, we cannot guarantee that we will be able to maintain our competitive position. We compete with both large and small companies for available jobs, and certain of our competitors, particularly our domestic competitor for major deepwater projects, have greater financial and other resources than we do.


Foreign governments often use subsidies and incentives to create local jobs where oil and gas production is being developed. In addition, decreased transportation costs incurred by our customers when exporting structures from foreign locations to the Gulf of Mexico may hinder our ability to successfully bid for projects in the Gulf of Mexico against foreign competitors. Because of subsidies, import duties and fees, taxes on foreign operators, lower wage rates in foreign countries, fluctuations in the value of the U.S. dollar, the possible imposition of tariffs on raw materials imported into the United States, and other factors, we may not be able to remain competitive with respect to pricing compared to foreign contractors for large deepwater projects.contractors. For additional information, see “BusinessItem 1. “Business and Properties – Competition”- Competition” for more information regarding the competitive nature of our industry.

Competitive pricing common in the fabrication industry may not provide sufficient protection from cost overruns.

As is common in the offshore platform fabrication industry, a substantial number of our projects are performed on afixed-price or unit-rate basis, although some projects are performed on an alliance/partnering orcost-plus basis. Underfixed-price or unit-rate contracts, we receive the price fixed in the contract, subject to adjustment only for change-orders placed by the customer. Under a unit rate contract, material items or labor tasks are assigned unit rates of measure. The unit rates of measure will generally be an amount of dollars per ton, per foot, per square foot or per item installed. A typical unit rate contract can contain hundreds to thousands of unit rates of measure. Profit margins are built in to the unit rates and, similar to a fixed price contract, we retain all cost savings but are also responsible for all cost overruns. Under typical alliance/partnering arrangements, the parties agree in advance to a target price that includes specified levels of labor, material costs and profit margins. If the project is completed at less cost than that targeted in the contract, the contract price is reduced by a portion of the savings. If the cost of completion is greater than target costs, the contract price is increased, but generally to the target price plus the actual incremental cost of materials and direct labor. Accordingly, under alliance/partnering arrangements, we have some protection against cost overruns but must share a portion of any cost savings with the customer. Undercost-plus arrangements, we receive a specified fee in excess of our direct labor and material cost and thus are protected against cost overruns, but do not benefit directly from cost savings.

The revenue, costs and gross profit realized on a contract will often vary from the estimated amounts on which such contracts were originally based due to, among other things:

changes in the availability and cost of labor and material;


variations in productivity from the original estimates;

our inability to recover compensation for additional work we perform or expenses we incur as a result of customer change orders or customer delays in delivering or deviations to designs and drawings;

changes in estimates or bidding;

our payment of liquidated damages upon a failure to meet scheduled delivery requirements; and

termination or de-scoping of projects by our customers.

These variations and the risks inherent in our industry may result in revenue and gross profits different from those originally estimated and reduce profitability or create losses on projects. Depending on the size of a project, variations from estimated contract performance can have a significant impact on our operating results for any particular fiscal quarter or year.

For example, we recognized contract losses of $6.6 million for the year ended December 31, 2014 that were primarily related to two tank barge projects for a marine transportation company, platform supply vessels for an offshore marine company and a production platform jacket for a deepwater customer. We also recognized contract losses of $29.6 million as of December 31, 2013 on one of our large deepwater projects, mainly due to our inability to recover certain costs and the de-scoping of one of our major deepwater contracts.

Our failure to successfully defend against claims made against us by customers or subcontractors, or our failure to successfully recover on claims made by us against customers or subcontractors, could adversely affect our business, financial condition, results of operations and cash flows.


Our projects are generally highly complex and we may encounter difficulties in design or engineering, schedule changes and other factors, some of which may be beyond our control, that affect our ability to complete projects in accordance with original delivery schedules or to otherwise meet contractual performance obligations. We may bring claims against customers for additional costs exceeding contract prices or for amounts not included in original contract prices as a result of customer-caused delays or changes from initial project scope. In addition, claims may be brought against us by customers relating to, among other things, alleged defective or incomplete work, breaches of warranty and/or late completion of work. Claims among us and our subcontractors may include claims similar to those described above. These claims may be subject to lengthy and/or expensive litigation or arbitration proceedings, and we may invest significant working capital in projects to cover cost overruns pending resolution of these claims. These claims could materially adversely affect our business, financial condition, results of operations and cash flows.


We may need to raise additional capital in the future for working capital, capital expenditures and/or acquisitions, and we may not be able to do so on favorable terms or at all, which would impair our ability to operate our business or achieve our strategic plan.

On December 16, 2016, we amended our credit agreement with Whitney Bank and JPMorgan Chase Bank N.A. which reduced the borrowing base from $80.0 million to $40.0 million. Given the historically low levels of borrowings under our prior credit facility and our cash position, we requested a reduction in the amount of available credit under the facility from $80.0 million to $40.0 million during negotiations with the lenders to decrease the commitment fees payable on the undrawn portion of the facility. See also "Liquidity and Capital Resources" within Item 7 of this Report. We may wish to take advantage of potential acquisitions during this period of consolidation within the oil and gas industry, or we may be awarded contracts as activities improve that may require capital above current capacity levels. To the extent that cash flow from operations, together with available borrowings under our credit facility, are insufficient to make future investments, acquisitions or provide needed working capital, we may require additional financing from other sources. Our ability to obtain such additional financing in the future will depend in part upon prevailing capital market conditions, as well as conditions in our business and our operating results, and those factors may affect our efforts to arrange additional financing on terms that are satisfactory to us. If adequate funds are not available, or are not available on acceptable terms, we may not be able to make future investments, take advantage of acquisitions or other investment opportunities, or respond to competitive challenges.

Our method of accounting for revenue using the percentage-of-completion method could result in an earnings charge.


Most of our revenue is recognized on apercentage-of-completion basis based on the ratio of direct labor hours worked to the total estimated direct labor hours required for completion. Accordingly, contract price and cost estimates are reviewed monthly as the work progresses, and adjustments proportionate to the percentage of completionpercentage-of-completion are reflected in revenue for the period when such estimates are revised. To the extent that these adjustments result in a reduction or elimination of previously reported profits, we are required to recognize a charge against current earnings, which may be significant depending on the size of the project or the adjustment.

For example, during the third and fourth quarters of 2015, we recognizedrecorded contract losses of $6.6$24.5 million for the year ended December 31, 2014 that were primarily related to two tank barges projects for a marine transportation company, platform supply vessels for an offshore marine company and a production platform jacket for a deepwater customer. We also recognizeddecrease in the contract losses of $29.6 million as of December 31, 2013 on one of our large deepwater projects, mainlyprice due to final weight re-measurements and our inability to recover certain costs andon disputed change orders related to a large deepwater project which was delivered in 2015. In the de-scopingsecond quarter of one2016, we initiated legal action to recover our costs from these disputed change orders. We can give no assurance that our actions will be successful or that we will recover all or any portion of these contract losses from our major deepwater contracts.

customer.




We are susceptiblerequired to adverse weather conditions in our market areas.

Our operations are directly affected by the seasonal differences in weather patternsmake other estimates in the Gulf of Mexico, as well as daylight hours. Since mostpreparation of our construction activities take place outdoors,consolidated financial statements in addition to the numberapplication of direct labor

hours workedpercentage-of-completion accounting and actual results could differ materially from those estimates.


Accounting principles generally declinesaccepted in the winter months dueUnited States (GAAP) require management to an increase in rain, colder temperatures,make estimates and a decrease in daylight hours. The seasonalityassumptions that affect the reported amounts of oilassets and gas industry activity as a whole inliabilities and disclosure of contingent liabilities at the Gulf Coast region also affects our operations. Our customers often scheduledate of the completionfinancial statements and the reported amounts of their projectsrevenue and expense during the summer monthsreporting period. Areas requiring significant estimates by our management in orderaddition to take advantagepercentage-of-completion accounting (described above) include asset impairments, value of milder weatherassets held for sale, provisions for contract losses, contract revenues and the installationdetermination of their platforms. The rainy weather, tropical storms, hurricanes and other storms prevalent in the Gulfallowance of Mexico and along the Gulf Coast throughout the year may also affect our operations. Accordingly, our operatingdoubtful accounts. Actual results may varycould materially differ from quarter to quarter, depending on factors outside of our control. As a result, full year results are not likely to be a direct multiple of any particular quarter or combination of quarters.

these estimates.


We depend on key personnel.


Our success depends to a great degree on the abilities of our key management personnel, particularly our executives and other key employees. The loss of the services of one or more of these individuals could adversely affect us.

We depend on significant customers.

We derive a significant amount of our revenue from a small number of major and independent oil and gas and marine companies. Generally, our major oil and gas customers engage us for large deepwater fabrication projects. Because the level of fabrication that we may provide to any particular customer depends, among other things, on the size of that customer’s capital expenditure budget devoted to platform construction plans in a particular year and our ability to meet the customer’s delivery schedule, customers that account for a significant portion of our revenue in one fiscal year may represent an immaterial portion of revenue in subsequent years. For example, our largest customers (those which individually accounted for 10% or more of revenue in a given year) accounted for 51% of revenue in 2014 (32% for Walter Oil and Gas Corporation and 19% for Anadarko Petroleum Corporation), 60% of revenue in 2013 (36% for Williams Field Services – Gulf Coast Company, L.P. and 24% for Chevron USA, Inc.), and 61% of revenue in 2012 (37% for Chevron USA, Inc. and 24% for Williams Field Services – Gulf Coast Company, L.P.). The loss of a significant customer in any given year for any reason, including a sustained decline in that customer’s capital expenditure budget or competitive factors, can result in a substantial loss of revenue and could have a material adverse effect on our operating performance.


The nature of our industry subjects us to compliance with regulatory and environmental laws.


Our operations and properties are materially affected by state and federal laws and other regulations relating to the oil and gas industry in general, as well as a wide variety of federal, state and local environmental laws and regulations, including those governing discharges into the air and water, the handling and disposal of solid and hazardous wastes, the remediation of soil and groundwater contaminated by hazardous substances and the health and safety of employees. Compliance with many of these laws is becoming increasingly complex, stringent and expensive. Many of these laws impose “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 its negligence or fault. Certain environmental laws provide for strict, joint and several liability for remediation of spills and other releases of hazardous substances, as well as damage to natural resources. In addition, we could be subject to claims alleging personal injury or property damage as a result of alleged exposure to hazardous substances. Such laws and regulations may also expose us to liability for the conduct of or conditions caused by others, or for acts that were in compliance with all applicable laws at the time such acts were performed. We believe that our present operations substantially comply with applicable federal and state pollution control and environmental protection laws and regulations. We also believe that compliance with such laws has had nonot resulted in material adverse effect on our operations. However, such environmental laws are changed frequently. Sanctions for noncompliance may include revocation of permits, corrective action orders, administrative or civil penalties and criminal prosecution. We are unable to predict whether environmental laws will materially adversely affect our future operations and financial results. See “Business“Business and Properties –- Government and Environmental Regulation.Regulation”

in Item 1 of this Report.


The demand for our services is also affected by changing taxes, price controls and other laws and regulations relating to the oil and gas industryand marine industries generally. The current environment has federal, state and local governments faced with spending deficits. We would expect to pass any potential increases in taxes on to our customers.

Offshore construction and drilling in certain areas has also been opposed by environmental groups and, in certain areas, has been restricted. To the extent laws are enacted or other governmental actions are taken that prohibit or restrict offshore construction and drilling or impose environmental protection requirements that result in increased costs to the oil and gas industry in general and the offshore construction industry in particular, our business and prospects could be adversely affected. We cannot determine to what extent future operations and earnings may be affected by new legislation, new regulations or changes in existing regulations.


Our business is highly dependent on our ability to utilize the Houma Navigation Canal and Corpus Christi Ship Channel.

navigation canals adjacent to our facilities.


The Houma Navigation Canal provides the onlyshortest means of access from our facilities in Houma, Louisiana, facilities to open waters. With respect to our Texas facilities, the IntercoastalU.S. Intracoastal Waterway provides access between our Texas North and Texas South Texas yards. From our Texas South Texas yard,Yard, the Corpus Christi Ship Channel provides access to the Gulf of Mexico. Our Jennings Shipyard in Jennings, Louisiana, is located on the west bank of the Mermentau River approximately 25 miles north of the Intracoastal Waterway and our Lake Charles Shipyard is 17 miles from the Gulf of Mexico on the Calcasieu River near Lake Charles, Louisiana. These waterways are considered to be navigable waterways of the United States and, as such, are protected by federal law from unauthorized obstructions that would hinder water-borne traffic. Federal law also authorizes maintenance of these waterways by the U.S. Army Corps of Engineers. These waterways are dredged from time to time to maintain water depth and, while federal funding for dredging has historically been provided, there is no assurance that Congressional appropriations sufficient for adequate dredging and other maintenance of these waterways will be continued indefinitely. If sufficient funding were not appropriated for that purpose, some or all of these waterways could become impassable by barges or other vessels required to transport many of our products and could have a material adverse effect on our operations and financial position.




We depend on subcontractor services to perform our contractual obligations.


Our ability to perform under our contracts depends to some degree on the performance of third parties we subcontract. We depend upon subcontractors for a variety of reasons, including:


to perform work as a result of scheduling demands we would otherwise perform with our employees;

to supervise and/or perform certain aspects of the contract more efficiently considering the conditions of the contract; and

to perform certain types of skilled work.


We work closely with these subcontractors to monitor progress and address our customer requirements. We generally have the ability to pursue back charges for costs we incur or liabilities we assume as a result of a subcontractor’s lack of performance. However, the inability of our subcontractors to perform under the terms of their contracts could cause us to incur additional costs that reduce profitability or create losses on projects.


We are exposed to risks arising out of recent legislation affecting U.S. public companies.


Changing laws, regulations and standards relating to corporate governance and public disclosures, including the Sarbanes-Oxley Act and the Dodd-Frank Wall Street Reform and Consumer Protection Act, and related regulations implemented thereunder, are increasing legal and financial compliance costs and making some activities more time consuming. Any failure to successfully or timely complete annual assessments of our internal controls required by Section 404 of the Sarbanes-Oxley Act could subject us to sanctions or investigations by regulatory authorities. Any such action could adversely affect our financial results or our reputation with investors, lenders and others.


We are susceptible to adverse weather conditions in our market areas.

Our operations are directly affected by the seasonal differences in weather patterns in the Gulf of Mexico, as well as daylight hours. Since most of our construction activities take place outdoors, the number of direct labor hours worked generally declines in the winter months due to an increase in rain, colder temperatures, and a decrease in daylight hours. The seasonality of oil and gas industry activity as a whole in the Gulf Coast region also affects our operations. Our oil and gas customers often schedule the completion of their projects during the summer months in order to take advantage of milder weather for the installation of their platforms. The rainy weather, tropical storms, hurricanes and other storms prevalent in the Gulf of Mexico and along the Gulf Coast throughout the year may also affect our operations. Accordingly, our operating results may vary from quarter to quarter, depending on factors outside of our control. As a result, full year results are not likely to be a direct multiple of any particular quarter or combination of quarters.

Systems and information technology interruption or failure and data security breaches could adversely impact our ability to operate or expose us to significant financial losses and reputational harm.

We rely heavily on computer information and communications technology and related systems in order to properly operate our business. From time to time, we experience occasional system interruptions and delays. In the event we are unable to regularly deploy software and hardware, effectively upgrade our systems and network infrastructure, and take other steps to maintain or improve the efficiency and efficacy of our systems, the operation of such systems could be interrupted or result in the loss, corruption, or release of data. In addition, our computer and communication systems and operations could be damaged or interrupted by natural disasters, force majeure events, telecommunications failures, power loss, acts of war or terrorism, computer viruses, malicious code, physical or electronic security breaches, intentional or inadvertent user misuse or error, or similar events or disruptions. Any of these or other events could cause interruptions, delays, loss of critical and/or sensitive data or similar effects, which could have a material adverse impact on our business, financial condition, protection of intellectual property, and results of operations, as well as those of our clients.

In addition, we face the threat to our computer systems of unauthorized access, computer hackers, computer viruses, malicious code, organized cyber-attacks and other security problems and system disruptions, including possible unauthorized access to and disclosure of our and our clients’ proprietary or classified information. We rely on industry accepted security measures and technology to securely maintain all confidential and proprietary information on our computer systems, but they may still be vulnerable to these threats. As a result, we may be required to expend significant resources to protect against the threat of these system disruptions and security breaches or to alleviate problems caused by these disruptions and breaches. Any of these events could damage our reputation and have a material adverse effect on our business, financial condition, results of operations and cash flows.



Item 1B.Unresolved Staff Comments

Item 1B. Unresolved Staff Comments
None.

Item 3.Legal Proceedings

Item 3. Legal Proceedings
We are subject to various routine legal proceedings in the normal conduct of our business primarily involving commercial claims, workers’ compensation claims, and claims for personal injury under the general maritime laws of the United States and the Jones Act. While the outcome of these lawsuits, legal proceedings and claims cannot be predicted with certainty, management believes that the outcome of any such proceedings, even if determined adversely, would not have a material adverse effect on our financial position, results of operations or cash flows.

Item 4.Mine Safety Disclosures

Item 4. Mine Safety Disclosures
None.

Item 4A. Executive Officers of the Registrant

Listed below are the names, ages and offices held by each of our executive officers as of March 5, 2015.2, 2017. All officers serve at the pleasure of our Board of Directors.

Name

 Age 

Position

Kirk J. Meche

 5254 President, Chief Executive Officer and Director

Jeffrey M. Favret

David S. Schorlemer		 5350 Executive Vice President, Chief Financial Officer, Treasurer and SecretaryTreasurer

Todd F. Ladd .

 4850 Executive Vice President and Chief Operating Officer

Kirk J. Meche became Chief Executive Officer in January 2013. Mr. Meche has served as President since January 2009. He served as Chief Operating Officer from January 2009 to December 2012. Mr. Meche served as the Executive Vice President – Operations from 2001 to 2009. Mr. Meche was President and Chief Executive Officer of Gulf Marine from February 2006 to October 2006. Mr. Meche served as President and Chief Executive Officer of Gulf Island, L.L.C. from February 2001 until January 2006. Prior to that, Mr. Meche served as President and Chief Executive Officer of Southport, Inc., a wholly-owned fabrication subsidiary of the Company, from 1999 to 2001. Mr. Meche was a project manager of the Company from 1996 to 1999. Mr. Meche held various engineering positions for J. Ray McDermott, Inc. from 1985 to 1996.

Jeffrey M. FavretDavid S. Schorlemer became Executive Vice President of Finance, Chief Financial Officer and Treasurer on January 3, 2017. Mr. Schorlemer has over 20 years experience as a financial or other senior officer in May 2013.the energy services industry. Prior to joining the Company, Mr. Favret became Secretary in May 2014Schorlemer served as Chief Financial Officer of GR Energy Services Management, L.P., an energy service company delivering completion and was appointedproduction solutions to the United States and Latin American markets. From 2004 to 2015, Mr. Schorlemer served as Executive Vice President in February 2015.and Chief Financial Officer of Stallion Oilfield Holdings, Inc., an energy service company providing upstream, midstream and industrial services to its customers. Mr. Favret has worked with companies in oil and gas exploration and production, vessel construction, offshore drilling construction and offshore vessel/marine transportation industries, among others. Mr. Favret previouslySchorlemer served as DirectorVice President - Finance and Chief Financial Officer of Finance,Q Services, Inc. from 1997 until Q Services merged with Key Energy Infrastructure Segment,Services, Inc. in 2002. Following the merger, Mr. Schorlemer served as Vice President - Marketing & Strategic Planning of FMC Technologies,Key Energy Services, Inc., a leading global provider of technology solutions for the energy industry, from May 2012 to May 2013. until 2004. Mr. FavretSchorlemer also served as the Chief Accounting Officer for Trico Marine Services, Inc., a provider of marine support vessel and subsea servicesConsulting Project Manager with Accenture PLC from 1991 to the offshore oil and gas industry, from April 2010 to May 2012. Prior to that, Mr. Favret served as Director (Partner) of the accounting firm Postlethwaite & Netterville, and in various roles at Ernst & Young in its Assurance and Advisory practice.1997.

Todd F. Ladd became Chief Operating Officer in February 2014 and was appointed Executive Vice President in February 2015. Mr. Ladd previously served as Vice President and General Manager of the Company since July 2013. Mr. Ladd has over 25 years industry experience in the offshore fabrication sector. From 2001 to 2013, Mr. Ladd served as a partner and Senior Project Manager with Paloma Energy Consultants, an offshore construction project management firm. From April 1996 to August 2001, Mr. Ladd served as a Project Manager for Gulf Island, L.L.C. Mr. Ladd also served as Production Engineer and Facility Engineer at McDermott Marine Construction from January 1988 through March 1996.



PART II

Item 5.Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities

Item 5. Market for Registrant's Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities
Our common stock is traded on the Nasdaq Global Select Market, under the symbol “GIFI.” As of March 5, 2015,2, 2017, we had approximately 3,2003,139 holders of record of our common stock.

The following table sets forth the high and low sale prices per share of the common stock, as reported by The Nasdaq Stock Market LLC, and the amount of cash dividends declared per share of our common stock, for each fiscal quarter of the two most recent fiscal years.

   High   Low   Dividend 

Fiscal Year 2014

      

First Quarter

  $23.89    $18.06    $.10  

Second Quarter

   24.01     18.10     .10  

Third Quarter

   21.99     17.11     .10  

Fourth Quarter

   23.57     16.43     .10  

Fiscal Year 2013

      

First Quarter

  $25.49    $20.20    $.10  

Second Quarter

   22.63     18.76     .10  

Third Quarter

   25.00     18.92     .10  

Fourth Quarter

   26.82     21.85     .10  

 High Low Dividend
Fiscal Year 2016     
First Quarter$10.21
 $7.78
 $0.01
Second Quarter7.93
 6.37
 0.01
Third Quarter9.47
 6.80
 0.01
Fourth Quarter$12.75
 $9.25
 $0.01
Fiscal Year 2015     
First Quarter$20.05
 $12.85
 $0.10
Second Quarter16.11
 10.03
 0.10
Third Quarter13.26
 9.05
 0.10
Fourth Quarter$13.00
 $8.95
 $0.10
In each quarter of 2014,2016, our Board of Directors declared a dividend of $0.10$0.01 per share on the shares of our common stock outstanding, totaling $5.9 million.$588,000. On February 26, 2015,23, 2017, our Board of Directors declared a dividend of $0.10$0.01 per share on the shares of our common stock outstanding, payable March 27, 201524, 2017 to shareholders of record on March 13, 2015. Any future10, 2017. Future declaration and payment of dividends, if any, is at the discretion of our Board of Directors and will depend on our retained earnings, working capital requirements and the future operation and growth of our business and other factors deemed relevant by the Board of Directors.

Issuer Purchases of Equity Securities

The following table sets forth shares of our common stock we repurchased during the three-month period ended December 31, 2014.

          Current Program 

Period

  Total
Number of
Shares
Purchased		  Average
Price
Paid per
Share		   Total Number of
Shares Purchased
as Part of Publicly
Announced Plans
or Programs		   Maximum
Number of Shares
that May Yet Be
Purchased Under the
Plans or Programs		 

October 1 to 31, 2014

   —      —       —       —    

November 1 to 30, 2014

   2,374   $19.51     —       —    

December 1 to 31, 2014

   9,820   $20.71     —       —    
  

 

 

    

 

 

   

Total

   12,194(a)  $20.48     —       —    
  

 

 

    

 

 

   

2016.
       Current Program
Period
Total
Number of
Shares
Purchased
   
Average
Price
Paid per
Share
 
Total Number of
Shares Purchased
as Part of Publicly
Announced Plans
or Programs
 
Maximum
Number of Shares
that May Yet Be
Purchased Under the
Plans or Programs
October 1 to 31, 2016—    —
 —
 —
November 1 to 30, 20161,447    $11.85
 —
 —
December 1 to 31, 20164,179    $12.32
 —
 —
Total5,626 
(a) 
 $12.20
 —
 —
(a)Represents shares repurchased under our applicable stock incentive planwithheld by the Company in order to satisfy employee tax obligations for stock options andvesting of restricted stock awards. We do not have a publicly announced share repurchase program.

On July 30, 2015, our Board of Directors authorized the Company to repurchase up to $10.0 million in shares of our common stock under a share repurchase program that remains in effect through July 30, 2017. Repurchases may be made through open market purchases or in privately negotiated transactions at such times and in such amounts as management deems appropriate, depending on market conditions and other factors. The repurchase program does not obligate the Company to acquire any particular amount of common stock and may be modified, suspended or discontinued at any time. To date, we have made no repurchases of our common stock. Due to the severity of the industry downturn, our Board of Directors approved a temporary suspension of our stock repurchase program in an effort to conserve cash.



Information as to the securities authorized for issuance under our equity compensation plans is incorporated herein by reference to Item 12 of this report on Form 10-K.

Stock Performance Graph

The following graph compares the cumulative total shareholder return on our common stock from December 31, 20092011 to December 31, 2014,2016, with the cumulative total return of the Standard & Poor’s 500 Index and the Standard & Poor’s 500 Oil & Gas Equipment & Services Index for the same period. The returns are based on an assumed investment of $100 on January 1, 20102012 at closing prices on December 31, 20092011 in our common stock and in each of the indexes and on the assumption that dividends were reinvested.

Total Return To Shareholders

(Includes reinvestment of dividends)

       ANNUAL RETURN PERCENTAGE
Years Ending		 

Company / Index

      Dec 10   Dec 11   Dec 12   Dec 13   Dec 14 

Gulf Island Fabrication, Inc.

     34.27     4.51     -16.45     -1.66     -14.85  

S&P 500 Index

     15.06     2.11     16.00     32.39     13.69  

S&P 500 Oil & Gas Equipment & Services

     39.28     -11.68     0.00     30.65     -7.80  
   Base
Period
Dec  09		   INDEXED RETURNS
Years Ending		 

Company / Index

    Dec 10   Dec 11   Dec 12   Dec 13   Dec 14 

Gulf Island Fabrication, Inc.

   100     134.27     140.32     117.25     115.30     98.18  

S&P 500 Index

   100     115.06     117.49     136.30     180.44     205.14  

S&P 500 Oil & Gas Equipment & Services

   100     139.28     123.01     123.01     160.71     148.18  

   
ANNUAL RETURN PERCENTAGE
Years Ending
Company / Index  Dec 12 Dec 13 Dec 14 Dec 15 Dec 16
Gulf Island Fabrication, Inc.  (16.45) (1.66) (14.85) (44.22) 14.30
S&P 500 Index  16.00 32.39 13.69 1.38 11.96
S&P 500 Oil & Gas Equipment & Services  — 30.65 (7.80) (18.75) 31.93
 
Base
Period
Dec  11
 
INDEXED RETURNS
Years Ending
Company / IndexDec 12 Dec 13 Dec 14 Dec 15 Dec 16
Gulf Island Fabrication, Inc.100 83.55 82.17 69.97 39.03 44.61
S&P 500 Index100 116.00 153.57 174.60 177.01 198.18
S&P 500 Oil & Gas Equipment & Services100 100.00 130.65 120.46 97.87 129.13


Item 6.Selected Financial Data

Item 6. Selected Financial Data
The following table sets forth selected historical financial data as of the dates and for the periods indicated. The historical financial data for each year in the five-year period ended December 31, 20142016 is derived from our audited financial statements. The following information should be read in conjunction with “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and our financial statements and notes thereto included elsewhere in this report on Form 10-K.

   Years Ended December 31, 
   2014  2013  2012  2011  2010 
   (in thousands, except per share data) 

Income Statement Data:

      

Revenue

  $506,639   $608,326   $521,340   $307,832   $248,286  

Cost of revenue:

      

Contract costs

   462,083    584,665    502,999    295,614    225,015  

Provision for losses on contract receivables

   —      —      14,501    —      —    

Asset impairments

   —      —      —      7,690    —    
  

 

 

  

 

 

  

 

 

  

 

 

  

 

 

 

Total cost of revenue

   462,083    584,665    517,500    303,304    225,015  
  

 

 

  

 

 

  

 

 

  

 

 

  

 

 

 

Gross profit

   44,556    23,661    3,840    4,528    23,271  

General and administrative expenses

   20,609    11,555    9,806    8,187    7,947  
  

 

 

  

 

 

  

 

 

  

 

 

  

 

 

 

Operating income (loss)

   23,947    12,106    (5,966)   (3,659)   15,324  

Net interest income (expense)

   (24)   (234)   433    902    5,021  

Other, income (expense)

   (99)   (337)   128    309    1,014  
  

 

 

  

 

 

  

 

 

  

 

 

  

 

 

 

Income (loss) before income taxes

   23,824    11,535    (5,405)   (2,448)   21,359  

Income taxes

   8,504    4,303    (1,314)   (644)   8,266  
  

 

 

  

 

 

  

 

 

  

 

 

  

 

 

 

Net income (loss)

  $15,320   $7,232   $(4,091)  $(1,804)  $13,093  
  

 

 

  

 

 

  

 

 

  

 

 

  

 

 

 

Income Summary Data:

      

Basic earnings (loss) per share—common shareholders

  $1.05   $0.50   $(0.29)  $(0.13)  $0.90  
  

 

 

  

 

 

  

 

 

  

 

 

  

 

 

 

Diluted earnings (loss) per share—common shareholders

  $1.05   $0.50   $(0.29)  $(0.13)  $0.90  
  

 

 

  

 

 

  

 

 

  

 

 

  

 

 

 

Basic weighted-average common shares

   14,505    14,463    14,400    14,351    14,318  
  

 

 

  

 

 

  

 

 

  

 

 

  

 

 

 

Diluted weighted-average common shares

   14,505    14,469    14,400    14,351    14,329  
  

 

 

  

 

 

  

 

 

  

 

 

  

 

 

 

Cash dividend declared per common share

  $0.40   $0.40   $0.40   $0.24   $0.04  
  

 

 

  

 

 

  

 

 

  

 

 

  

 

 

 

   As of December 31, 
   2014   2013   2012   2011   2010 
   (in thousands) 

Balance Sheet Data:

          

Working capital

  $99,730    $89,721    $81,330    $101,926    $112,111  

Property, plant and equipment, net

   224,777     223,555     229,216     216,722     197,652  

Total assets

   397,943     426,234     403,495     395,935     334,856  

Debt

   —       —       —       —       —    

Operating Data:

          

Direct labor hours worked for the year ended December 31, (1)

   3,646     4,060     4,768     2,715     2,403  

Backlog as of December 31, (2)

          

Direct labor hours

   1,654     3,256     4,372     4,609     3,837  

Dollars

  $184,667    $358,732    $536,950    $614,481    $486,146  

 Years Ended December 31,
 2016 2015 2014 2013 2012
 (in thousands, except per share data)
Income Statement Data:         
Revenue$286,326
 $306,120
 $506,639
 $608,326
 $521,340
Cost of revenue:         
Contract costs261,473
 321,276
 462,083
 584,665
 502,999
Provision for losses on contract receivables—
 —
 —
 —
 14,501
Total cost of revenue261,473
 321,276
 462,083
 584,665
 517,500
Gross profit (loss)24,853
 (15,156) 44,556
 23,661
 3,840
General and administrative expenses19,670
 16,256
 17,409
 11,555
 9,806
Asset impairment—
 7,202
 3,200
 —
 —
Operating income (loss)5,183
 (38,614) 23,947
 12,106
 (5,966)
Net interest (expense) income(308) (139) (24) (234) 433
Other, income (expense)681
 20
 (99) (337) 128
Income (loss) before income taxes5,556
 (38,733) 23,824
 11,535
 (5,405)
Income taxes2,041
 (13,369) 8,504
 4,303
 (1,314)
Net income (loss)$3,515
 $(25,364) $15,320
 $7,232
 $(4,091)
Income Summary Data:         
Basic and diluted earnings (loss) per share—common shareholders$0.24
 $(1.75) $1.05
 $0.50
 $(0.29)
Basic and diluted weighted-average common shares14,631
 14,546
 14,505
 14,463
 14,400
Cash dividend declared per common share$0.04
 $0.40
 $0.40
 $0.40
 $0.40


 As of December 31,
 2016 2015 2014 2013 2012
 (in thousands)
Balance Sheet Data:         
Working capital$78,012
 $77,968
 $97,084
 $89,721
 $81,330
Property, plant and equipment, net206,222
 200,384
 224,777
 223,555
 229,216
Total assets322,408
 316,923
 395,297
 426,234
 403,495
Debt—
 —
 —
 —
 —
Cash Flow Data:         
Net cash provided by operating activities14,351
 10,615
 32,110
 38,003
 11,037
Net cash provided by (used in) investing activities2,698
 (6,007) (26,729) (20,802) (35,890)
Net cash (used in) financing activities(710) (5,865) (5,865) (5,520) (5,546)
Operating Data:         
Direct labor hours worked for the year ended December 31 (1)
2,784
 2,655
 3,646
 4,060
 4,768
Backlog as of December 31 (2)
         
Direct labor hours1,265
 1,914
 1,654
 3,256
 4,372
Dollars$132,972
 $232,411
 $184,667
 $358,732
 $536,950
(1)Direct labor hours are hours worked by employees directly involved in the production of our products.
(2)Our backlog is based on management’s estimate of the number of direct labor hours required to complete and the remaining revenues to be recognized with respect to those projects for which a customer has authorized us to begin work or purchase materials or services pursuant to written contracts, letters of intent or other forms of authorization. The backlog as of each year end also includes commitments received subsequent to December 31 of each year as described in Item 17 of this reportReport on Form 10-K.



Item 7.
Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations

Introduction and OutlookAnalysis of Financial Condition and Results of Operations

Executive Overview and Summary
Our Business
We are a leading fabricator of complex steel structures and marine vessels used in energy extraction and production, petrochemical and industrial facilities, power generation and alternative energy projects and shipping and marine transportation operations. We also provide related installation, hookup, commissioning, repair and maintenance services with specialized crews and integrated project management capabilities. We are currently fabricating complex modules for the construction of a new petrochemical plant, completing newbuild construction of two technologically advanced offshore support and two multi-purpose service vessels and recently fabricated wind turbine pedestals for the first offshore wind power project in the United States. We also constructed one of the largest liftboats servicing the Gulf of Mexico ("GOM"), one of the deepest production jackets in the GOM and the first SPAR fabricated in the United States. Our customers include U.S. and, to a lesser extent, international energy producers, petrochemical, industrial, power and marine operators.

We operate our business through three operating divisions: Fabrication, Shipyards and Services which are further discussed below. We use modern welding and fabrication technology, and all of our projects are manufactured in accordance with industry standards, specifications and regulations, including those published by the American Petroleum Institute, the American Welding Society, the American Society of Mechanical Engineers, the American Bureau of Shipping and the United States Coast Guard. The quality management systems of our operating divisions are certified as ISO 9001-2008 quality assurance programs.

Fabrication Division

- Our Fabrication division primarily fabricates structures such as offshore drilling and production platforms and other steel structures for customers in the oil and gas industry including jackets and deck sections of fixed production platforms along with pressure vessels. Our Fabrication division also fabricates structures for alternative energy customers (such as the five jackets and piles we constructed for a shallow water wind turbine project off the coast of Rhode Island during 2015) as well as modules for petrochemical facilities. We perform these activities out of our fabrication yards in Houma, Louisiana, and Aransas Pass and Ingleside, Texas.


Shipyards Division - Our Shipyards division primarily fabricates and repairs marine vessels including offshore supply vessels, anchor handling vessels, liftboats, tugboats, towboats, barges and other marine vessels. Our Shipyards division also constructs and owns dry docks to lift marine vessels out of the water in order to make repairs or modifications. Our marine repair activities include steel repair, blasting and painting services, electrical systems repair, machinery and piping system repairs and propeller, shaft and rudder reconditioning. Our Shipyards division also performs conversion projects that consist of lengthening or modifying the use of existing vessels to enhance their capacity or functionality. We perform these activities out of our shipyards in Houma, Jennings and Lake Charles, Louisiana.

Services Division - Our Services division primarily provides interconnect piping services on offshore platforms and inshore structures. Interconnect piping services involve sending employee crews to offshore platforms in the Gulf of Mexico to perform welding and other activities required to connect production equipment, service modules and other equipment on a platform. We also contract with oil and gas companies that have platforms and other structures located in the inland lakes and bays throughout the southeastern United States for various on-site construction and maintenance activities. In addition, our Services division fabricates packaged skid units and perform various municipal and drainage projects, such as pump stations, levee reinforcement, bulkheads and other public works projects for state and local governments. We perform these services at our customer's facilities or out of our Houma Service Yard.

Known Trends and Uncertainties

Our results of operations are affected primarily by (i) theby:

The level of exploration and development activity maintained by oil and gas exploration and production companies in the Gulf of Mexico, and to a lesser extent, foreign locations throughout the world, (ii) our ability to manage contracts to successful completion, and (iii) our ability to win contracts through competitive bidding or alliance/partnering arrangements.overseas locations. The level of exploration and development activity throughout the energy industry is related to several factors, including trends in oil and gas prices, expectations of future oil and gas prices, changes in technology and changes in the regulatory environment, including new permitting processesenvironment.

The level of petrochemical facility construction and increased regulation imposed on domestic oilimprovements.

Our ability to win contracts through competitive bidding or alliance/partnering arrangements.



Our ability to effectively manage contracts to successful completion.

Oil and gas exploration byprice volatility has created significant uncertainty in global equity prices and overall market fundamentals within the Bureau of Ocean Energy, Regulation and Enforcement.

The slowdown inenergy industry. During 2016, our industry as a result of the downturn in oil prices presents challenges in the near term, particularly as it relates to shallow water activity. In 2014, the pace of growth in overall capital spendingcustomers in the global oil and gas industry decreased. From 2010continued to 2013,reduce capital spending relative to the already reduced spending levels in 2015. This has also negatively impacted the marine industry experienced an approximate 12% compound annual growth rate in upstream capital spending; in 2014, overall spending was only up 3% from the prior year. In recent years, capex growth, especially in North America, was fueled primarily by independentthat supports offshore exploration and production companies; however, even before the recent reductionproduction. This had an adverse effect on our overall backlog levels and created challenges with respect to our ability to operate our fabrication facilities at desired utilization levels.


Beginning in December of 2016, we have seen improvement with current oil prices many independent producers reduced their offshore positions for the relative safety and predictability of onshore shale projects. In the latter part of 2014, the industry began to experience decreased spending by larger, integrated companies, particularly in the mid $50's/bbls with announced production cuts by OPEC. We have also been successful in obtaining limited new backlog through recent awards; however, the revenue from recent awards may not be realized until later in 2017, and these awards were received during a period of very competitive pricing with low margins. Oil and gas producers are expected to cautiously increase drilling activity during 2017; however, such increases may not materialize into significant offshore sector. The recent downturn in oil prices introduces additional uncertaintyspending as producers may choose to short- and long-term demand in offshorefocus on land-based oil and gas project activity.

production through newly discovered shale finds. Accordingly, we believe that the current environment continues to remain limited with relatively few new bids which presents challenges in the near term. Even if the oil and gas industry experiences a rapid recovery, we believe that there would be a lag of several months before a recovery would optimize the utilization of our fabrication yards.


We are quickly respondingcontinue to expected near-termrespond to decreases in capital spending by our customers by reducing our own discretionary spending. Since the beginning of 2016, wage adjustments along with employee benefit reductions and capital spending.overall cost reductions in all of our facilities have been implemented along with continued examination of all potential cost reductions associated with our business divisions. We continuously adjusthave reduced the level of our workforce based on anticipated future backlog. As webooked work through existing backlog, depending on the durationin all of the downturn, we may needour facilities and will continue to make additional reductions in labor in the second halfdo so, as necessary. We reduced our capital expenditures and continue to evaluate opportunities to dispose of 2015, commensurate with the level of activity in our fabrication yards. assets that are either underperforming or not expected to provide sufficient long-term value.

From a marketing perspective, we are increasinghave increased our focus on obtaining marine fabrication projects outside of the oil and repair work,gas sector, including certain large petrochemical plant module work, alternative energy fabrication projects, such as wind farm projects similar to our existing project off the coast of Rhode Island, and other activitiesprojects that are less susceptible to fluctuations in oil and gas prices.

We intend to use this periodare currently fabricating complex modules for the construction of reduced activity that we anticipate as a resultnew petrochemical plant and fabricated wind turbine pedestals in 2015 for the first offshore wind power project in the United States.  Opportunities for shipyard-related projects remain largely outside of the slowdownoil and gas sector. Opportunities for our Services division are expected to remain consistent with current levels.


With no debt and $51.2 million in customer spendingcash at December 31, 2016, we will continue to conserve our cash due to the uncertainty of both the severity and duration of the current oil and gas market downturn. We will, however, continue to explore opportunities for mergers or acquisitions that may exist. Our recent acquisition of substantially all of LEEVAC's assets, as further discussed below, has provided assets and operations that are complementary to our existing marine fabrication business at an opportunity to further strengthen our execution improvement strategies, including modernizing certain information technology systems.attractive value. We believe that our strong balance sheet, levels of cash, and access to capital provides us with the strength to persevere throughout this cycle.

Indifficult business environment.


Operational Achievements During 2016
On January 1, 2016, we acquired substantially all of the long term, demandassets and assumed certain specified liabilities of LEEVAC. The purchase price for our products and services will,the acquisition was $20.0 million, subject to a large extent, continueworking capital adjustment. The transaction added approximately $121.2 million of incremental contract backlog. Strategically, the acquisition expands our marine fabrication and repair and maintenance presence in the GOM market and further diversifies our fabrication capabilities. See also Note 2 of the Notes to dependConsolidated Financial Statements.

In June 2016, we completed the fabrication and assembly of an 1,100-ton compression module for a major international engineering/design company associated with a gas processing plant for onshore Trinidad operations.

On February 6, 2017, we completed and duly tendered for delivery an offshore supply vessel related to the backlog that we acquired in the LEEVAC transaction.

We completed the remaining two of three tow boats for an inland towing customer that commenced in the third quarter of 2014. The first tow boat was completed during the fourth quarter of 2015.

In December 2016, we completed and loaded-out a production platform jacket and piles for a customer in the international offshore natural gas production business. The jacket and piles were subsequently installed by the customer in February 2017.



The Potential Sale of Our South Texas Properties
On February 23, 2017, our Board of Directors approved a recommendation of management to consolidate all of our fabrication operations in South Texas with our fabrication operations in Houma, Louisiana, and place our properties located in Aransas Pass and Ingleside, Texas, up for sale. Our Texas South Yard in Ingleside, Texas, is located on the timingnorthwest corner of changes in prices for oil and gasthe U.S. Intracoastal Waterway and the capital spend decisionsCorpus Christi Ship Channel. The 45-foot deep Corpus Christi Ship Channel provides direct and unrestricted access to the Gulf of oilMexico. Our Texas North Yard in Aransas Pass, Texas, is located along the U.S. Intracoastal Waterway and gas explorationis approximately three miles north of the Corpus Christi Ship Channel. See also "Our Fabrication Facilities in Ingleside and production companies, which is difficultAransas Pass, Texas" in Item 1 of this Report. The net book value of property, plant and equipment for these assets was $107.6 million at December 31, 2016. These properties are currently underutilized and represent excess capacity within our Fabrication division. We are working to predict.

wind down all fabrication activities at these locations and re-allocate remaining backlog and workforce to our Houma fabrication operations as necessary. As a result of the decision to place our South Texas properties for sale and the underutilization currently being experienced, we expect to incur costs associated with the maintaining of the facility through its sale that will not be recoverable. These costs include insurance, general maintenance of the property in its current state, property taxes, and retained employees.


We do not expect the sale of these properties to impact our ability to service our deepwater customers or operate our Fabrication division. For additional information, see our Risk Factors listed in Item 1A of this Report.

Backlog

Our backlog is based on management’s estimate of the direct labor hours required to complete, and the remaining revenue to be recognized with respect to those projects a customer has authorized us to begin work or purchase materials or services pursuant to written contracts, letters of intent or other forms of authorization. As engineering and design plans are finalized or changes to existing plans are made, management’s estimate of the direct labor hours required to complete a project and the price of a project at completion is likely to change.

All projects currently included in our backlog generally are subject to suspension, termination, or a reduction in scope at the option of the customer, although the customer is generally required to pay us for work performed and materials purchased through the date of termination, suspension, or reduction in scope. In addition, customers have the ability to delay the execution of projects.

As



A comparison of our backlog as of December 31, 2014, we had a revenue backlog2016, September 30, 2016 and as of $184.7 million and a labor backlogDecember 31, 2015 is as follows (amounts in thousands, except for percentages):
 
As of December 31, 2016 (1)
 As of September, 2016 
As of December 31, 2015 (2)
 $'sLabor hours $'sLabor hours $'sLabor hours
Fabrication$65,444
707 $84,940
841 $62,006
724
Shipyards59,771
457 78,886
582 131,660
886
Services7,757
101 17,386
163 38,761
304
Intersegment eliminations—
— —
— (16)—
Total Backlog$132,972
1,265 $181,212
1,586 $232,411
1,914
         
 NumberPercentage NumberPercentage NumberPercentage
Major customerstwo80.5%
(3) 
three75.3% five76.1%
         
 $'sPercentage $'sPercentage $'sPercentage
Deepwater locations$2,743
2.1% $15,775
8.7% $47,077
20.3%
Foreign locations4,774
3.6% 13,519
7.5% 26,184
11.3%
         
Backlog that is expected to be recognized in revenue during:
 $'sPercentage      
2017$130,412
98.1%
(4) 
     
20182,560
1.9%
(4) 
     
Total Backlog$132,972
100%      
1) Backlog as of approximately 1.7 million man-hours remaining to work, includingDecember 31, 2016 includes commitments received through February 25, 2015 compared to revenue backlog of $358.7 million and a labor backlog of 3.3 million man-hours reported as of December 31, 2013.22, 2017. We exclude suspended projects from contract backlog that are expected to be suspended more than twelve months because resumption of work and timing of revenue recognition for these projects are difficult to predict. AsOur amount of December 31, 2014, we had one suspended projectbacklog that was acquired in the LEEVAC transaction includes $3.8 million of non-cash deferred revenue related to the fabricationpurchase price fair value of a shallow water jacket. The project was 44% completethe contracts acquired in the LEEVAC transaction and included in deferred revenue in our Consolidated Balance Sheet at December 31, 2014 and the remaining backlog was $2.6 million. We were paid in full for all work completed for this project.

Of our backlog at December 31, 2014,

2016.
2)Backlog as of December 31, 2015 includes commitments received through February 19, 2016 and $112.0 million of newbuild construction backlog that was acquired in the LEEVAC transaction as reported in our 2015 Form 10-K.

64.2% was for three customers as compared to 69.1% for three customers at December 31, 2013.

$70.1 million, or 38.0%, represented projects destined for deepwater locations compared to $224.5 million, or 62.6%, at December 31, 2013.

$5.3 million, or 2.9%, represented projects destined for foreign locations compared to 28.7 million, or 8.0%, at December 31, 2013.

3) Projects for our threetwo largest customers consistedconsist of the following:

(i) jackets, piles, and topside for a deepwater Gulf of Mexico projecttwo large multi-purpose supply vessels for one customer which commencedin our Shipyards division, from contracts we assumed in the secondLEEVAC transaction and fourth quarters of 2013, respectively; (ii) five jackets and piles for a shallow water wind turbine project located off the coast of Rhode Island, that commenced in the fourth quarter of 2014; and (iii) three tow boats for an inland towing customer that commenced in the third quarter of 2014. The deepwater project is scheduled to be completed during the third quarter of 2015; two of the jackets, piles and deck projects are scheduled to be completed during the second quarter of 2015 and the last three jackets, piles and deck projects are scheduled to be completed during the third quarter of 2015; the first tow boat is expected to be completed during the third quarter of 2015, the second tow boat is expected towill be completed during the first and second quarter of 2016,2018; and
(ii) the third tow boat is expectedfabrication of four modules associated with a U.S. ethane cracker project in our Fabrication division to be completed during the third quarter of 2016.

Depending on the size of the project, the termination, postponement, or reduction in scope of any one project could significantly reduce our backlog, and could have a material adverse effect on revenue, net income and cash flow. For additional information, see Note 1 in the Notes to Consolidated Financial Statements “Assets held for sale” and Item 1A. Risk Factors – “Our backlog is subject to change as a result of changes to management’s estimates, suspension or termination of projects currently in our backlog or our failure to secure additional projects. Our revenue, net income and cash flow could be adversely affected as a result of changes to our backlog.”

As of December 31, 2014, we expected to recognize revenues from our backlog of approximately

late 2017.

$176.7 million, or 95.7%, during the calendar year 2015, and

$8.0 million, or 4.3%, during calendar year 2016.

4) The timing of our recognition of the revenue backlog as presented above is based on management estimates of the application of the direct labor hours during the current projected timelines to complete the projects in our backlog. Certain factors and circumstances, as mentioned above, could cause changes in the period when the backlog is recognized as revenue.

Based

Depending on the activitysize of the major oilproject, the termination, postponement, or reduction in scope of any one project could significantly reduce our backlog and gas companiescould have a material adverse effect on revenue, net income and certain engineering companies, we expect bids for deepwater projects to be availablecash flow. For additional information, see Note 1 in the second halfNotes to Consolidated Financial Statements and Item 1A. Risk Factors – “Our backlog is subject to change as a result of 2015 withchanges to management’s estimates, suspension or termination of projects currently in our backlog or our failure to secure additional projects. Our revenue, net income and cash flow could be adversely affected as a higher levelresult of bidding activity in the fourth quarter of 2015. Bidding activity for non-traditional Gulf of Mexico (GOM) marine related projects, GOM shallow water projects, and ancillary work associated with deepwater structures is expectedchanges to increase in the second half of 2015.

our backlog.”



Workforce

Our workforce varies based on the level of ongoing fabrication activity at any particular time. During 2016, we made reductions in our workforce (primarily at our Fabrication and Shipyard facilities) in response to decreases in the amount of fabrication work. On January 1, 2016, we hired 380 employees with the LEEVAC transaction representing substantially all of the former LEEVAC employees. As of December 31, 20142016 and 2013,2015, we had approximately 1,7001,178 and 1,9001,255 employees, respectively. Additionally, we willWe use contract labor when required to meet customer demand. The number of contract laborers we used decreasedincreased to 24792 in 20142016 as compared to 46771 in 2013.2015. None of our employees are employed pursuant to a collective bargaining agreement, and we believe our relationship with our employees is good. In an effort to maintain our current workforce and attract new employees in period of high activity, we have enhanced several incentive programs and expanded our training facility. For additional information, see Item 1A- Risk Factors – “We might be unable to employ a sufficient number of skilled workers.”

Man-hours

Labor hours worked were 3.62.8 million, 4.12.7 million and 4.83.6 million for the years ending December 31, 2014, 20132016, 2015 and 20122014 respectively. The decreaseincrease in man-hourslabor hours worked in 20142016 relative to 20132015 was primarily attributable to the contracts assumed in the LEEVAC transaction, partially offset by decreases in overall decreased levels of activity as a result of the completiona decline in our oil and gas fabrication activity.
As disclosed in "The Potential Sale of topsidesOur South Texas Properties" above, our Board of Directors approved a recommendation of management to place our South Texas properties up for two large deepwater customers in 2013,sale on February 23, 2017. We are working to wind down all fabrication activities at our South Texas properties and a Spar Hull for a large deepwater customer in the first quarter of 2014.

re-allocate remaining backlog and workforce to our Houma Fabrication Yard as necessary.

Critical Accounting Policies

Our consolidated financial statements are prepared in accordance with accounting principles generally accepted in the United States, which require us to make estimates and assumptions. We believe that of our significant accounting policies (see Note 1 in the Notes to Consolidated Financial Statements), the following involves a higher degree of judgment and complexity:

Revenue Recognition

The majority of our revenue is recognized on a percentage-of-completion basis based on the ratio of direct labor hours actually performed to date compared to the total estimated direct labor hours required for completion. Accordingly, contract price and cost estimates are reviewed monthly as the work progresses, and adjustments proportionate to the percentage of completionpercentage-of-completion are reflected in revenue for the period when such estimates are revised. If these adjustments were to result in a reduction of previously reported profits, we would have to recognize a charge against current earnings, which may be significant depending on the size of the project or the adjustment.

Some contracts include a total

Profit incentives are included in revenue when their realization is probable. Claims for extra work or partial reimbursementchanges in scope of work are included in revenue when the amount can be reliably estimated and collection is probable. To the extent work from changes in scope have been approved for scope, but not as to us of anyprice, revenue is recognized up to cost incurred. Changes in job performance, job conditions, and estimated profitability, including those arising from contract penalty provisions, and final contract settlements may result in revisions to costs associated with specific capital projects required by the fabrication process. If a particular capital project provides future benefits to us, the cost to build the capital project will be capitalized, and the revenue for the capital project will increase the estimated profitincome and are recognized in the contract.

period in which the revisions are determined. For the years ended December 31, 2016, 2015 and 2014, there was no significant revenue related to unapproved change orders or claims.

Contract costs include all direct material, labor and subcontract costs and those indirect costs related to contract performance, such as indirect labor, supplies and tools. Also included in contract costs are a portion of those indirect contract costs related to plant capacity, such as depreciation, insurance and repairs and maintenance. These indirect costs are allocated to jobs based on actual direct labor hours worked. Profit incentives are included in
Some contracts include a total or partial reimbursement to us of any costs associated with specific capital projects required by the fabrication process. If a particular capital project provides future benefits to us, the cost to build the capital project will be capitalized, and the revenue when their realization is probable. Claims for extra work or changes in scope of work are included in revenue when the amount can be reliablycapital project will increase the estimated and collection is probable. Changes in job performance, job conditions, and estimated profitability, including those arising from contract penalty provisions, and final contract settlements may result in revisions to costs and income and are recognizedprofit in the period in which the revisions are determined.

At December 31, 2014, we had no revenue related to unapproved change-orders on projects. At December 31, 2013, we recorded revenue totaling $0.1 million related to certain change-orders on two projects which were approved as to scope but not price. At December 31, 2013, we recorded revenue totaling $3.7 million related to re-measure units and quantities on a unit rate contract. At December 31, 2012, we recorded

revenue totaling $5.2 million related to certain change-orders on four projects which were approved as to scope but not price. At December 31, 2012, we also recorded revenue totaling $7.7 million related to re-measure units and quantities on a unit rate contract. All unapproved items as of December 31, 2013 and 2012, respectively, were subsequently approved in the normal course of business.

Provisions for estimated losses on uncompleted contracts are made in the period in which such losses are determined. We recognized contract losses of $6.6$1.8 million, $30.8$33.9 million, and $12.5$6.6 million, for the years ended December 31, 2014, 2013,2016, 2015 and 2012,2014, respectively. Contract losses for the year ended December 31, 2016 were primarily attributable to our inability to absorb fixed costs due to decreases in expected oil and gas fabrication activity and competitive pricing.
Contract losses for the year ended December 31, 2015 were primarily related to a $24.5 million decrease in the contract price due to final weight re-measurements and our inability to recover certain costs on disputed change orders related to a large deepwater project delivered during the fourth quarter of 2015. In addition we accrued contract losses of approximately $9.4 million resulting from increases in our projected unit labor rates of our fabrication facilities which were driven by our inability to absorb fixed costs due to decreases in expected oil and gas fabrication activity. Contract losses for the year ended December 31, 2014 of


$6.6 million were primarily related to two tank barge projects for a marine transportation company, platform supply vessels for an offshore marine company and a production platform jacket for a deepwater customer. Contract losses in 2013 were primarily due to our inability to recover certain costs and the de-scoping of one of our major deepwater projects, as further discussed in the “Backlog” section above. Contract losses in 2012 were primarily related to increased man-hours driven by delays in delivery of specification and design changes by a deepwater customer causing out-of-sequence work schedules.

Allowance for Doubtful Accounts

We routinely review individual contracts receivable balances and make provisions for probable doubtful accounts as we deem appropriate. Among the factors considered during the review are the financial condition of our customers and their access to financing, underlying disputes on the account, age and amount of the account and overall economic conditions. Accounts are written off only when all reasonable collection efforts are exhausted.

Our principal customers include major and large independent oil and gas companies and their contractors and marine vessel operators and their contractors. This concentration of customers may impact our overall exposure to credit risk, either positively or negatively, in that customers may be similarly affected by changes in economic or other conditions. Receivables are generally not collateralized; however, in certain instances we obtain collateral to reduce our credit exposure. In the normal course of business, we extend credit to our customers on a short-term basis.

During 2016, the provision for bad debts was approximately $493,000 which is primarily related to uncollected storage rentals from customers within our Fabrication division. During 2015, allowances for bad debts were approximately $44,000. During the fourth quarter of 2014, the Company included an allowance for bad debt in the amount of $3.6 million in connection with negotiations of an outstanding contract receivable balance with a deepwater offshore customer related to a deepwater hull project that was completed during the first quarter of 2014.

At

Fair Value Measurements:
The determination of fair value can require the use of significant judgment and can vary based on the facts and circumstances. See also Note 6 of the Notes to Consolidated Financial Statements.
We evaluate long-lived assets or asset groups used in operations for impairment losses when events and circumstances indicate that the assets or asset groups might not be recoverable. If events and circumstance indicate that the assets or asset groups might not be recoverable, the expected future undiscounted cash flows from the assets or asset groups are estimated and compared with the carrying amount of the assets or asset groups. If the sum of the estimated undiscounted cash flows is less than the carrying amount of the assets or asset groups, an impairment loss is recorded.
An impairment loss is measured by comparing the fair value of the asset or asset group to its carrying amount and recording the excess of the carrying amount of the asset or asset group over its fair value as an impairment charge. An asset group constitutes the minimum level for which identifiable cash flows are principally independent of the cash flows of other asset or liability groups. Fair value is determined based on discounted cash flows or appraised values, as appropriate. Due to the sustained slowdown in our industry as a result of the downturn in oil prices, we continued to identify indicators of impairment at our South Texas properties. We have evaluated the future undiscounted cash flows for the South Texas properties; however, given the uncertainty with respect to those cash flows we have obtained appraisals to determine the fair value of the asset group. We compared the fair value of the asset group to the net realizable value based upon, which did not result in impairment.
As disclosed our "Executive Summary" above, our Board of Directors approved a recommendation to place our South Texas properties up for sale on February 23, 2017.
We measure and record assets held for sale at the lower of their carrying amount or fair value less cost to sell. Assets held for sale at December 31, 2013,2015 consisted of equipment that was subsequently sold during the Company includedfirst quarter of 2016. We estimated the fair value as the actual cash proceeds received less costs incurred to sell. We recorded an allowance for bad debt in the amountimpairment of $0.9 million in connection with a vessel upgrade and outfitting project. The Company collected $0.6 million ofrelated to this balance in connection with a final settlementequipment during the fourth quarter 2014.

Assets Held for Sale

Assets held for sale consist of 2015.

During 2015, we also recorded an impairment of $6.6 million related to a partially constructed topside, related valves, pilingpiping and equipment that we acquired from a customer following its default under a contract for a deepwater project in 2012. Assets held for sale are required to be measured at2012 based on the lower of their carrying amount or fair value less cost to sell. Management determined fairestimated scrap value of these assets withmaterials and reclassified the assistance of third party valuation specialists, assuming the sale of the underlying assets individually or in the aggregate to a willing market participant, including normal ownership risks assumed by the purchaser, and the sale of certain components at scrap value. We estimated fair value relying primarily on the cost approach and applied the market approach where comparable sales transaction information was readily available. The cost approach is based on current replacement or reproduction costs of the subject assets less depreciation attributable to physical, functional, and economic factors. The market approach involves gathering data on sales and offerings of similar assets in order to value the subject assets. This approach also includes an assumption for the measurement of the loss in value from physical, functional, and economic factors. The fairasset’s net realizable value of assets held for sale represent Level 3 fair value measurements (as defined by GAAP),

based primarily$3.7 million to inventory. We intend to use this inventory on the limited availability of market pricing information for either identical or similar items. In connection with its fourth quarter of 2014 assessment of the fair value of the assets held for sale, management determined that its previous estimate of $13.5 million for the fair value of these assets had declined to $10.3 million. As a result, we included infuture construction projects at our income statement within general and administrative expense for the year ended December 31, 2014 an impairment charge of $3.2 million.

During the first quarter of 2014, we entered into an agreement with the manufacturer of certain equipment, representing approximately 50% of the fair value of assets held for sale, whereby the manufacturer agreed to assist with restoration and marketing efforts, in return for a percentage of the sale proceeds. In addition, in 2014, we engaged engineering consultants to assist with the marketing efforts for the assets held for sale.

To date, we have not sold, licensed, or leased any of the equipment subject to the security agreement; however, we continue to actively market the equipment, and believe that the fair value of the assets is recoverable through the eventual disposition of project deliverables. However, the ultimate amount we are able to recover for these assets is dependent upon various factors, including overall market interest in the project deliverables and equipment, which may change in the future. The timing of any sales we are able to consummate and the price we are able to obtain may result in a revision to the recorded fair value amount of any remaining assets held for sale.

Results of Operations

Comparison of the Years Ended December 31, 2014 and 2013

For the twelve-month period ended December 31, 2014, our revenue was $506.6 million compared to $608.3 million for the twelve-month period ended December 31, 2013, a decrease of 16.7%. The following factors contributed to the decrease in revenues for the year ended December 31, 2014 compared to the year ended December 31, 2013:

fabrication facilities.

pass-through costs, as a percentage of revenue, for the twelve-month period ended December 31, 2014 were 48.2% compared to 58.5% for the twelve-month period ended December 31, 2013; and


overall decreased levels of activity as a result of the completion of topsides for two large deepwater customers in 2013, and a Spar Hull for a large deepwater customer in the first quarter of 2014.

The decrease in pass-through costs for the twelve months ended December 31, 2014 primarily relates to higher levels of sub-contracted service costs on our major deepwater projects in 2013. Pass-through costs, as described in Note 12 in the Notes to Consolidated Financial Statements, are included in revenue, but have no impact on the gross profit recognized for that particular period. The decrease in revenue was offset by lower estimated contract losses of $6.6 million for December 31, 2014 compared to $30.8 million for December 31, 2013. These losses are further discussed in “Backlog” above.

For the twelve-month periods ended December 31, 2014 and 2013, gross profit was $44.6 million (8.8% of revenue) and $23.7 million (3.9% of revenue), respectively. Factors contributing to the overall increase in gross profit for the twelve-month period ended December 31, 2014 compared to the twelve-month period ended December 31, 2013 include:

lower contract losses of $6.6 million during the twelve month period ended December 31, 2014 compared to $30.8 million during the twelve-month period ended December 31, 2013 as further explained in “Backlog” above;

a return to traditional jacket and smaller topside shallow water projects during 2014 as compared to 2013; and

a higher level of offshore commissioning and hook-up activity performed on a time and material basis.

Both the offshore connection and hook-up work and execution of the 2014 shallow water projects garnered higher profit margins as compared to our mix of projects performed during 2013, primarily due to (i) certain project improvement initiatives undertaken in 2014, and (ii) the fact that we historically have been able to more effectively control costs associated with these projects as compared to larger, more complex deepwater projects.

Our general and administrative expenses were $20.6 million for the twelve-month period ended December 31, 2014 compared to $11.6 million for the twelve-month period ended December 31, 2013. Factors that contributed to the increase in general and administrative expenses for the twelve months ended December 31, 2014 include:

an impairment charge of $3.2 million in 2014 related to assets held for sale;

a net increase of $2.7 million in bad debt expense;

increases in expenses related to the relocation of our corporate headquarters to Houston, Texas and hiring of additional corporate staff members to support operations;

the addition of three consultants to assist with the marketing efforts for assets held for sale and potential FLNG opportunities; and

increases in expenses associated with an increase in the numbers of directors serving on our board.

Bad debt expense for 2014 included a $3.6 million increase inDuring the fourth quarter related to negotiations of an outstanding contract receivable balance with a customer for a deepwater hull project completed during the first quarter of 2014. At December 31, 2013, the Company included an allowance for bad debt in the amount of $0.9 million in connection with a vessel upgrade and outfitting project. The Company collected $0.6 million of this balance in connection with a final settlement during the fourth quarter 2014.

As further discussed in “Assets held for sale”, under Critical Accounting Policies above, as of December 31, 2014, management determined that its previous estimate of $13.5 million for the fair value of assets held for sale had declined to $10.3 million. As a result,million, and we included in general and administrative expenses in our income statementrecorded an impairment charge of $3.2 million for the year ended December 31, 2014 an impairment charge2014.




Purchase Price Accounting - LEEVAC Transaction

On January 1, 2016, we acquired substantially all of $3.2 million.

We had net interest expensethe assets and assumed certain specified liabilities of $24,000LEEVAC. The purchase price for the twelve-month periodacquisition was $20.0 million, subject to a working capital adjustment whereby we received a dollar-for-dollar reduction for the assumption of certain net liabilities of LEEVAC and settlement payments applied from sureties on certain ongoing fabrication projects that were assumed in the transaction. See also Note 2 of the Notes to Consolidated Financial Statements.


We allocate the purchase price to the acquired assets and assumed liabilities, including machinery and equipment, identifiable intangible assets and deferred revenues based upon their fair values as required by GAAP. The allocation and determination of respective fair values requires significant judgment and inherently complex calculations. We typically obtain the assistance of third party advisors in making these determinations.

The values assigned for the machinery and equipment we acquired were estimated primarily using the cost method. The cost method uses the concept of replacement and/or reproductive cost of the asset less depreciation due to physical, functional and economic factors, including obsolescence. The values assigned to the intangible assets (leasehold interest) and deferred revenues from below market contracts were calculated using the income method by applying a discounted cash flow model to the differences between the forecasted cash flows and market rates. The significant estimates and assumptions used in calculating these estimates are generally unobservable in the marketplace and reflect management’s estimates of assumptions that market participants would use.

We expense acquisition costs as incurred. During the years ended December 31, 2016, 2015 and 2014, comparedwe incurred acquisition costs of $118,000, $721,000 and $0, respectively.

Depreciation

Depreciation is computed using the straight-line method over an estimated useful life of three to net interest25 years for machinery and equipment. See Note 5 of the Notes to Consolidated Financial Statements. The determination of useful lives requires judgment and includes significant estimates that management reassesses as circumstances warrant. Depreciation expense of $234,000 for the twelve-month periodyears ended December 31, 2013. Net interest expense for2016, 2015 and 2014 was $25.4 million, $26.2 million and $26.4 million, respectively.

Results of Operations
2015 Loss Provision - During the periodyear ended December 31, 20142015, we incurred contract losses of $24.5 million related to a decrease in the contract price due to final weight re-measurements and our inability to recover certain costs on disputed change orders related to a large deepwater project which was lowerdelivered in 2015. In the second quarter of 2016, we initiated legal action to recover our costs from these disputed change orders. We can give no assurance that our actions will be successful or that we will recover all or any portion of these contract losses from our customer. No recoveries from our legal action have been included in the preparation of our Consolidated Financial Statements for the years ended December 31, 2016 or 2015.
In addition, we accrued contract losses of approximately $9.4 million during the year ended December 31, 2015 resulting from increases in our projected unit labor rates of our fabrication facilities. Our increases in unit labor rates were driven by our inability to absorb fixed costs due to decreases in expected oil and gas fabrication activity.


Comparison of the years ended December 31, 2016 and 2015 (in thousands, except for percentages):
Consolidated
 Twelve Months Ended December 31, Increase or (Decrease)
 2016 2015 AmountPercent
Revenue$286,326
 $306,120
 $(19,794)(6.5)%
Cost of revenue261,473
 321,276
 (59,803)(18.6)%
Gross profit (loss)24,853
 (15,156) 40,009
264.0 %
Gross profit (loss) percentage8.7% (5.0)%   
General and administrative expenses19,670
 16,256
 3,414
21.0 %
Asset impairment—
 7,202
 (7,202)(100.0)%
Operating income (loss)5,183
 (38,614) 43,797
(113.4)%
Other income (expense):      
Interest expense(332) (165) (167) 
Interest income24
 26
 (2) 
Other income681
 20
 661
 
Total Other income (expense)373
 (119) 492
413.4 %
Net income (loss) before income taxes5,556
 (38,733) 44,289
114.3 %
Income taxes2,041
 (13,369) 15,410
115.3 %
Net income (loss)$3,515
 $(25,364) $28,879
113.9 %
Revenues - Our revenues for years ended December 31, 2016 and 2015 were $286.3 million and $306.1 million, respectively, representing a decrease of 6.5%. The decrease is due to the significant decreases in capital spending by our customers as a result of decreased borrowings on the line of credit.

We had other expenses of $99,000 forprolonged downturn in the twelve-month period ended December 31, 2014, compared to other expenses of $337,000 for the twelve-month period ended December 31, 2013. Other expenses for both periods primarily represent losses on sales of miscellaneous equipment.

Our effective income tax rate was 35.7% for the twelve-month period ended December 31, 2014, compared to 37.3% for the twelve-month period ended December 31, 2013. Theoil and gas industry particularly in our Fabrication division and a decrease in pass through costs. Additionally, our Fabrication division completed a 1,200 foot jacket, piles and an approximate 450 short ton topside during 2015 with no similar project in 2016. Our decrease in revenue earned from offshore fabrication work was partially offset by the effective rate forcontracts acquired in the period ended December 31, 2014 is a result of (a) lower effective state income tax rate; and (b) the fact that we were able to fully utilized net operating lossesLEEVAC transaction (see LEEVAC Transaction above), which contributed $75.6 million in 2014, allowing the Company to take the Qualified Production Activities Income Deduction (Section 199) for taxable earnings in excess of net operating lossesrevenue for the year ended December 31, 2014.

Comparison of the Years Ended December 31, 2013 and 2012

For the twelve-month period ended December 31, 2013, our revenue was $608.3 million compared to $521.3 million for the twelve-month period ended December 31, 2012, an increase of 16.7%. The following factors contributed to the increase in revenues for the year ended December 31, 2013 compared to the year ended December 31, 2012:

2016. Pass-through costs as a percentage of revenue were 36.5% and 44.4% for the twelve-month periodyears ended December 31, 2013 were 58.5% compared2016 and 2015, respectively. Pass-through costs, as described in Note 3 of the Notes to 48.3%Consolidated Financial Statements, are included in revenue but have no impact on the gross profit recognized on a project for a particular period.


Gross profit (loss) - Our gross profit (loss) for the twelve-month periodyears ended December 31, 2012.2016 and 2015 was $24.9 million (8.7% of revenue) and $(15.2) million (5.0% of revenue), respectively. The increase

in gross profit was primarily due to:


$24.5 million of contract losses related to a decrease in the contract price due to final weight re-measurements and our inability to recover certain costs on disputed change orders related to a large deepwater project delivered in 2015 as referred to above;
$9.4 million of contract losses due to projected increases in our unit labor rates during the fourth quarter of 2015 as referred to above;
significant cost cutting measures implemented in order to right-size our operations in response to the decreases in work at our fabrication facilities which include wage adjustments, employee benefit reductions and workforce reductions (see also "Executive Summary" above; and
amortization of $5.2 million of non-cash deferred revenue related to the purchase price fair value of the contracts acquired in the LEEVAC transaction for 2016.

General and administrative expenses - Our general and administrative expenses were $19.7 million for the year ended December 31, 2016, compared to $16.3 million for the year ended December 31, 2015. The increase in general and administrative expenses was primarily attributable to the LEEVAC transaction which added $2.9 million in general and administrative expenses and an increase in stock-based compensation expense of $418,000 during the year ended December 31, 2016 as compared to December 31, 2015, partially offset by cost cutting efforts implemented as a result of the downturn in the oil and gas industry.



Asset impairment - We recorded asset impairment charges of $7.2 million during the year ended December 31, 2015 related to our assets held for sale as further discussed in Note 6 of the Notes to Consolidated Financial Statements. We had no asset impairment charges for the year ended December 31, 2016.

Interest expense - The Company had net interest expense of $308,000 for the year ended December 31, 2016 compared to net interest expense of $139,000 for 2015. The increase in net interest expense was primarily driven by interest expense associated with our unused commitment fee on our credit facility increasing from 0.25% to 0.50%.

Other income - Other income for the year ended December 31, 2016 was $681,000 compared to $20,000 for 2015. Other income for the year ended December 31, 2016 primarily represents gains on sales of cranes at our South Texas facility.

Income taxes - Our effective income tax rate for the year ended December 31, 2016 was 36.7% compared to an effective tax rate of 34.5% for 2015. The increase in the effective tax rate is primarily due to the impact of alternative minimum taxes and state income taxes for our operations in Louisiana.

Operating Segments
Fabrication Division
 Twelve Months Ended December 31, Increase or (Decrease)
 2016 2015 AmountPercent
Revenue$88,683
 $151,576
 $(62,893)(41.5)%
Gross profit (loss)5,061
 (37,541) 42,602
113.5 %
Gross profit percentage5.7% (24.8)%   
General and administrative expenses6,100
 9,293
 (3,193)(34.4)%
Asset impairment—
 7,202
 (7,202)(100.0)%
Operating loss$(1,039) $(54,036) $52,997
98.1 %
Revenue - Revenue decreased $62.9 million for the year ended December 31, 2016 compared to 2015. The decrease is attributable to an overall decrease in work experienced in our fabrication yards as a result of depressed oil and gas prices and the corresponding reduction in customer demand for offshore fabrication projects. During 2015, we completed the fabrication of a 1,200 foot jacket, piles and an approximate 450 short ton topside with no similar project in 2016.

Gross profit (loss) - Gross profit increased $42.6 million for the year ended December 31, 2016 compared to 2015. The increase is due to:

$24.5 million of contract losses related to a decrease in the contract price due to final weight re-measurements and our inability to recover certain costs on disputed change orders related to a large deepwater project delivered in 2015 as referred to above;
$9.4 million of contract losses due to projected increases in our unit labor rates during the fourth quarter of 2015 as referred to above; and
Significant cost cutting measures implemented in order to right-size our operations in response to the decreases in work at our fabrication facilities.

General and administrative expense - General and administrative expenses decreased $3.2 million for the year ended December 31, 2016 compared to 2015 due to cost cutting measures implemented during 2016 in response to decreases in work at our fabrication facilities and a decrease in the percentage of allocation of administrative expenses from our corporate office.

Asset impairment - We had no asset impairment charges for the year ended December 31, 2016. We recorded an asset impairment charges of $7.2 million during the year ended December 31, 2015 related to our assets held for sale as further discussed above and in Note 6 of the Notes to Consolidated Financial Statements.



Shipyards Division
 Twelve Months Ended December 31, Increase or (Decrease)
 2016 2015 AmountPercent
Revenue (1)
$109,502
 $59,601
 $49,901
83.7 %
Gross profit7,587
 8,665
 (1,078)(12.4)%
Gross profit percentage6.9%
14.5%   
General and administrative expenses7,750
 1,692
 6,058
358.0 %
Operating (loss) income$(163) $6,973
 $(7,136)(102.3)%
____________

in pass-through costs

(1)Revenue for the twelve monthsyear ended December 31, 2013 primarily relates2016, includes 5.2 million of non-cash amortization of deferred revenue related to sub-contracted service costs on our major deepwater projects. Pass-through costs, as described in Note 11the values assigned to the contracts acquired in the Notes to Consolidated Financial Statements, are included in revenue, but have no impact on amount of gross margin recognized for the related project for a particular period.

LEEVAC transaction

Increased

Revenue - Revenue increased $49.9 million for the year ended December 31, 2016 compared to 2015 due to the contracts acquired in the LEEVAC transaction (see LEEVAC Transaction above), which contributed $75.6 million in revenue for the year ended December 31, 2016. Included in revenue for 2016 is amortization of $5.2 million million of non-cash deferred revenue related to the purchase price fair value of the contracts acquired in the LEEVAC transaction for 2016. The increase was partially offset by decreases in marine work due to the downturn in the oil and gas industry.

Gross profit - Gross profit decreased $1.1 million for the year ended December 31, 2016 compared to 2015 due to consolidation of jobs at our shipyard in Houma, Louisiana, and tighter margins for other jobs in progress due to the downturn in the oil and gas industry.

General and administrative expense - General and administrative expenses increased $6.1 million for the year ended December 31, 2016 compared to 2015 due to the expenses associated with labor hoursthe operations acquired in the LEEVAC transaction which added $2.9 million in general and administrative expenses and an increase in the percentage allocation of administrative expenses from our corporate office.

Services Division
 Twelve Months Ended December 31, Increase or (Decrease)
 2016 2015 AmountPercent
Revenue$91,414
 $100,431
 $(9,017)(9.0)%
Gross profit12,205
 13,726
 (1,521)(11.1)%
Gross profit percentage13.4%
13.7%   
General and administrative expenses5,637
 4,178
 1,459
34.9 %
Operating income$6,568
 $9,548
 $(2,980)(31.2)%

Revenue - Revenue decreased $9.0 million for the year ended December 31, 2016 compared to 2015 due to decreases in work and tighter margins due to the downturn in the oil and gas industry, particularly in the latter half of 2016.

Gross profit - Gross profit decreased $1.5 million for the year ended December 31, 2016 compared to 2015 due to decreases in work and tighter margins for other jobs in progress due to the downturn in the oil and gas industry, particularly in the latter half of 2016.

General and administrative expense - General and administrative expenses increased $1.5 million for the year ended December 31, 2016 compared to 2015 due to increased bonus expense and an increase in the allocation percentage of administrative expenses from our corporate office.



Comparison of the years ended December 31, 2015 and 2014 (in thousands, except for percentages):
Consolidated
 Twelve Months Ended December 31, Increase or (Decrease)
 2015 2014 AmountPercent
Revenue$306,120
 $506,639
 $(200,519)(39.6)%
Cost of revenue321,276
 462,083
 (140,807)(30.5)%
Gross (loss) profit(15,156) 44,556
 (59,712)(134.0)%
Gross profit percentage(5.0)% 8.8%   
General and administrative expenses16,256
 17,409
 (1,153)(6.6)%
Asset impairment7,202
 3,200
 4,002
125.1 %
Operating (loss) income(38,614) 23,947
 (62,561)(261.2)%
Other income (expense):      
Interest expense(165) (37) (128) 
Interest income26
 13
 13
 
Other income (expense)20
 (99) 119
 
Total Other income (expense)(119) (123) 4
3.3 %
(Loss) income before income taxes(38,733) 23,824
 (62,557)(262.6)%
Income taxes(13,369) 8,504
 (21,873)(257.2)%
Net (loss) income$(25,364) $15,320
 $(40,684)(265.6)%
Revenues - Our revenues for years ended December 31, 2015 and 2014 were $306.1 million and $506.6 million, respectively, representing a decrease of 39.6%. The decrease is primarily attributable to an overall decrease in work experienced in our fabrication yards as a result of depressed oil and gas prices and the corresponding reduction in activity in the Gulf of Mexico. In addition, we also experienced:

a decrease in the contract price due to final weight re-measurements and our inability to recover certain costs on topsidesdisputed change orders related to a large deepwater project which was delivered in 2015, as further described in "2015 Loss Provision'' above; and completion
higher revenue during 2014 primarily as a result of a Spar Hullwork performed for a large deepwater customer after contract renegotiationsproject and, to effectively convert the contract from a unit rate basis to an alliance/partnering basis.

The increaselesser extent, experienced a decrease of pass through costs in revenue was partially offset by estimated contract losses of $30.8 million primarily for a separate large deep-water project, as further discussed in “Backlog” above.

For the twelve-month periods ended December 31, 2013 and 2012, gross profit was $23.7 million (3.9% of revenue) and $3.8 million (0.7% of revenue), respectively. Factors contributing to the overall increase in gross profit for the twelve-month period ended December 31, 2013 compared to the twelve-month period ended December 31, 2012 include:

Increased margin on revenue associated with fabrication of topside and hull projects for a large deepwater customer after contract renegotiations to effectively convert the contracts from a unit rate basis to an alliance/partnering basis.

We recognized no provision for losses on contract receivables during the twelve-month period ended December 31, 20132015 as compared to a provision for losses on contract receivables of $14.5 million related to the suspension and subsequent termination of our deepwater contract with Bluewater during the twelve month period ended December 31, 2012. For additional information, see2014.


Pass-through costs, as described in Note 13 in the Notes to Consolidated Financial Statements, “Assets heldare included in revenue but have no impact on the gross profit recognized on a project for sale”.

a particular period. Pass-through costs as a percentage of revenue were 44.4% and 48.2% for the years ended December 31, 2015 and 2014, respectively.

Overall increase

Gross (loss) profit - Our gross (loss) profit for the years ended December 31, 2015 and 2014 was $(15.2) million (5.0% of revenue) and $44.6 million (8.8% of revenue), respectively. The decrease in margingross profit was primarily due to:

contract losses of $24.5 million recorded during the third and fourth quarters of 2015, as referred to above;
$9.4 million of contract losses due to projected increases in our unit labor rates as referred to above;
lower project activity during 2015 as compared to the same period in 2014 and
less offshore commissioning and hook-up activity performed on a time and material basis during 2015 as compared to 2014.

General and administrative expenses - Our general and administrative expenses were $16.3 million for the year ended December 31, 2015, compared to $17.4 million for the year ended December 31, 2014. The decrease in general and administrative expenses was primarily attributable to bad debt expense of $3.6 million recorded during the fourth quarter of 2014 related to a contract receivable balance with a customer for a deepwater hull project as well as reductions in discretionary spending in response to customer reductions in capital expenditures and reduced fabrication activity. These decreases were partially offset by contract losses$721,000 in acquisition and due diligence expenditures related to the LEEVAC transaction and an increase in stock-based compensation expense of $30.8$1.6 million during 2015 as compared to 2014.



Asset impairment - We recorded asset impairment charges of $7.2 million during the twelve-month periodyear ended December 31, 20132015 related to our assets held for sale as further discussed in Note 6 of the Notes to Consolidated Financial Statements as compared to asset impairment charges of $3.2 million for the year ended December 31, 2014.

Interest expense - The Company had net interest expense of $139,000 for the year ended December 31, 2015 compared to net interest expense of $24,000 for 2014. The increase in net interest expense was primarily driven by interest expense associated with increases to letters of credit during 2015.

Other income (expense) - Other income for the year ended December 31, 2015 was $20,000 compared to other expense of $99,000 for 2014. Other income for the year ended December 31, 2015 primarily represents gains on sales of property, plant, and equipment as compared to other expense in 2014, which primarily related to losses on sales of property, plant, and equipment during 2014.

Income taxes - Our effective income tax rate for 2015 was 34.5% compared to an effective tax rate of 35.7% for 2014. The decrease in the effective tax rate is primarily due to the impact of state income taxes for our operations in Louisiana.

Operating Segments
Fabrication Division
 Twelve Months Ended December 31, Increase or (Decrease)
 2015 2014 AmountPercent
Revenue$151,576
 $303,880
 $(152,304)(50.1)%
Gross (loss) profit(37,541) 19,418
 (56,959)(293.3)%
Gross profit percentage(24.8)% 6.4%   
General and administrative expenses9,293
 12,139
 (2,846)(23.4)%
Asset impairment7,202
 3,200
 4,002
125.1 %
Operating (loss) income$(54,036) $4,079
 $(58,115)(1,424.7)%
Revenue - Revenue decreased $152.3 million for the year ended December 31, 2015 compared to 2014. The decrease is attributable to:

a decrease in the contract price due to final weight re-measurements and our inability to recover certain costs on disputed change orders related to a large deepwater project which was delivered in 2015, as further described in "2015 Loss Provision'' above;
recognized higher revenue primarily as a result of work performed for a large deepwater project during 2014;
a decrease of pass through costs due to lesser amounts of subcontractor services and the de-scoping of one of our major deepwater projects,direct materials in 2015 as compared to $12.52014; and
an overall decrease in work experienced in our fabrication yards as a result of depressed oil and gas prices and the corresponding reduction in customer demand for offshore fabrication projects.

Gross (loss) profit - Gross profit decreased $57.0 million recognized duringfor the twelve-month periodyear ended December 31, 20122015 compared to 2014. The decrease is due to:

$24.5 million of contract losses related to a decrease in the contract price due to final weight re-measurements and our inability to recover certain costs on disputed change orders related to a large deepwater project delivered in 2015 as further explainedreferred to above; and
$9.4 million of contract losses due to projected increases in “Backlog”our unit labor rates during the fourth quarter of 2015 as referred to above.

Our general

These were partially offset by $5.4 million of contract losses recognized during 2014 related to tank barge projects for a marine transportation company.

General and administrative expenses were $11.6 - General and administrative expenses decreased $2.8 million for the twelve-month periodyear ended December 31, 20132015, compared to $9.8 million for the twelve-month period ended December 31, 2012. Although the absolute dollar value represented an 18% increase in 2013 relative to 2012, general and administrative expenses, as a percentage of revenue, was 1.9% for the twelve-month periods ended December 31, 2013 and 2012. Factors that contributed to the increase2014. The decrease in general and administrative expenses forwas primarily attributable to bad debt expense of $3.6 million recorded during the twelve monthsfourth quarter of 2014.



Asset impairment - We recorded asset impairment charges of $7.2 million during the year ended December 31, 2013 include:

An increase2015 related to our assets held for sale as further discussed in Note 6 of $0.9the Notes to Consolidated Financial Statements as compared to asset impairment charges of $3.2 million in employee compensation; and

An increase of $0.9 million in bad debt expenses in connection with a vessel upgrade and outfitting project.

We had net interest expense of $234,000 for the twelve-month periodyear ended December 31, 2013 compared to net interest income of $433,0002014.


Shipyards Division
 Twelve Months Ended December 31, Increase or (Decrease)
 2015 2014 AmountPercent
Revenue$59,601
 $79,197
 $(19,596)(24.7)%
Gross profit8,665
 4,922
 3,743
76.0 %
Gross profit percentage14.5% 6.2%   
General and administrative expenses1,692
 1,660
 32
1.9 %
Operating (loss) income$6,973
 $3,262
 $3,711
113.8 %
Revenue - Revenue decreased $19.6 million for the twelve-month periodyear ended December 31, 2012. Net interest expense for the period ended December 31, 2013 was higher2015 compared to 2014. The decrease is attributable to an overall decrease in work experienced in our fabrication yards as a result of depressed oil and gas prices and the corresponding reduction in customer demand for marine vessels.

Gross profit - Gross profit increased borrowings on the line of credit. Net interest income$3.7 million for the periodyear ended December 31, 2012 included2015 compared to 2014. The increase is due to improvements in productivity and significant cost cutting measures implemented in order to right-size our operations in response to the decreases in work at our facilities. Additionally, we recognized contract losses of $1.3 million during 2014 that were primarily related to platform supply vessels for an accretion of a discount associated with a financing arrangement.

We had other expenses of $337,000offshore marine company.


Services Division
 Twelve Months Ended December 31, Increase or (Decrease)
 2015 2014 AmountPercent
Revenue$100,431
 $132,107
 $(31,676)(24.0)%
Gross profit13,726
 20,258
 (6,532)(32.2)%
Gross profit percentage13.7% 15.3%   
General and administrative expenses4,178
 2,756
 1,422
51.6 %
Operating (loss) income$9,548
 $17,502
 $(7,954)(45.4)%

Revenue - Revenue decreased $31.7 million for the twelve-month periodyear ended December 31, 2013,2015 compared to other income of $128,0002014. The decrease is attributable to depressed oil and gas prices and the corresponding reduction in customer demand for offshore connection and hook-up activity.

Gross profit - Gross profit decreased $6.5 million for the twelve-month periodyear ended December 31, 2012. Other income2015 compared to 2014. The decrease is due to lower demand for offshore connection and expense forhook-up activity resulting in both periods primarily represent gainsdecreases in revenues and lossestighter margins on sales of miscellaneous equipment.

Our effective income tax rate was 37.3%work performed during 2015.


General and administrative expenses - General and administrative expenses increased $1.4 million for the twelve-month periodyear ended December 31, 2013,2015, compared to a tax benefit of 24.3% for the twelve-month period ended December 31, 2012.2014. The increase in the effective rate for the period ended December 31, 2013 is a result of the Company’s pre-tax income in 2013, comparedwas primarily attributable to losses recorded in 2012, and represents a more typical overall effective tax rate for profitable years.

additional support to fulfill contract obligations.


Liquidity and Capital Resources

At December 31, 2014, our cash and cash equivalents totaled $36.1 million; working capital was $99.7 million; and our ratio of current assets to current liabilities was 2.3 to 1.0, compared to cash and cash equivalents of $36.6 million; working capital of $89.7 million; and a ratio of current assets to current liabilities of 1.8 to 1.0 at December 31, 2013. Our primary uses of cash during 2014 were related to capital expenditures, investments in projects, and payment of dividends.

We are currently in discussions with a customer related to collection of a contract receivable balance for a deepwater hull project that was completed during the first quarter 2014. In the fourth quarter 2014, we included in general and administrative expenses in our income statement an allowance for bad debt in the amount of $3.6 million for this customer, resulting in a $10.0 million receivable balance at December 31, 2014. We expect to have the matter fully resolved before or shortly after the end of the first quarter 2015. There are no unbilled balances associated with this project.

As of February 25, 2015, we collected $62.5 million of our contract receivable balance outstanding at December 31, 2014. We had approximately $7.7 million of costs and estimated earnings in excess of billings on uncompleted contracts balance that related to projects with milestone billing terms, of which approximately $3.5 million was billed subsequent to December 31, 2014. The remaining unbilled amounts are billable on a monthly basis.

Historically, we have funded our business activities through cash generated from operations. At December 31, 2016, cash and cash equivalents totaled $51.2 million compared to $34.8 million at December 31, 2015 with no borrowings outstanding under our credit facility. Working capital was $78.0 million and our ratio of current assets to current liabilities was 3.2 to 1 at December 31, 2016. Our primary source of cash for the year ended December 31, 2016, was the collection of accounts receivable under various customer contracts and sales of three cranes at our Texas facility for $6.4 million. At December 31, 2016, our contracts receivable balance was $20.2 million. We have subsequently collected $12.6 million through February 28, 2017.

On January 1, 2016, we acquired substantially all of the assets and assumed certain specified liabilities of LEEVAC. The Company haspurchase price for the acquisition was $20.0 million, subject to a working capital adjustment whereby we received a dollar-for-


dollar reduction for the assumption of certain net liabilities of LEEVAC at closing and settlement payments from sureties on certain ongoing fabrication projects that were assigned to us in the transaction. After taking into account these adjustments, we received approximately $1.6 million in cash at closing. During the fourth quarter, we finalized our working capital true-up with the seller and received $1.4 million in cash for additional working capital. Additionally, we hired 380 employees upon acquisition of the facilities representing substantially all of the former LEEVAC employees. Strategically, the transaction expands our marine fabrication and repair and maintenance presence in the Gulf South market. At the date of transaction, we acquired approximately $121.2 million of newbuild construction backlog inclusive of approximately $9.2 million of purchase price fair value allocated to four, newbuild construction projects to be delivered in 2017 and 2018 for two customers. At December 31, 2016, our reported backlog includes $3.8 million of non-cash deferred revenue related to the purchase price fair value of the contracts acquired in the LEEVAC transaction and included in deferred revenue in our Consolidated Balance Sheet.

On December 16, 2016, we amended our credit agreement with Whitney Bank and JPMorgan Chase Bank N.A. that provides for an $80 million revolvingThe amended and restated credit facility. The credit agreement also allows the Company to use up to the full amount of the available borrowing base for letters of credit. The credit facility matures on December 31, 2015. Our revolving line of creditfacility: (i) is secured by substantially all of our assets other(other than real property locatedestate); (ii) extends the term of the facility from January 2, 2017 to November 29, 2018; (iii) reduces the borrowing base from $80.0 million to $40.0 million; and (iv) permits the full borrowing base to be used for issuing letters of credit and/or general corporate and working capital purposes. Under the prior facility, only $20.0 million of the $80.0 million borrowing base could be used for general corporate and working capital purposes. Given the historically low levels of borrowings under our prior credit facility and our cash position, we requested a reduction in the stateamount of Louisiana. Amounts borrowedavailable credit under our revolving linethe facility from $80.0 million to $40.0 million during negotiations with the lenders to decrease the commitment fees payable on the undrawn portion of the facility. We must comply with the following financial covenants each quarter beginning with the quarter ending December 31, 2016:

(i)minimum net worth requirement of not less than $255.0 million, plus
(a)plus 50% of net income earned in each quarter beginning December 31, 2016 and
(b)100% of proceeds from any issuance of common stock,
(c)less the amount of any impairment on assets owned by Gulf Marine Fabricators, L.P. up to $30.0 million;
(ii)debt to EBITDA ratio not greater than 2.5 to 1.0; and
(iii) interest coverage ratio not less than 2.0 to 1.0.

The annual interest rates applicable to amounts outstanding under the amended and restated credit bear interest,facility continue to remain, at ourthe Company’s option, at either the(i) a prime lending rate established by JPMorgan Chase Bank, N.A., or (ii) a LIBOR rate (defined in the amended and restated credit agreement) plus 1.5 percent. We pay a2.0% per annum. In addition, the commitment fee on a quarterly basisthe undrawn portion of one-fourththe facility and the letter of one percentcredit fee on undrawn stated amounts under letters of credit issued by the lenders remain at 0.50% per annum on the weighted-average unused portion of our revolving line of credit.

and 2.0% per annum, respectively. At December 31, 20142016 we had no outstanding borrowings under our revolving line ofthe credit agreement, and we had outstanding letters of credit totaling $21.0 million, which reduced$7.7 million. After consideration of outstanding letters of credit, the availability of the unused portion of ourthe revolving linecredit agreement (as amended) for additional letters of credit to $59.0and for general corporate purposes was $32.3 million.

We are required to maintain certain financial covenants under our revolving line of credit, including a minimum current ratio of 1.25 to 1.0, a net worth minimum requirement of $254.1 million, debt to net worth ratio of 0.5 to 1.0, and earnings before interest, taxes, depreciation and amortization (EBITDA) to interest expense ratio of 4.0 to 1.0. As of December 31, 2014, we were in compliance with our covenants at December 31, 2016.


Our primary liquidity requirements are for the costs associated with fabrication projects, capital expenditures and payment of dividends to our shareholders. We experienced a significant decline in our fabrication work from our oil and gas customers during 2015 and 2016 primarily due to the decline in oil and gas prices.

We anticipate capital expenditures for 2017 to range between $8.0 million to $12.0 million primarily for the following:

improvements to our Jennings and Lake Charles leased shipyards,
improvement to the bulkhead at our Houma facility, and
computer system upgrades.

On October 21, 2016, a customer of our Shipyards division announced it had received limited waivers from its lenders and noteholders through November 11, 2016, which was extended through March 3, 2017 with respect to noncompliance with certain financial covenants included in the customer’s debt agreements. The customer also announced its debt agreements will require further negotiation and amendment. In the event our customer is unsuccessful in these covenants.

Netefforts, the customer has publicly stated that it will consider other options including a possible reorganization under Chapter 11 of the Federal bankruptcy laws. At December 31, 2016, we had two vessels under construction for this customer with no contracts receivable outstanding and deferred revenue exceeded our contracts in progress.


We completed and tendered to this customer for delivery the first vessel on February 6, 2017. Upon our tender of delivery, our customer alleged certain technical deficiencies associated with the vessel. We disagree with our customer concerning these alleged technical deficiencies and have put the customer in default under the terms of the contract. As of February 6, 2017, approximately $4.5 million remained due and outstanding from our customer under this contract. We continue to hold discussions


with our customer in an effort to resolve this matter and intend to take all legal action as may be necessary to protect our rights under the contract and recover the remaining balance owed to us. The second offshore supply vessel for this customer is scheduled for delivery in May 2017. As of February 28, 2017, the balance due to us for this second vessel is approximately $4.9 million and both we and our customer remain in compliance with the terms of this contract.

We continue to monitor our work performed in relation to our customer’s status and its ability to pay under the terms of these contracts. Because these vessels have been completed or are substantially complete, we believe that they have significant fair value, and that we would be able to fully recover any amounts due to us.

On February 23, 2017, our Board of Directors declared a dividend of $0.01 per share on our shares of common stock outstanding, payable March 24, 2017 to shareholders of record on March 10, 2017.

We believe our cash and cash equivalents generated by operating activities and funds available under our credit facility will be sufficient to fund our capital expenditures, issue future letters of credit and meet our working capital needs through the next year to continue our operations, satisfy our contractual operations and pay dividends to our shareholders.

Cash Flows for the Years Ended December 31, 2016, 2015 and 2014 (in thousands):
  201620152014
Operating activities $14,351
$10,615
$32,110
Investing activities 2,698
(6,007)(26,729)
Financing activities $(710)$(5,865)$(5,865)
     
Operating activities:

The increase in cash provided by operating activities was $32.1 millionoperations for the year ended December 31, 2014,2016 compared to $38.0 million for the year ended December 31, 2013. The decrease2015 was a result of increased investment in projects in 2014, primarily in connection with the start-up of our large traditional jacket deepwater project, partially offset by stronger operating performance, specifically relateddue to increased gross profit and lower contract losses.

Netprofit.


The decrease in cash usedflows provided by operating activities for 2015 as compared to 2014 was primarily due to net losses incurred during 2015 as compared to net income during 2014.

Investing activities:

The increase in cash provided by investing activities for the year ended December 31, 2016 compared to 2015 was primarily due to proceeds received from the sale of assets (primarily three cranes at our Texas facility) of $6.5 million and $3.0 million in cash received in the LEEVAC transaction.

The decrease in cash flows used in investing activities for 2015 as compared to 2014 was $26.7 million, primarily relateddue to reduced capital expenditures for equipmentas a result of management’s concerted effort to reduce our discretionary and improvements to our production facilities, including $15.4 million for two cranes for our Texas facility.

We anticipate capital expenditures for 2015 to be approximately $4.8 million, including $1.1 million for yard and facility infrastructure, $2.0 million for new equipment, and $1.7 million for maintenance capital expenditures at our facilities.

spending.


Financing activities:

The $5.9 million of netdecrease in cash used in financing activities for the year ended December 31, 2016 compared to 2015 was due to the reduction in the cash dividend in 2016.

Cash flows used in financing activities for each of the years ended December 31, 2015 and 2014 wasprimarily related to paymentsthe payment of dividends on common stock.

We believe that for the next twelve months, our cash on hand, amounts received through collection of accounts receivable, our cash generated by operating activities and funds available under our revolving line of credit will be sufficient to fund our capital expenditures and meet our working capital needs. However, job awards may require us to issue additional letters of credit further reducing the capacity available on our revolving line of credit. We may also expand our operations through acquisitions in the future, which may require additional equity or debt financing which we believe would be available to us; however, there can be no assurance that amounts will ultimately be available or will be available on commercial terms acceptable to us.

dividends.




Contractual Obligations and Commitments

The following table sets forth an aggregation of our contractual obligations and commitments as of December 31, 2014,2016, (in thousands).

   Total   Payments Due by Period 
     Less Than
1 Year		   1 to 3
Years		   3 to 5
Years		   Thereafter 

Purchase commitment – equipment (1)

  $179    $179    $—      $—      $—    

Purchase commitment – material and services (2)

   12,873     12,873     —       —       —    

Operating leases (3)

   1,124     213     438     454     19  
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 
  $14,176    $13,265    $438    $454    $19  
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

 Total Payments Due by Period
 
Less Than
1 Year
 
1 to 3
Years
 
3 to 5
Years
 Thereafter
Purchase commitment – equipment (1)
$834
 $834
 $—
 $—
 $—
Purchase commitment – material and services (2)
28,417
 27,359
 1,058
 —
 —
Operating leases (3)
2,122
 852
 879
 288
 103
Total$31,373
 $29,045
 $1,937
 $288
 $103
(1)“Purchase commitment – equipment” is a commitmentare commitments related to purchase order agreements.agreements for equipment.
(2)“Purchase commitment – material and services” is a commitmentare commitments related to purchase order agreements.agreements for contracts in progress.
(3)Operating leases are commitments for office space.space and facilities.

Off-Balance Sheet Arrangements

We are not a party to any contract or other obligation not included on our balance sheet that has, or is 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.

Other Matters

Not applicable.

Item 7A.Quantitative and Qualitative Disclosures About Market Risk

Item 7A. Quantitative and Qualitative Disclosures About Market Risk
We do not have operations subject to material risk of foreign currency fluctuations, nor do we use derivative financial instruments in our operations or investment portfolio. We have an $80.0a credit agreement with Whitney Bank and JPMorgan Chase Bank N.A. that provides for a $40.0 million revolving linecredit facility that allows us to use up to the full amount of the available borrowing base for letters of credit with our primary commercial banks. Underand for general corporate purposes. The annual interest rates applicable to amounts outstanding under the terms of our revolving line ofamended and restated credit we may elect to pay interest atfacility are either (i) a prime lending rate established by JPMorgan Chase Bank, N.A., or (ii) a LIBOR rate (defined in the bank from time to time or LIBORamended and restated credit agreement) plus 1.5 percent.

2.0% per annum (as selected at our option). The commitment fee on the undrawn portion of the facility and the letter of credit fee on undrawn stated amounts under letters of credit issued by the lenders is 0.50% per annum and 2.0% per annum, respectively. At December 31, 2016 we had no outstanding borrowings under the credit agreement, and we had outstanding letters of credit totaling $7.7 million. After consideration of outstanding letters of credit, the availability of the unused portion of the revolving credit agreement was $32.3 million.

Item 8.Financial Statements and Supplementary Data

Item 8. Financial Statements and Supplementary Data
In this report our consolidated financial statements of and the accompanying notes appear on pages F-1 through F-20F-21 and are incorporated herein by reference. See Index to Consolidated Financial Statements on Page 3844.

Item 9.Changes in and Disagreements With Accountants on Accounting and Financial Disclosure

Item 9. Changes in and Disagreements With Accountants on Accounting and Financial Disclosure
None.

Item 9A.Controls and Procedures

Item 9A. Controls and Procedures
The Company maintains disclosure controls and procedures that are designed to ensure that information required to be disclosed by the Company in the reports that it files or submits under the Securities Exchange Act of 1934 is recorded, processed, summarized and reported within the time periods specified in the SEC rules and forms, and that such information is communicated to the Company’s management, including its Chief Executive Officer and Chief Financial Officer, as appropriate, to allow timely decisions regarding required disclosure. The Company’s management, with the participation of the Company’s Chief Executive Officer and Chief Financial Officer, has evaluated the effectiveness of our disclosure controls and procedures (as defined in Rule 13a-15(e) under the Securities Exchange Act of 1934) as of the end of the period covered by this report. Based on this evaluation, our Chief Executive Officer and Chief Financial Officer have concluded that the design and operation of our disclosure controls and procedures were effective as of the end of the period covered by this report.



Management’s Report on Internal Control Over Financial Reporting

Our management is responsible for establishing and maintaining adequate internal control over financial reporting, as such term is defined in Exchange Act Rule 13a-15(f). Under the supervision and with the participation of our management, including our principal executive officer and principal financial officer, we conducted an evaluation of the effectiveness of our internal control over financial reporting based on the framework inInternal Control – Integrated Frameworkissued by the Committee of Sponsoring Organizations of the Treadway Commission (2013 framework). Based on our evaluation under the framework inInternal Control – Integrated Framework,our management concluded that our internal control over financial reporting was effective as of December 31, 2014.2016.

Management's assessment of and conclusion on the effectiveness of internal control over financial reporting did not include the internal controls over the operations and assets acquired from LEEVAC Shipyards L.L.C and its affiliates as we are permitted to exclude these from our assessment in the initial year of acquisition. Total assets and liabilities reported by LEEVAC and included in our Consolidated Balance Sheet as of December 31, 2016 were $52.2 million and $54.0 million, respectively. Revenues and net loss reported by LEEVAC for the year ended December 31, 2016 were $75.6 million and $1.8 million, respectively.
The effectiveness of our internal control over financial reporting as of December 31, 20142016 has been audited by Ernst & Young LLP, an independent registered public accounting firm, as stated in their report dated March 5, 2015,2, 2017, which is included herein.



Report of Independent Registered Public Accounting Firm

The Board of Directors and Shareholders

Gulf Island Fabrication, Inc.


We have audited Gulf Island Fabrication, Inc.’s (the “Company’s”) internal control over financial reporting as of December 31, 2014,2016, based on criteria established inInternal Control – Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (2013 framework) (the COSO criteria). Gulf Island Fabrication, Inc.’s management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting included in the accompanying Management’s Report on Internal Control Over Financial Reporting. Our responsibility is to express an opinion on the Company’s internal control over financial reporting based on our audit.

We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects. Our audit included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, testing and evaluating the design and operating effectiveness of internal control based on the assessed risk, and performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.

A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the Company;company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the Companycompany are being made only in accordance with authorizations of management and directors of the Company;company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the Company’scompany’s assets that could have a material effect on the financial statements.

Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

As indicated in the accompanying Management's Report on Internal Control over Financial Reporting, management's assessment of and conclusion on the effectiveness of internal control over financial reporting did not include the internal controls of LEEVAC Shipyards, L.L.C and its affiliates, which is included in the December 31, 2016 consolidated financial statements of Gulf Island Fabrication, Inc. and constituted $52.2 million and $54.0 million of total assets and liabilities, respectively, as of December 31, 2016 and $75.6 million and $(1.8) million of revenues and net income (loss), respectively, for the year then ended. Our audit of internal control over financial reporting of Gulf Island Fabrication, Inc. also did not include an evaluation of internal control over financial reporting of LEEVAC Shipyards, L.L.C.
In our opinion, Gulf Island Fabrication, Inc. maintained, in all material respects, effective internal control over financial reporting as of December 31, 2014,2016, based on the COSO criteria.

We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the consolidated balance sheets of Gulf Island Fabrication, Inc. as of December 31, 20142016 and 2013,2015, and the related consolidated statements of income,operations, changes in shareholders’ equity, and cash flows for each of the three years in the period ended December 31, 2014,2016, and our report dated March 5, 2015,2, 2017, expressed an unqualified opinion thereon.

/s/ Ernst & Young LLP

New Orleans, Louisiana

March 5, 2015

2, 2017



Item 9B.Other Information

Item 9B. Other Information
Not applicable.




PART III

Item 10.Directors, Executive Officers and Corporate Governance

Item 10. Directors, Executive Officers and Corporate Governance
The information regarding executive officers called for by this item may be found following Item 4 of this report on Form 10-K under the caption “Executive Officers of the Registrant” and is incorporated herein by reference.

We have adopted a Code of Ethics for the Chief Executive Officer, the Chief Financial Officer (the principal accounting officer), and the Corporate Controller – Financial Reporting (the principal accounting officer) and persons performing similar functions (the “Code of Ethics”) and a Code of Business Conduct and Ethics, which applies to all employees and directors, including the Chief Executive Officer, the Chief Financial Officer (the principal accounting officer), the Corporate Controller and persons performing similar functions. These codes are available to the public on our web sitewebsite at www.gulfisland.com. Any substantive amendments to the Code of Ethics or any waivers granted under the Code of Ethics will be disclosed within four business days of such event on our web site.

website.

The remaining information called for by this item may be found in our definitive Proxy Statement prepared in connection with the 20152017 Annual Meeting of Shareholders and is incorporated herein by reference.

Item 11.Executive Compensation

Item 11. Executive Compensation
Information called for by this item may be found in our definitive Proxy Statement prepared in connection with the 20152017 Annual Meeting of Shareholders and is incorporated herein by reference.

Item 12.Security Ownership of Certain Beneficial Owners and Management and Related Stockholders Matters

Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholders Matters
Information regarding security ownership of certain beneficial owners and management called for by this item may be found in our definitive Proxy Statement prepared in connection with the 20152017 Annual Meeting of Shareholders and is incorporated herein by reference.

Equity Compensation Plan Information

The following table provides information about our shares of common stock that may be issued upon the exercise of options, warrants and rights under all of our existing equity compensation plans as of December 31, 2014.

Plan Category

  Number of securities
to be issued upon
exercise of
outstanding options,
warrants and rights
(a)		  Weighted-average
exercise price of
outstanding
options, warrants
and rights
(b)		   Number of securities remaining
available for future issuance
under equity compensation
plans (excluding securities
reflected in column (a))
(c)		 

Equity compensation plans approved by security holders

   0    N/A     542,123  

Equity compensation plans not approved by security holders

   0      0  
  

 

 

    

 

 

 

Total

   0(1)     542,123(2) 
  

 

 

    

 

 

 

2016.
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 column
  
Equity compensation plans approved by security holders411,032    N/A 1,012,121   
Equity compensation plans not approved by security holders—      —   
Total—     1,012,121 
(1) 
(1)There were no outstanding options asAmount includes the effect of December 31, 2014.
(2)As of December 31, 2014,111,361 performance share awards granted on February 123, 2017. Accordingly, there were 445,551846,230 shares remaining available for issuance under the 20112015 Stock Incentive Plan, 74,66954,304 shares remaining available under the 20022011 Long-Term Incentive Plan, and 21,903111,587 shares remaining available under the Long-Term Incentive Plan, all of which could be issued under the terms of the plans upon the exercise of stock options or stock appreciation rights, or in the form of restricted stock or other stock awards.Plan.

Item 13.Certain Relationships and Related Transactions, and Director Independence

Item 13. Certain Relationships and Related Transactions, and Director Independence
Information called for by this item may be found in our definitive Proxy Statement prepared in connection with the 20152017 Annual Meeting of Shareholders and is incorporated herein by reference.




Item 14.Principal Accounting Fees and Services

Item 14. Principal Accounting Fees and Services
Information called for by this item may be found in our definitive Proxy Statement prepared in connection with the 20152017 Annual Meeting of Shareholders and is incorporated herein by reference.



PART IV

Item 15.Exhibits, Financial Statement Schedules

Item 15. Exhibits, Financial Statement Schedules
The following financial statements, schedules and exhibits are filed as part of this Report:

(i) Financial Statements

 Page

Report of Independent Registered Public Accounting Firm

F-1

Consolidated Balance Sheets at December 31, 20142016 and December 31, 2013

2015F-2

Consolidated Statements of IncomeOperations for the Years Ended December 31, 2014, 2013,2016, 2015, and 2012

2014F-3

Consolidated Statements of Changes in Shareholders’ Equity for the Years Ended December 31, 2014, 2013,2016, 2015, and 2012

2014F-4

Consolidated Statements of Cash Flows for the Years Ended December 31, 2014, 2013,2016, 2015, and 2012

2014F-5

Notes to Consolidated Financial Statements

F-6

(ii) Schedules

Other schedules have not been included because they are not required, not applicable, immaterial, or the information required has been included elsewhere herein.

(iii) Exhibits

See Exhibit Index on page E-1. The Company will furnish to any eligible shareholder, upon written request, a copy of any exhibit listed upon payment of a reasonable fee equal to the Company’s expenses in furnishing such exhibit. Such requests should be addressed to to:
Investor Relations
Gulf Island Fabrication, Inc.,
16225 Park Ten Place, Suite 280
Houston, Texas 77084.

77084



GLOSSARY OF CERTAIN TECHNICAL TERMS

blasting and coating facility:

 Building and equipment used to clean steel products and prepare them for coating with marine paints and other coatings.

coping machine:

 A computerized machine that cuts ends of tubular pipe sections to allow for changes in weld bevel angles and fits onto other tubular pipe sections.

deck:

 The component of a platform on which development drilling, production, separating, gathering, piping, compression, well support, crew quartering and other functions related to offshore oil and gas development are conducted.

deepwater drilling

Drilling is typically defined as drilling that occurs in depths of 1,000 feet or more..

direct labor hours:

 Hours worked by employees directly involved in the production of the Company’s products. These hours do not include contractor labor hours and support personnel hours such as maintenance, warehousing and drafting.

dry tree system:

A system in which a platform’s well control valves and apparatus (“christmas trees”) and risers are installed and operated above water.

fixed platform:

A platform consisting of a rigid jacket which rests on tubular steel pilings driven into the seabed and which supports a deck structure above the water surface.

floating production platform:

 Floating structure that supports offshore oil and gas production equipment (MinDOC, TLP, FPSO, SPAR).

FPSO:

 Floating Production Storage and Offloading vessel. A floating vessel used by the offshore oil and gas industry for the production and processing of hydrocarbons, and for the storage of oil.

graving dock:

 A box shaped basin made of steel sheet pile walls and concrete floor into which a vessel may be floated into or out of by pumping out or in water. The end will be closed by earthen berms and a sheet pile wall that will be removed to float out vessels.

grit blast system:

 System of preparing steel for coating by using steel grit rather than sand as a blasting medium.

hydraulic plate shear:

 Machine that cuts steel by a mechanical system similar to scissors.

inshore:

 Inside coastlines, typically in bays, lakes and marshy areas.

ISO 9001-2008:

 International Standards of Operations 9001-2008 – Defines quality management system of procedures and goals for certified companies.

jacket:

 A component of a fixed platform consisting of a tubular steel, braced structure extending from the mudline of the seabed to a point above the water surface. The jacket is supported on tubular steel pilings driven into the seabed and supports the deck structure located above the level of storm waves.

MinDOC:

 Minimum Deepwater Operating Concept. Floating production platform designed for stability and dynamic response to waves consisting of three vertical columns arranged in a triangular shape connected to upper and lower pontoon sections.

modules:

 Packaged equipment usually consisting of major production, utility or compression equipment with associated piping and control system.

offshore:

 In unprotected waters outside coastlines.



piles:

 Rigid tubular pipes that are driven into the seabed to support platforms.

plasma-arc cutting system:

 Steel cutting system that uses an ionized gas cutting rather than oxy-fuel system.

platform:

 A structure from which offshore oil and gas development drilling and production are conducted.

pressure vessel:

 A metal container generally cylindrical or spheroid, capable of withstanding various internal pressure loadings.

skid unit:

 Packaged equipment usually consisting of major production, utility or compression equipment with associated piping and control system.

SPAR:

 Single Point Anchor Reservoir. A floating vessel with a circular cross-section that sits vertically in the water and is supported by buoyancy chambers (“hard tanks”) at the topused for infield flow lines and stabilized by a structure (“midsection”) hanging from the hard tanks.associated subsea infrastructure. The SPAR connects subsea production and injection wells for oil and gas production in deepwater environments.

spud barge:

 Construction barge rigged with vertical tubular or square lengths of steel pipes that are lowered to anchor the vessel.

subsea templates:

 Tubular frames which are placed on the seabed and anchored with piles. Usually a series of oil and gas wells are drilled through these underwater structures.

tension leg platform (TLP):

 A platform consisting of a floating hull and deck anchored by vertical tensioned cables or pipes connected to pilings driven into the seabed. A tension leg platform is typically used in water depths exceeding 1,000 feet.


REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM



Report of Independent Registered Public Accounting Firm
The Board of Directors and Shareholders

Gulf Island Fabrication, Inc.

We have audited the accompanying consolidated balance sheets of Gulf Island Fabrication, Inc. as of December 31, 20142016 and 2013,2015, and the related consolidated statements of income,operations, changes in shareholders’ equity, and cash flows for each of the three years in the period ended December 31, 2014.2016. 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 audits.

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

In our opinion, the financial statements referred to above present fairly, in all material respects, the consolidated financial position of Gulf Island Fabrication, Inc. at December 31, 20142016 and 2013,2015, and the consolidated results of its operations and its cash flows for each of the three years in the period ended December 31, 2014,2016, in conformity with U.S. generally accepted accounting principles.

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), Gulf Island Fabrication, Inc.’s internal control over financial reporting as of December 31, 2014,2016, based on criteria established in Internal Control—Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (2013 framework) and our report dated March 5, 2015,2, 2017, expressed an unqualified opinion thereon.


/s/ Ernst & Young LLP


New Orleans, Louisiana

March 5, 2015

2, 2017




GULF ISLAND FABRICATION, INC.

CONSOLIDATED BALANCE SHEETS

   December 31,
2014		   December 31,
2013		 
   (in thousands) 

ASSETS

    

Current assets:

    

Cash and cash equivalents

  $36,085    $36,569  

Contracts receivable, net

   80,448     98,579  

Contract retainage

   —       111  

Costs and estimated earnings in excess of billings on uncompleted contracts

   26,989     24,727  

Prepaid expenses and other

   4,510     4,862  

Inventory

   10,140     11,329  

Deferred tax assets

   2,646     9,927  

Income tax receivable

   1,350     1,365  

Assets held for sale

   10,327     14,527  
  

 

 

   

 

 

 

Total current assets

   172,495     201,996  

Property, plant and equipment, net

   224,777     223,555  

Other assets

   671     683  
  

 

 

   

 

 

 

Total assets

  $397,943    $426,234  
  

 

 

   

 

 

 

LIABILITIES AND SHAREHOLDERS’ EQUITY

    

Current liabilities:

    

Accounts payable

  $40,272    $66,054  

Billings in excess of costs and estimated earnings on uncompleted contracts

   18,766     35,006  

Accrued contract losses

   817     —    

Accrued employee costs

   7,723     7,516  

Accrued expenses and other liabilities

   5,187     3,699  
  

 

 

   

 

 

 

Total current liabilities

   72,765     112,275  

Deferred tax liabilities

   39,380     38,397  
  

 

 

   

 

 

 

Total liabilities

   112,145     150,672  

Shareholders’ equity:

    

Preferred stock, no par value, 5,000,000 shares authorized, no shares issued and outstanding

   —       —    

Common stock, no par value, 20,000,000 shares authorized, 14,539,104 issued and outstanding at December 31, 2014 and 14,493,748 at December 31, 2013, respectively

   10,090     10,012  

Additional paid-in capital

   93,828     93,125  

Retained earnings

   181,880     172,425  
  

 

 

   

 

 

 

Total shareholders’ equity

   285,798     275,562  
  

 

 

   

 

 

 

Total liabilities and shareholders’ equity

  $397,943    $426,234  
  

 

 

   

 

 

 

 December 31,
2016		 December 31,
2015
 (in thousands)
ASSETS   
Current assets:   
Cash and cash equivalents$51,167
 $34,828
Contracts receivable, net20,169
 47,060
Contracts in progress26,829
 12,822
Prepaid expenses and other3,222
 3,418
Inventory11,973
 12,936
Assets held for sale—
 4,805
Total current assets113,360
 115,869
Property, plant and equipment, net206,222
 200,384
Other assets2,826
 670
Total assets$322,408
 $316,923
LIABILITIES AND SHAREHOLDERS’ EQUITY   
Current liabilities:   
Accounts payable$9,021
 $13,604
Advance billings on contracts3,977
 7,081
Deferred revenue, current11,881
 —
Accrued contract losses387
 9,495
Accrued expenses and other liabilities10,032
 7,608
Income taxes payable50
 113
Total current liabilities35,348
 37,901
Net deferred tax liabilities23,234
 21,825
Deferred revenue, noncurrent489
 —
Other liabilities305
 —
Total liabilities59,376
 59,726
Shareholders’ equity:   
Preferred stock, no par value, 5,000,000 shares authorized, no shares issued and outstanding

 

Common stock, no par value, 20,000,000 shares authorized, 14,695,020 issued and outstanding at December 31, 2016 and 14,580,216 at December 31, 2015, respectively10,641
 10,352
Additional paid-in capital98,813
 96,194
Retained earnings153,578
 150,651
Total shareholders’ equity263,032
 257,197
Total liabilities and shareholders’ equity$322,408
 $316,923
The accompanying notes are an integral part of these financial statements.




GULF ISLAND FABRICATION, INC.

CONSOLIDATED STATEMENTS OF INCOME

OPERATIONS

(in thousands, except per share data)

   Years Ended December 31, 
   2014  2013  2012 

Revenue

  $506,639   $608,326   $521,340  

Cost of revenue:

    

Contract costs

   462,083    584,665    502,999  

Provision for loss on contract receivable

   —      —      14,501  
  

 

 

  

 

 

  

 

 

 

Total cost of revenue

   462,083    584,665    517,500  
  

 

 

  

 

 

  

 

 

 

Gross profit

   44,556    23,661    3,840  

General and administrative expenses

   20,609    11,555    9,806  
  

 

 

  

 

 

  

 

 

 

Operating income (loss)

   23,947    12,106    (5,966) 

Other income (expense):

    

Interest expense

   (37)   (237)   (153) 

Interest income

   13    3    586  

Other income (expense), net

   (99)   (337)   128  
  

 

 

  

 

 

  

 

 

 
   (123)   (571)   561  
  

 

 

  

 

 

  

 

 

 

Income (loss) before income taxes

   23,824    11,535    (5,405) 

Income taxes

   8,504    4,303    (1,314) 
  

 

 

  

 

 

  

 

 

 

Net income (loss)

  $15,320   $7,232   $(4,091) 
  

 

 

  

 

 

  

 

 

 

Per share data:

    

Basic earnings (loss) per share—common shareholders

  $1.05   $0.50   $(0.29) 
  

 

 

  

 

 

  

 

 

 

Diluted earnings (loss) per share—common shareholders

  $1.05   $0.50   $(0.29) 
  

 

 

  

 

 

  

 

 

 

 Years Ended December 31,
 2016 2015 2014
Revenue$286,326
 $306,120
 $506,639
Cost of revenue:     
Contract costs261,473
 321,276
 462,083
Gross profit (loss)24,853
 (15,156) 44,556
General and administrative expenses19,670
 16,256
 17,409
Asset impairment—
 7,202
 3,200
Operating income (loss)5,183
 (38,614) 23,947
Other income (expense):     
Interest expense(332) (165) (37)
Interest income24
 26
 13
Other income (expense), net681
 20
 (99)
Total Other income (expense)373
 (119) (123)
Net income (loss) before income taxes5,556
 (38,733) 23,824
Income tax expense (benefit)2,041
 (13,369) 8,504
Net income (loss)$3,515
 $(25,364) $15,320
Per share data:     
Basic and diluted earnings (loss) per share—common shareholders$0.24
 $(1.75) $1.05
The accompanying notes are an integral part of these financial statements.




GULF ISLAND FABRICATION, INC.

CONSOLIDATED STATEMENT OF CHANGES IN SHAREHOLDERS’ EQUITY

(in thousands, except share data)

          Additional
Paid-In
Capital		  Retained
Earnings		  Total
Shareholders’
Equity		 
   Common Stock    
   Shares   Amount    

Balance at January 1, 2012

   14,376,443    $9,921   $91,933   $180,945   $282,799  

Exercise of stock options

   15,065     (8)   (63)   —      (71) 

Income tax benefit from stock compensation

   —       —      259    —      259  

Net loss

   —       —      —      (4,091)   (4,091) 

Vesting of restricted stock

   61,152     (79)   (717)   —      (796) 

Compensation expense restricted stock

   —       122    1,100    —      1,222  

Dividends on common stock

   —       —      —      (5,822)   (5,822) 
  

 

 

   

 

 

  

 

 

  

 

 

  

 

 

 

Balance at December 31, 2012

   14,452,660    $9,956   $92,512   $171,032   $273,500  

Exercise of stock options

   2,900     20    183    —      203  

Income tax benefit from stock compensation

   —       —      116    —      116  

Net income

   —       —      —      7,232    7,232  

Vesting of restricted stock

   38,188     (32)   (290)   —      (322) 

Compensation expense restricted stock

   —       68    604    —      672  

Dividends on common stock

   —       —      —      (5,839)   (5,839) 
  

 

 

   

 

 

  

 

 

  

 

 

  

 

 

 

Balance at December 31, 2013

   14,493,748    $10,012   $93,125   $172,425   $275,562  

Net income

   —       —      —      15,320    15,320  

Vesting of restricted stock

   45,356     (35)   (323)   —      (358) 

Compensation expense restricted stock

   —       113    1,026    —      1,139  

Dividends on common stock

   —       —      —      (5,865)   (5,865) 
  

 

 

   

 

 

  

 

 

  

 

 

  

 

 

 

Balance at December 31, 2014

   14,539,104    $10,090   $93,828   $181,880   $285,798  
  

 

 

   

 

 

  

 

 

  

 

 

  

 

 

 

 Common Stock 
Additional
Paid-In
Capital
 
Retained
Earnings
 
Total
Shareholders’
Equity
 Shares Amount   
Balance at January 1, 201414,493,748
 $10,012
 $93,125
 $172,425
 $275,562
Net income—
 —
 —
 15,320
 15,320
Vesting of restricted stock45,356
 (35) (323) —
 (358)
Compensation expense restricted stock—
 113
 1,026
 —
 1,139
Dividends on common stock—
 —
 —
 (5,865) (5,865)
Balance at December 31, 201414,539,104
 $10,090
 $93,828
 $181,880
 $285,798
Net loss—
 —
 —
 (25,364) (25,364)
Vesting of restricted stock41,112
 (9) (70) —
 (79)
Compensation expense restricted stock—
 271
 2,436
 —
 2,707
Dividends on common stock—
 —
 —
 (5,865) (5,865)
Balance at December 31, 201514,580,216
 $10,352
 $96,194
 $150,651
 $257,197
Net income—
 —
 —
 3,515
 3,515
Vesting of restricted stock114,804
 (23) (194) —
 (217)
Compensation expense restricted stock—
 312
 2,813
 —
 3,125
Dividends on common stock—
 —
 —
 (588) (588)
Balance at December 31, 201614,695,020
 $10,641
 $98,813
 $153,578
 $263,032
The accompanying notes are an integral part of these financial statements.



GULF ISLAND FABRICATION, INC.

CONSOLIDATED STATEMENTS OF CASH FLOWS

(in thousands)

   Years Ended December 31, 
   2014  2013  2012 

Operating activities:

    

Net income (loss)

  $15,320   $7,232   ($4,091) 

Adjustments to reconcile net income (loss) to net cash provided by operating activities:

    

Depreciation

   26,436    25,087    23,396  

Provision for losses on contract receivables

   —      —      14,501  

Asset impairment

   3,200    —      —    

Allowance for doubtful accounts

   3,168    887    —    

Loss on the sale of assets

   86    353    —    

Deferred income taxes

   8,264    3,788    (1,848) 

Stock-based compensation expense

   1,139    672    (259) 

Excess tax benefits from share-based payment arrangements

   —      (116)   1,222  

Changes in operating assets and liabilities:

    

Contracts receivable, net

   14,963    (55,353)   (1,937) 

Contract retainage

   111    1,187    3,015  

Costs and estimated earnings in excess of billings on uncompleted contracts

   (2,262)   1,590    (13,335) 

Billings in excess of costs and estimated earnings on uncompleted contracts

   (16,240)   9,418    (20,865) 

Accounts payable

   (25,782)   16,569    28,983  

Prepaid subcontractor costs

   —      33,145    (23,414) 

Prepaid expenses and other assets

   352    (385)   (1,113) 

Inventory

   1,189    (6,325)   1,254  

Accrued contract losses

   817    (3,790)   3,790  

Accrued employee costs

   (154)   1,854    944  

Accrued expenses

   1,488    (1,462)   2,551  

Current income taxes

   15    3,652    (1,757) 
  

 

 

  

 

 

  

 

 

 

Net cash provided by operating activities

  $32,110   $38,003   $11,037  

Cash flows from investing activities:

    

Capital expenditures, net

   (27,658)   (21,353)   (35,890) 

Proceeds on the sale of equipment

   929    551    —    
  

 

 

  

 

 

  

 

 

 

Net cash used in investing activities

   (26,729)   (20,802)   (35,890) 

Cash flows from financing activities:

    

Borrowings against notes payable

   22,000    45,000    —    

Payments on notes payable

   (22,000)   (45,000)   —    

Proceeds from exercise of stock options

   —      203    17  

Excess tax benefit from share-based payment arrangements

   —      116    259  

Payments of dividends on common stock

   (5,865)   (5,839)   (5,822) 
  

 

 

  

 

 

  

 

 

 

Net cash used in financing activities

   (5,865)   (5,520)   (5,546) 
  

 

 

  

 

 

  

 

 

 

Net (decrease) increase in cash and cash equivalents

   (484)   11,681    (30,399) 

Cash and cash equivalents at beginning of period

   36,569    24,888    55,287  
  

 

 

  

 

 

  

 

 

 

Cash and cash equivalents at end of period

  $36,085   $36,569   $24,888  
  

 

 

  

 

 

  

 

 

 

Supplemental cash flow information:

    

Interest paid

  $169   $843   $99  
  

 

 

  

 

 

  

 

 

 

Income taxes paid (received), net of payments (refunds)

  $225   $3,138   $2,291  
  

 

 

  

 

 

  

 

 

 
Schedule of Noncash Financing Activities  

Reclassification of assets to held for sale

   —     $14,527    —    
  

 

 

  

 

 

  

 

 

 

 Years Ended December 31,
 2016 2015 2014
Operating activities:     
Net income (loss)$3,515
 $(25,364) $15,320
Adjustments to reconcile net (loss) income to net cash provided by operating activities:     
Depreciation25,448
 26,204
 26,436
Amortization of deferred revenue(5,223) —
 —
Asset impairment—
 7,202
 3,200
Allowance for doubtful accounts493
 448
 3,168
(Gain) loss on the sale of assets(757) (10) 86
Deferred income taxes1,409
 (14,061) 8,264
Stock-based compensation expense3,125
 2,707
 1,139
Changes in operating assets and liabilities:     
Contracts receivable, net28,067
 31,740
 15,074
Contracts in progress(13,984) 14,167
 (2,262)
Advance billings on contracts(3,197) (11,685) (16,240)
Accounts payable(12,757) (26,668) (25,782)
Prepaid expenses and other assets230
 1,092
 352
Inventory6,501
 931
 1,189
Accrued contract losses(9,108) 8,678
 817
Deferred revenue(11,656) —
 —
Deferred compensation305
 —
 —
Accrued expenses2,003
 (5,381) 1,334
Current income taxes(63) 615
 15
Net cash provided by operating activities14,351
 10,615
 32,110
Cash flows from investing activities:     
Cash received in acquisition3,035
 —
 —
Capital expenditures, net(6,795) (6,018) (27,658)
Proceeds from the sale of equipment6,458
 11
 929
Net cash provided by (used in) investing activities2,698
 (6,007) (26,729)
Cash flows from financing activities:     
Borrowings against notes payable—
 —
 22,000
Payments on notes payable—
 —
 (22,000)
Payment of financing costs(122) —
 —
Payments of dividends on common stock(588) (5,865) (5,865)
Net cash used in financing activities(710) (5,865) (5,865)
Net increase (decrease) in cash and cash equivalents16,339
 (1,257) (484)
Cash and cash equivalents at beginning of period34,828
 36,085
 36,569
Cash and cash equivalents at end of period$51,167
 $34,828
 $36,085
Supplemental cash flow information:     
Interest paid$332
 $165
 $169
Income taxes paid (refunds received), net$377
 $(152) $225
Schedule of noncash financing activities
Reclassification of property, plant and equipment to assets held for sale$—
 $4,805
 $—
Reclassification of assets held for sale to inventory$—
 $3,727
 $—
The accompanying notes are an integral part of these financial statements.



GULF ISLAND FABRICATION, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

DECEMBER 31, 2014

2016


1. ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Basis of Presentation

Gulf Island Fabrication, Inc. ("Gulf Island"), and together with its subsidiaries (the “Company”, “we”("the Company," "we" or “our”"our"), is a leading fabricator of offshore drillingcomplex steel structures and marine vessels used in energy extraction and production, platformspetrochemical and otherindustrial facilities, power generation and alternative energy projects and shipping and marine transportation operations. We also provide related installation, hookup, commissioning, repair and maintenance services with specialized structures. The Company’s principalcrews and integrated project management capabilities. We are currently fabricating complex modules for the construction of a new petrochemical plant, completing newbuild construction of two technologically advanced offshore support and two multi-purpose service vessels and recently fabricated wind turbine pedestals for the first offshore wind power project in the United States. We also constructed one of the largest liftboats servicing the Gulf of Mexico ("GOM"), one of the deepest production jackets in the GOM and the first SPAR fabricated in the United States. Our customers include U.S. and, to a lesser extent, international energy producers, petrochemical, industrial, power and marine operators. Our corporate officeheadquarters is located in Houston, Texas, and itswith fabrication facilities are located in Houma, Jennings and Lake Charles, Louisiana, and San Patricio County,Aransas Pass and Ingleside, Texas. The Company’s principal markets are concentrated in the offshore regions and along the coast

On January 1, 2016, we acquired substantially all of the assets and assumed certain specified liabilities of LEEVAC Shipyards, L.L.C. and its affiliates (collectively, “LEEVAC”), through our newly formed wholly-owned subsidiary, Gulf Island Shipyards, L.L.C. in an all cash transaction. See further discussion of Mexico. the LEEVAC transaction as discussed in Note 2 - "LEEVAC Transaction."

The consolidated financial statements include the accounts of Gulf Island Fabrication, Inc. and its majority owned subsidiaries. All significant intercompany balances and transactions have been eliminated in consolidation.

Gulf Island Fabrication, Inc. (“Gulf Island”) serves as a holding company and conducts all of its operations through its subsidiaries, which include Gulf Island, L.L.C. and Gulf Marine Fabricators, L.P. (both of which perform fabrication of offshore drilling and production platforms and other specialized structures used in the development and production of oil and gas reserves), Gulf Island Marine Fabricators, L.L.C. (which performs marine fabrication and construction services), Dolphin Services, L.L.C. (which performs offshore and onshore fabrication and construction services), Dolphin Steel Sales, L.L.C. (which sells steel plate and other steel products) and Gulf Island Resources, L.L.C. (which hires laborers with similar rates and terms as those provided by contract labor service companies).


Operating Cycle


The lengths of our contracts vary, but are typically longer than one year in duration. Consistent with industry practice, assets and liabilities have been classified as current under the operating cycle concept whereby all contract-related items are regarded as current regardless of whether cash will be received or paid within a twelve month period. Assets and liabilities classified as current which may not be paid or received within the next twelve months include contract retainage, costscontracts in progress and estimated earnings in excess ofadvanced billings on uncompleted contracts, and billings in excess of costs and estimated earnings on uncompleted contracts. However, any variation from normal contract terms would cause classification of assets and liabilities as long-term.


Use of Estimates

The preparation of financial statements in conformity with accounting principles generally accepted in the United States (GAAP) requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent liabilities at the date of the financial statements and the reported amounts of revenue and expense during the reporting period. Areas requiring significant estimates by our management include asset impairments, value of assets held for sale, provisions for contract losses, contract revenues, costs and profits, and the application of the percentage-of-completion (POC) method of accounting.accounting and the determination of the allowance of doubtful accounts. Actual results could differ from those estimates.

Cash Equivalents

The Company considers all highly liquid investments with maturities of three months or less when purchased to be cash equivalents.

Allowance for Doubtful Accounts

We routinely review individual contracts receivable balances and make provisions for probable doubtful accounts as we deem appropriate. Among the factors considered during the review are the financial condition of

GULF ISLAND FABRICATION, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—(Continued)

our customer and their access to financing, underlying disputes on the account, age and amount of the account and overall economic conditions. Accounts are written off only when all reasonable collection efforts are exhausted.

Our principal customers include major and large independent oil and gas companies and their contractors and marine vessel operators and their contractors. This concentration of customers may impact our overall exposure to credit risk, either positively or negatively, in that customers may be similarly affected by changes in economic or other conditions. Receivables are generally
GULF ISLAND FABRICATION, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS-(Continued)

not collateralized. In the normal course of business, we extend credit to our customers on a short-term basis.

During the fourth quarter See Note 4 - "Contracts Receivable and Retainage" for a detail of 2014, the Company included anour allowance for bad debt in the amount of $3.6 million in connection with negotiations of an outstanding contract receivable balance with a deepwater offshore customer related to a deepwater hull project completed during the first quarter of 2014.

At December 31, 2013, the Company included an allowance for bad debt in the amount of $0.9 million in connection with a vessel upgrade and outfitting project. The Company collected $0.6 million of this balance as part of the final settlement during the fourth quarter 2014.

doubtful accounts.

Stock-Based Compensation

Awards under the Company’s stock-based compensation plans are calculated using a fair-valuefair value based measurement method. Share-based compensation expense for share based awards is recognized only for those awards that are expected to vest. We use the straight-line method to recognize share-based compensation expense over the requisite service period of the award.

Inventory

Inventory consists of materials and production supplies and is stated at the lower of cost or market determined on the first-in, first-out basis.

Assets Held for Sale

Assets held for sale are required to be measured at the lower of their carrying amount or fair value less cost to sell. Management determined fair value with the assistance of third party valuation specialists, assuming the sale of the underlying assets individually or in aggregate to a willing market participant, including normal ownership risks assumed by the purchaser, and the sale of certain components at scrap value. We estimated fair value relying primarily on the cost approach and applied the market approach where comparable sales transactionSee Note 6 - “Fair Value Measurements” for additional information was readily available. The cost approach is based on current replacement and reproduction costs of the subject assets less depreciation attributable to physical, functional, and economic factors. The market approach involves gathering data on sales and offerings of similar assets in order to value the subject assets. This approach also includes the assumption for the measurement of the loss in value from physical, functional, and economic factors. The fair value of theregarding our assets held for sale at December 31, 2014 represent Level 3 fair value measurements (as defined by GAAP), based primarily on the limited availability of market pricing information for either identical or similar items.

sale.

Workers Compensation Liability

The Company and its subsidiaries are self-insured for workers’ compensation liability except for losses in excess of varying threshold amounts. Our workers compensation liability balance was $2.7 million and $1.9$3.4 million as of December 31, 20142016 and 2013,$2.6 million as of December 31, 2015, respectively.

GULF ISLAND FABRICATION, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—(Continued)

Property, Plant and Equipment

Property, plant and equipment is stated at cost less accumulated depreciation. Depreciation is computed on the straight-line basis over the estimated useful lives of the assets, which range from 3three to 25 years. Ordinary maintenance and repairs, which do not extend the physical or economic lives of the plant or equipment, are charged to expense as incurred.

Long-Lived Assets

The Company records

We evaluate impairment losses on long-lived assets or asset groups used in operations when events and circumstances indicate that the assets or asset groups might not be impairedrecoverable. If events and circumstance indicate that the assets or asset groups might not be recoverable, the expected future undiscounted cash flows that are estimated to be generated by thosefrom the assets or asset groups are estimated and compared with the carrying amount of the assets or asset groups. If the sum of the estimated undiscounted cash flows is less than the carrying amountsamount of thosethe assets or asset groups. Thegroups, an impairment loss is determinedrecorded.
An impairment loss is measured by comparing the fair value of the asset or asset group to its carrying amount and recording the excess of the carrying amount of the asset or asset group over its fair value as an impairment charge. An asset group constitutes the minimum level for which identifiable cash flows are principally independent of the cash flows of other asset or liability groups. Fair value is determined based on discounted cash flows or appraised values, as appropriate. Due to the slow down in our industry as a result of the downturn in oil prices, we identified indicators of impairment at our Texas facility. Management performed an undiscounted cash flow analysis during the fourth quarter of 2014 for the Texas facility, which did not result in impairment.

Fair Value Measurements

The Company bases its fair value determinations of the carrying value of other financial assets and liabilities on an evaluation of their particular facts and circumstances and valuation techniques that require judgments and estimates. Valuation techniques used to measureWe base our fair value maximize the use of relevant observable inputs and minimize the use of unobservable inputs. Fair value is estimateddeterminations by applying the following hierarchy, which prioritizes the inputs used to measure fair value into three levels and bases the categorization within the hierarchy upon the lowest level of input that is available and significant to the fair value measurement:

Level 1—inputs1-inputs are based upon quoted prices for identical instruments traded in active markets.


Level 2—inputs2-inputs are based upon quoted prices for similar instruments in active markets, quoted prices for similar or identical instruments in inactive markets and model-based valuation techniques for which all significant assumptions are observable in the market or can be corroborated by observable market data for substantially the full term of the assets and liabilities.

market.


Level 3—inputs3-inputs are generally unobservable and typically reflect management’s estimates of assumptions that market participants would use in pricing the asset or liability. The fair values are therefore determined using model-based techniques thatThese include option pricing models, discounted cash flow models and similar valuation techniques.

The carrying amounts that we have reported for financial instruments, including cash and cash equivalents, accounts receivables and accounts payable approximate their fair values.


SeeNote 5-6-“Assets Held for Sale”Fair Value Measurements” for additional information regarding fair value measurements.


GULF ISLAND FABRICATION, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS-(Continued)

Revenue Recognition

The Company uses

We use the percentage-of-completion accounting method for constructionfabrication contracts. Revenue from fixed-price or unit rate contracts is recognized on the percentage-of-completion method, computed by the efforts-expended method which measures the percentage of labor hours incurred to date as compared to

GULF ISLAND FABRICATION, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—(Continued)

estimated total labor hours for each contract. This progress percentage is applied to estimatedour estimate of total anticipated gross profit for each contract to determine gross profit earned to date. Revenue recognized in a period for a contract is the amount of gross profit earned for that period plus the costs incurred on the contract during the period.

Under a unit rate contract, material items or labor tasks are assigned unit rates of measure. The unit rates of measure will generally be an amount of dollars per ton, per foot, per square foot or per item installed. A typical unit rate contract can contain hundreds to thousands of unit rates of measure. Profit margins are built into the unit rates.

Profit incentives are included in revenue when their realization is probable. Claims for extra work or changes in scope of work are included in revenue when the amount can be reliably estimated and collection is probable. To the extent work from changes in scope have been approved for scope, but not as to price, revenue is recognized up to cost incurred. Changes in job performance, job conditions, and estimated profitability, including those arising from contract penalty provisions, and final contract settlements may result in revisions to costs and income and are recognized in the period in which the revisions are determined. For the years ended December 31, 2016, 2015, and 2014, there was no significant revenue related to unapproved change orders or claims.
Some contracts include a total or partial reimbursement to us of any costs associated with specific capital projects required by the fabrication process. If a particular capital project provides future benefits to us, the cost to build the capital project will be capitalized, and the revenue for the capital project will increase the estimated profit in the contract.

See Note 3 -“Contract costs include all direct material, laborRevenue and subcontract costsPercentage-of-Completion Method” for additional information regarding our percentage-of-completion accounting and those indirect costs related to contract performance, such as indirect labor, supplies and tools. Also included in contract costs are a portion of those indirect contract costs related to plant capacity, such as depreciation, insurance and repairs and maintenance. These indirect costs are allocated to jobs based on actual direct labor hours incurred. Profit incentives are included in revenue when their realization is probable. Claims for extra work or changes in scope of work are included in revenue when the amount can be reliably estimated and collection is probable. Changes in job performance, job conditions, and estimated profitability, including those arising from contract penalty provisions, and final contract settlements may result in revisions to costs and income and are recognized in the period in which the revisions are determined.

Some of our contracts contain provisions that require us to pay liquidated damages if we are responsible for the failure to meet specified contractual milestone dates and the applicable customer asserts a claim under those provisions. Those contracts define the conditions under which our customers may make claims against us for liquidated damages. In 2014, we had one asserted liquidated damages claim in the amount of $0.3 million that was fully settled, related to the fabrication of an offshore supply vessel. Other than the aforementioned claim, as of March 5, 2015, we were not aware of any asserted liquidated damage claims by any of our customers.

At December 31, 2014, we had no revenue related to unapproved change orders on projects. At December 31, 2013, we recorded revenue totaling $0.1 million related to certain change orders on two projects which had been approved as to scope but not price. At December 31, 2013, we recorded revenue totaling $3.7 million related to re-measure units and quantities on a unit rate contract. At December 31, 2012, we recorded revenue totaling $5.2 million related to certain change-orders on four projects which were approved as to scope but not price. At December 31, 2012, we recorded revenue totaling $7.7 million related to re-measure units and quantities on a unit rate contract. All matters relating to unapproved items have since been resolved.

Provisions for estimated losses on uncompleted contracts are made in the period in which such losses are determined. We recognized contract losses of $6.6 million, $30.8 million, and $12.5 million in the years ended December 31, 2014, 2013, and 2012, respectively.

During the quarter ended September 30, 2013, we entered into discussions with a large deepwater customer concerning our customer’s request for a reduction in scope of the project, whereby remaining completion and integration work would be performed at the integration site by a different integration contractor. We transferred the project deliverables to the integration contractor’s site and removed from backlog estimated revenue of $25.5 million and estimated labor hours of 271,000 hours representing our previous estimate of remaining work to

GULF ISLAND FABRICATION, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—(Continued)

complete the project during the third quarter of 2013. Throughout the fourth quarter of 2013 and into the first quarter 2014, we continued negotiations with our large deepwater customer with respect to final amounts due to us and to our subcontractors for claims for all work performed prior to transition of the scope of work to the customer-designated replacement contractor. We executed a final change order to this contract with the customer in early March 2014 that provided for a final payment of $11.0 million by our customer that was received during the first half of 2014. We recorded an additional loss provision of $18.2 million in the fourth quarter of 2013 related to this project. For the year ended December 31, 2013, we recognized estimated contract losses of $29.6 million primarily as a result of our inability to recover certain costs and the de-scoping of this contract.

recognition.

Income Taxes

Income taxes have been provided using the liability method. 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 using enacted rates expected to be in effect during the year in which the basis differences reverse. A valuation allowance is provided to reserve for deferred tax assets if, based upon the available evidence, it is more likely than not that some or all of the deferred tax assets will not be realized.

Reserves for uncertain tax positions are recognized when the positions are more likely than not to not be sustained upon audit. Interest and penalties on uncertain tax positions are recorded in income tax expense. Our federal tax returns have been examined and settled through the 20072012 tax year. There were no material uncertain tax positions recorded for the years presented in these statements.

See also Note 9 - "Income Taxes."

New Accounting Standards

On May 28, 2014, the Financial Accounting Standards Board or FASB,("FASB") issued Accounting Standards Update (ASU)("ASU") No. 2014-09, “Revenue from Contracts with Customers” (Topic 606), which supersedes the revenue recognition requirements in FASB Accounting Standard Codification (ASC) Topic 605, “Revenue Recognition.” ASU No. 2014-09 requires entities to recognize revenue in a way that depicts the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. ASU 2014-09 requires retrospective application and will be effective for financial statements issued for fiscal years beginning after December 15, 2016,2017, and interim periods within those fiscal years. Early application is permitted. We use the percentage-of-completion accounting method to account for our fixed-price or unit rate contracts, computed by the efforts-expended method which measures the percentage of labor hours incurred to date as compared to estimated total labor hours for each contract. We understand that this method will still be allowed under the update; however, there are additional criteria to consider for the requirements to recognize revenue under the percentage-of-completion method. We are in process of reviewing our contracts to ensure that we will continue to be able to apply our revenue recognition policies, but we are evaluating whether implementation of this update will have a material effect to our results of operations. We intend to use the modified retrospective model in adopting this standard, which will require a cumulative catch up adjustment, if any, on January 1, 2018.
In July 2015, the FASB issued ASU 2015-11, “Inventory (Topic 330): Simplifying the Measurement of Inventory,” which requires entities to measure inventory at the lower of cost or net realizable value rather than at the lower of cost or market. Net realizable value is the estimated selling price in the ordinary course of business less reasonably predictable costs of completion, disposal and transportation. ASU 2015-11 will be effective for annual periods beginning after December 15, 2016, and early adoption is permitted. We have not elected to early adopt this guidance. We do not expect the adoption of ASU 2015-11 will have a material impact on our financial position, results of operations and related disclosures.
GULF ISLAND FABRICATION, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS-(Continued)


In September 2015, the FASB issued ASU 2015-16, “Simplifying the Accounting for Measurement-Period Adjustments,” which eliminates the requirement that an acquirer in a business combination account for measurement-period adjustments retrospectively. Instead, an acquirer will recognize a measurement-period adjustment during the period in which it determines the amount of the adjustment. ASU 2015-16 will be effective for annual periods beginning after December 15, 2016, and early adoption is permitted. We have not elected to early adopt this guidance. We do not expect the adoption of ASU 2015-16 will have a material impact on our financial position, results of operations and related disclosures.

In February 2016, the FASB issued ASU 2016-02, “Leases,” which requires lessees to record most leases on their balance sheets but recognize expenses in a manner similar to current guidance. ASU 2016-02 will be effective for annual periods beginning after December 15, 2018. The Companyguidance is required to be applied using a modified retrospective approach. We are currently evaluating the effect that ASU 2016-02 will have on our financial position, results of operations and related disclosures; however, we expect to record our lease obligations on our balance sheet. See Note 5 for disclosure of our minimum lease payments.

In March 2016, the FASB issued ASU 2016-09, “Improvements to Employee Share-Based Payment Accounting,” which amends several aspects of the accounting for share-based payment transactions, including the income tax consequences, classification of awards as either equity or liabilities, and classification on the statement of cash flows. This guidance requires all excess tax benefits or deficiencies to be recognized as income tax benefit or expense in the income statement, and all excess tax benefits to be classified with other income tax cash flows as operating activities. This portion of the amendment should be applied prospectively. The guidance also changes the timing of when excess tax benefits are recognized and the methods available to an entity to estimate the impact of forfeitures related to share-based awards. These two amendment topics should be applied using a modified retrospective transition method, and would require recognition of cumulative-effect adjustments to equity as of the beginning of the period in which the guidance is adopted. The guidance also classifies cash paid by an employer when directly withholding shares for tax-withholding purposes as a financing activity on the statement of cash flows. This portion of the amendment should be applied retrospectively. ASU 2016-09 will be effective for annual periods beginning after December 15, 2016. Early adoption is permitted in any interim or annual period. We have not elected to early adopt this guidance. We are currently evaluating the effect that ASU 2016-09 will have on our financial position and related disclosures.

In June 2016, the FASB issued ASU 2016-13, “Financial Instruments - Credit Losses - Measurement of Credit Losses on Financial Instruments,” which changes the way companies evaluate credit losses for most financial assets and certain other instruments. For trade and other receivables, held-to-maturity debt securities, loans and other instruments, entities will be required to use a new forward-looking “expected loss” model to evaluate impairment, potentially resulting in earlier recognition of allowances for losses. The new standard also requires enhanced disclosures, including the requirement to disclose the information used to track credit quality by year of origination for most financing receivables. ASU 2016-13 will be effective for annual periods beginning after December 15, 2019. Early adoption is permitted for all entities for annual periods beginning after December 15, 2018. We have not elected to early adopt this guidance. The guidance must be applied using a cumulative-effect transition method. We are currently evaluating the effect that ASU 2016-13 will have on our financial position, results of operations and related disclosures.

During 2016, we adopted ASU 2014-15, "Presentation of Financial Statements - Going Concern," for our fiscal year ending December 31, 2016.  Based on management’s evaluation, which covered the one year period following our 2016 Form 10-K filing, we did not identify any conditions or events that raise substantial doubt about our ability to continue as a going concern.  Accordingly the adoption of this new standardguidance did not have an impact on itsour financial statements.

position, results of operations and related disclosures.


2. CONTRACTS RECEIVABLE AND RETAINAGE

The principal customersLEEVAC TRANSACTION


On January 1, 2016, we acquired substantially all of the Company include majorassets and large independent oilassumed certain specified liabilities of LEEVAC Shipyards, L.L.C. and gas companiesits affiliates (“LEEVAC”). The purchase price for the acquisition was $20.0 million, subject to a working capital adjustment whereby we received a dollar-for-dollar reduction for the assumption of certain net liabilities of LEEVAC and their contractors and marine vessel operators and their contractors. Of our contracts receivable balancesettlement payments applied from sureties on certain ongoing fabrication projects that were assigned to us in the transaction. After taking into account these adjustments, we received approximately $1.6 million in cash at December 31, 2014, $47.1 million, or 58.5%, is for three customers.

closing. During the fourth quarter, we finalized our working capital true-up with the seller and received $1.4 million for additional working capital resulting in an adjustment to the initial purchase price accounting values as further discussed below.


Included in our consolidated balance sheet as of 2014,December 31, 2016 are assets of $52.2 million and liabilities of $54.0 million from the Company included an allowance for bad debtoperations and assets acquired in the amountLEEVAC transaction. The results of $3.6LEEVAC are included in our consolidated statements of operations for the year ended December 31, 2016. Revenue and net (loss) income included in our results of operations and attributable to the assets and operations acquired in the LEEVAC transaction were $75.6 million and $(1.8) million for the
GULF ISLAND FABRICATION, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS-(Continued)

year ended December 31, 2016, respectively. Included in revenue was $5.2 million in connectionnon-cash amortization of deferred revenue related to the values assigned to the contracts acquired in the LEEVAC transaction.
The facilities acquired in the LEEVAC transaction are leased and operated under lease and sublease agreements as follows:

Jennings Shipyard -Our Jennings Shipyard is an 180-acre complex five miles east of Jennings, Louisiana, on the west bank of the Mermentau River approximately 25 miles north of the Intracoastal waterway that we lease from a third party. The Jennings Shipyard includes over 100,000 square feet of covered fabrication area including a panel line, pipe shop and 3,000 feet of water frontage with negotiationstwo launch ways and four covered construction bays. The lease, including exercisable renewal options, extends through January 2045.

Lake Charles Shipyard - Our Lake Charles Shipyard is a 10-acre complex 17 miles from the Gulf of an outstanding contract receivable balanceMexico on the Calcasieu River near Lake Charles, Louisiana, that we sublease from a third party. The Lake Charles Shipyard includes 1,100 feet of bulkhead water frontage with a customer relatedwater depth of 40 feet located one mile from the Gulf Intracoastal Waterway and is located near multiple petrochemical plants. The sublease, including exercisable renewal options (subject to sublessor renewals), extends through July 2038.

Prospect Shipyard - We lease a deepwater hull project that was completed during35-acre complex 26 miles from the first quarterGulf of 2014.

At DecemberMexico near Houma, Louisiana, from the former owner of LEEVAC Shipyards, currently the Senior Vice President of our Shipyards division. Payment terms are approximately $67,000 per month. The lease expires 90 days following the completion of either of the two vessels currently under construction at the facility, but no later than August 31, 2013,2017. We expect to move the Company included an allowance for bad debtmachinery and equipment at this shipyard to our remaining Shipyard division facilities prior to or at expiration of the lease.


Strategically, the LEEVAC transaction expands our marine fabrication and repair and maintenance presence in the amount of $0.9 million in connection with a vessel upgrade and outfitting project. The Company collected $0.6Gulf South market. We acquired approximately $121.2 million of this balance as partnewbuild construction backlog inclusive of approximately $9.2 million of purchase price fair value allocated to four, newbuild construction projects to be delivered in 2017 and 2018 for two customers. Additionally, we hired 380 employees representing substantially all of the final settlementformer LEEVAC employees.

We finalized our working capital true-up with the seller during the fourth quarter 2014.

of 2016, which resulted in an additional receipt of cash of $1.4 million. We have recorded adjustments to the initial purchase price accounting values based upon the actual working capital values that we presented. Our working capital true-up resulted from a $2.1 million reduction in the seller payment owed for prepaid contracts and a $3.6 million decrease in the actual value of working capital (primarily accounts receivable and accounts payable) that we received. We also recorded an adjustment of $2.1 million to the purchase price valuation allocated to machinery and equipment. The tables below present the total cash received as reported in our consolidated statements of cash flows, the amounts received from the seller and the corresponding fair values assigned to the assets and liabilities acquired from LEEVAC which includes the effect of the working capital true-up and our updated valuation of machinery and equipment.

   As Originally Reported Adjustment from Working Capital True-up Valuation Adjustment Fair Value
Assets:        
 Accounts receivable $3,544
 $(1,882) $—
 $1,662
 Inventory 4,938
 724
 —
 5,662
 Prepaid expenses and other assets —
 57
 —
 57
 Machinery and equipment 23,056
 —
 2,118
 25,174
 Intangible assets (leasehold interests) 2,123
 —
 —
 2,123
Liabilities:       —
 Accounts payable and accrued expenses 6,003
 2,464
 —
 8,467
 Deferred revenue and below market contracts 29,246
 —
 —
 29,246
Net cash received from seller $1,588
 $3,565
 $(2,118) $3,035

GULF ISLAND FABRICATION, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—STATEMENTS-(Continued)

3. CONTRACTS RECEIVABLE

Amounts due on contracts as


   As Originally Reported Adjustment from Working Capital True-up Adjusted
Consideration received upon acquisition of LEEVAC:      
 
Seller payment for prepaid contracts (1)
 $16,942
 $(2,118) $14,824
 
Surety payments related to assigned contracts (2)
 7,125
 —
 7,125
Sub-total 24,067
 (2,118) 21,949
Less:      
 Working capital assumed 2,479
 (3,565) (1,086)
 Net cash due to the Company 1,588
 1,447
 3,035
Sub-total 4,067
 (2,118) 1,949
Purchase price $20,000
 $—
 $20,000
__________
(1)Payment from seller for customer payments received in advance of progress on contracts assigned to us concurrent with the closing of the LEEVAC transaction.
(2)Payments from sureties in connection with the release of further obligations related to contracts assigned to us concurrent with the closing of the LEEVAC transaction.

Pro Forma Results of Acquisitions

The results of the LEEVAC Transaction are fully incorporated in our financial statements for the year ended December 31, were2016 as followsthe transaction occurred on January 1, 2016. The table below presents our pro forma results of operations for the year ended December 31, 2015 assuming that we acquired substantially all of the assets and certain specified liabilities of LEEVAC on January 1, 2015 (in thousands):

   2014   2013 

Completed contracts

    

Current receivables

  $24,667    $3,885  

Long term receivables due after one year

   —       —    

Contracts in progress:

    

Current receivables

   59,384     95,581  

Retainage due within one year

   —       111  
  

 

 

   

 

 

 
   84,051     99,577  

Less allowance for doubtful accounts

   3,603     887  
  

 

 

   

 

 

 
  $80,448    $98,690  
  

 

 

   

 

 

 

4. COSTS

Year Ended December 31, 2015 Pro forma adjustments   
  Historical results LEEVAC Adjustments  Pro forma results
Revenue $306,120
 $87,239
 $—
  $393,359
Net income (loss) $(25,364) $(4,655) $3,738
(1) 
 $(26,281)
______________
(1) Adjustments to historical results are as follows:
  Year Ended December 31, 2015
Effect of purchase price depreciation $1,217
Elimination of interest expense 2,038
Income taxes 483
Total $3,738

3. CONTRACT REVENUE AND ESTIMATED EARNINGS ON UNCOMPLETED CONTRACTS

PERCENTAGE-OF-COMPLETION METHOD

Information with respect to uncompleted contracts as of December 31, is as follows (in thousands):

   2014   2013 

Costs incurred on uncompleted contracts

  $742,608    $991,123  

Estimated profit earned to date

   53,551     40,045  
  

 

 

   

 

 

 
   796,159     1,031,168  

Less billings to date

   787,936     1,041,447  
  

 

 

   

 

 

 
  $8,223    $(10,279) 
  

 

 

   

 

 

 

 2016 2015
Costs incurred on uncompleted contracts$246,424
 $437,658
Estimated profit earned to date21,363
 7,777
Sub-total267,787
 445,435
Less billings to date244,935
 439,694
Total$22,852
 $5,741
GULF ISLAND FABRICATION, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS-(Continued)

The above amounts are included in the accompanying consolidated balance sheets at December 31, under the following captions (in thousands):

   2014  2013 

Costs and estimated earnings in excess of billings on uncompleted contracts

  $26,989   $24,727  

Billings in excess of costs and estimated earnings on uncompleted contracts

   (18,766)   (35,006) 
  

 

 

  

 

 

 
  $8,223   $(10,279) 
  

 

 

  

 

 

 

5. ASSETS HELD FOR SALE

Assets held

 2016 2015
Contracts in progress$26,829
 $12,822
Advance billings on contracts(3,977) (7,081)
Total$22,852
 $5,741
Provision for sale consistestimated losses

Provisions for estimated losses on uncompleted contracts are made in the period in which such losses are determined. We recognized contract losses of $1.8 million, $33.9 million, and $6.6 million in the years ended December 31, 2016, 2015, and 2014, respectively. Contract losses for the year ended December 31, 2016 were primarily attributable to decreasing margins on fabrication work due to continued depressed oil and gas prices within our Fabrication division and the movement of vessels in progress from our leased Prospect Shipyard to our owned Houma Shipyard within our Shipyards division. Contract losses for the year ended December 31, 2015 were primarily due to $24.5 million related to a partially constructed topside,decrease in the contract price due to final weight re-measurements and our inability to recover certain costs on disputed change orders related valves, piling and equipment that we acquired fromto a customer following its default under a contract for alarge deepwater project which was delivered in 2012. Assets held for sale are required2015. In addition, we increased accrued contract losses associated with our remaining contracts by approximately $9.4 million during 2015 due to be measured at the lower of their carrying amount or fair value less cost to sell. Management determined fair value of these assets with the assistance of third party valuation specialists, assuming the sale of the underlying assets individually or in the aggregate to a willing market participant, including normal ownership risks assumed by the purchaser, and the sale of certain components at scrap value. We estimated fair value relying primarily on the cost approach and applied the market approach where comparable sales transaction information was readily available. The cost approach is based on current replacement or reproduction costs of the subject assets less depreciation attributable to physical, functional, and economic factors. The market approach involves gathering data on sales and offerings of similar assets in order to value the subject assets. This approach also includes an assumption for the measurement of

GULF ISLAND FABRICATION, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—(Continued)

the loss in value from physical, functional, and economic factors. The fair value of assets held for sale represent Level 3 fair value measurements (as defined by GAAP), based primarily on the limited availability of market pricing information for either identical or similar items. In connection with its 2014 fourth quarter assessment of the fair value of assets held for sale, management determined that its previous estimate of $13.5 million for the fair value of these assets had declined to $10.3 million. As a result, we includedincreases in our income statement within generalprojected unit labor rates of our fabrication facilities. Our increases in unit labor rates were driven by our inability to absorb fixed costs due to decreases in expected oil and administrative expensesgas fabrication activity. Contract losses for the year ended December 31, 2014 an impairment charge of $3.2 million.

During the first quarter, 2014, we entered into an agreement with the manufacturer of certain equipment, representing approximately 50% of the fair value of assets held for sale, whereby the manufacturer agreedwere primarily related to assist with restoration and marketing efforts, in returntwo tank barge projects for a percentage of the sale proceeds. The agreement includes an assessment period at the end of which the two parties determine whether or not to continue marketing effortsmarine transportation company, platform supply vessels for an additional six months. It is management’s intention to continue to renew the agreement at least through the end of calendar year 2015. In addition, Management has engaged consultants to assist with the marketing efforts for the assets held for sale as well as providing assistance to secure potential FLNG (“Floating Liquefied Natural Gas”) opportunities.

To date, we have not sold, licensed, or leased any of the equipment subject to the security agreement; however, we continue to actively market the equipment,offshore marine company and believe that the fair value of the assets is recoverable through the eventual disposition of project deliverables. However, the ultimate amount we are able to recover for these assets is dependent upon various factors, including overall market interest in the project deliverables and equipment, which may change in the future. The timing of any sales we are able to consummate and the price we are able to obtain may result in a revision to the recorded fair value amount of any remaining assets held for sale.

In addition, during 2013, we included $1.0 million in assets held for sale for the sale of an aircraft, and recorded a $0.3 million loss related to the sale. The aircraft was delivered to the buyer in February 2014.

6. PROPERTY, PLANT AND EQUIPMENT

Property, plant and equipment consisted of the following at December 31 (in thousands):

   Estimated
Useful Life		   2014   2013 
   (in Years)         

Land

   n/a    $10,463    $10,463  

Buildings

   25     63,837     62,515  

Machinery and equipment

   3 to 25     228,284     198,611  

Furniture and fixtures

   3 to 5     5,354     5,143  

Transportation equipment

   3 to 5     3,748     3,224  

Improvements

   15     125,265     123,201  

Construction in progress

   n/a     1,177     7,450  
    

 

 

   

 

 

 
     438,128     410,607  

Less accumulated depreciation

     213,351     187,052  
    

 

 

   

 

 

 
    $224,777    $223,555  
    

 

 

   

 

 

 

The Company leases certain equipment used in the normal course of its operations under month-to-month lease agreements cancelable only by the Company. During 2014, 2013, and 2012, the Company expensed $5.6 million, $9.5 million, and $7.7 million, respectively, related to these leases.

GULF ISLAND FABRICATION, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—(Continued)

On June 10, 2013, the Company entered into a lease agreement with BRI 1825 Park Ten, LLC for certain office and parking facilities located in Houston, Texas to house its corporate office. Leased premises consist of office space of approximately 4,421 square feet. The term of the lease, which commenced August 1, 2013, is 64 months. The Company has an option to extend the lease termproduction platform jacket for a period of five (5) years after the expiration date. Additionally, on December 9, 2013, we entered into an amendment to the lease to effectively provide an additional 3,624 square feet of office space. The amendment, among other things, extends the term for both the existing premises and expansion premises to January 31, 2020. The schedule of minimum rental payments for operating leases (in thousands) is as follows:

2015

  $213  

2016

   217  

2017

   221  

2018

   225  

2019

   229  

Thereafter

   19  

7. INCOME TAXES

Significant components of the Company’s deferred tax assets and liabilities as of December 31 were as follows (in thousands):

   2014   2013 

Deferred tax liabilities:

    

Property, plant and equipment

  $38,070    $38,397  

Prepaid insurance

   1,310     —    
  

 

 

   

 

 

 

Total deferred tax liabilities:

   39,380     38,397  

Deferred tax assets:

    

Employee benefits

   951     677  

Uncompleted contracts

   391     931  

Stock based compensation expense

   43     65  

Allowance for uncollectible accounts

   1,261     311  

Federal net operating loss

   —       7,584  

Other

   —       359  
  

 

 

   

 

 

 

Total deferred tax assets:

   2,646     9,927  
  

 

 

   

 

 

 

Net deferred tax liabilities:

  $36,734    $28,470  
  

 

 

   

 

 

 

We utilized our entire federal net operating loss in 2014.

GULF ISLAND FABRICATION, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—(Continued)

Significant components of income tax expense for the years ended December 31 were as follows (in thousands):

   2014  2013   2012 

Current:

     

Federal

  $(105)  $—      $—    

State

   459    254     534  
  

 

 

  

 

 

   

 

 

 

Total current

   354    254     534  

Deferred:

     

Federal

   8,120    4,049     (1,749) 

State

   30    —       (99) 
  

 

 

  

 

 

   

 

 

 

Total deferred

   8,150    4,049     (1,848) 
  

 

 

  

 

 

   

 

 

 

Income taxes

  $8,504   $4,303    $(1,314) 
  

 

 

  

 

 

   

 

 

 

A reconciliation of income taxes computed at the U.S. federal statutory tax rate to the Company’s income tax expense for the years ended December 31 is as follows (in thousands):

   2014  %  2013  %  2012  % 

U.S. statutory rate

  $8,338    35.0%  $4,037    35.0%  $(1,892)   35.0% 

Increase (decrease) resulting from:

       

State income taxes

   311    1.0    317    2.7    783    (14.5) 

Qualified Production Activities

   (21)   (0.1)     

Other

   (124)   (0.2)   (51)   (0.4)   (205)   3.8  
  

 

 

  

 

 

  

 

 

  

 

 

  

 

 

  

 

 

 

Income tax expense

  $8,504    35.7%  $4,303    37.3%  $(1,314)   24.3% 
  

 

 

  

 

 

  

 

 

  

 

 

  

 

 

  

 

 

 

8. LINE OF CREDIT

The Company has a credit agreement with Whitney Bank and JPMorgan Chase Bank, N.A. that provides the Company with an $80 million revolving credit facility (the “Credit Facility”). The Credit Facility also allows the Company to use up to the full amount of the available borrowing base for letters of credit. On October 23, 2014, we entered into an amendment to our credit facility to extend the maturity datedeepwater customer.

Revenues from December 31, 2014 to December 31, 2015.

The Credit Facility is secured by substantially all of our assets other than real property located in the state of Louisiana. Amounts borrowed under the Credit Facility bear interest, at our option, at either the prime lending rate established by JPMorgan Chase Bank, N.A. or LIBOR plus 1.5 percent. We pay a fee on a quarterly basis of one-fourth of one percent per annum on the weighted-average unused portion of the Credit Facility.

At December 31, 2014, no amounts were outstanding under the Credit Facility, and we had outstanding letters of credit totaling $21.0 million, reducing the unused portion of our credit facility to $59.0 million. We are required to maintain certain financial covenants, including a minimum current ratio of 1.25 to 1.0, a net worth minimum requirement of $254.1 million, debt to net worth ratio of 0.5 to 1.0, and earnings before interest, taxes, depreciation and amortization (EBITDA) to interest expense ratio of 4.0 to 1.0. As of December 31, 2014, we were in compliance with these covenants.

GULF ISLAND FABRICATION, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—(Continued)

9. CONTINGENT LIABILITIES

The Company is subject to various routine legal proceedings in the normal conduct of its business, primarily involving commercial claims, workers’ compensation claims, and claims for personal injury under general maritime laws of the United States and the Jones Act. While the outcome of these lawsuits, legal proceedings and claims cannot be predicted with certainty, management believes that the outcome of any such proceedings, even if determined adversely,would not have a material adverse effect on the financial position, results of operations or cash flows of the Company.

10. REVENUES FROM MAJOR CUSTOMERS

The Company’s customer base is primarily concentrated in the oil and gas and marine industries. Major Customers

The Company is not dependent on any one customer, and the revenue earned from each customer varies from year to year based on the contracts awarded; however, the Company is highly dependent on a few large customers in each year, particularly customers for our major deepwater projects, as shown below. Revenues from customers comprising 10% or more of the Company’s total revenue for the years ended December 31, 2016, 2015 and 2014, respectively, are summarized as follows (in thousands):

   2014   2013   2012 

Williams Field Services-Gulf Coast Company L.P.

   *    $216,875    $124,841  

Chevron Corporation

   *     148,539     192,370  

Walter Oil & Gas

   160,173     *     *  

Anadarko

   98,644     *     *  
Customer2016 2015 2014
A$65,981
 *
 *
B*
 $55,775
 $160,173
C*
 $36,320
 *
D*
 *
 $98,644
*The customer revenue was less than 10% of the total revenue for the yearyear.

11. INTERNATIONAL REVENUES

International Revenues
The Company’s fabricated structures are used worldwide by U.S. customers operating abroad and by foreign customers. Revenues related to fabricated structures for delivery outside of the United States accounted for 10%14%, 6%, and 9%10% of the Company’s revenues for the years ended December 31, 2016, 2015 and 2014, 2013respectively, and 2012, respectively,are summarized as follows:

   December 31, 
   2014   2013   2012 
   (In millions) 

Location:

      

United States

  $456.8    $570.7    $472.4  

International

   49.8     37.6     48.9  
  

 

 

   

 

 

   

 

 

 

Total

  $506.6    $608.3    $521.3  
  

 

 

   

 

 

   

 

 

 

12. CONTRACT COSTS

follows (in thousands):

 2016 2015 2014
Location:     
United States$245,039
 $287,892
 $456,839
International41,287
 18,228
 49,800
Total$286,326
 $306,120
 $506,639
Contract Costs
Contract costs include all direct material, labor and subcontract costs and those indirect costs related to contract performance, such as indirect labor, supplies and tools. Also included in contract costs are a portion of those indirect contract costs related to plant capacity, such as depreciation, insurance and repairs and maintenance. These indirect costs are allocated to jobs based on actual direct labor hours incurred.
GULF ISLAND FABRICATION, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS-(Continued)

We define pass-through costs as material, freight, equipment rental, and sub-contractor services included in the direct costs of revenue associated with projects.

The Company uses the percentage-of-completion accounting method for fabrication contracts. Revenue from fixed-price or unit rate contracts is recognized on the percentage-of-completion method, computed by the efforts-expended method which measures the percentage of labor hours incurred to date as compared to estimated total labor hours for each contract. This progress percentage is applied to our estimate of total anticipated gross profit for each contract to determine gross profit earned to date. Revenue recognized in a period

GULF ISLAND FABRICATION, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—(Continued)

for a contract is the amount of gross profit earned for that period plus pass-through costs incurred on the contract during the period. Consequently, pass-through Pass-through costs have no impact in the determination of gross margin recognized for the related project for a particular period.

Pass-through costs as a percentage of revenue were 48.2%36.5%, 58.5%44.4% and 48.3%48.2% for the years ended December 31, 2016, 2015 and 2014, 2013respectively.

Some of our contracts contain provisions that require us to pay liquidated damages if we are responsible for the failure to meet specified contractual milestone dates and 2012, respectively.

Therethe applicable customer asserts a claim under those provisions. Those contracts define the conditions under which our customers may make claims against us for liquidated damages. In 2014, we had one asserted liquidated damages claim in the amount of $0.3 million that was fully settled, related to the fabrication of an offshore supply vessel. Other than the aforementioned claim, as of March 2, 2017, we were no prepaid subcontractor costsnot aware of any asserted or unasserted liquidated damage claims by any of our customers.


4. CONTRACTS RECEIVABLE AND RETAINAGE
Of our contracts receivable balance at December 31, 2014 and 2013 and $33.12016, $8.6 million, or 42.7%, is for three customers. Amounts due on contracts as of December 31, 2012. These costs represent uninstalled materials purchased usingwere as follows (in thousands):
 2016 2015
Completed contracts   
Current receivables$6,812
 $15,904
Long-term receivables due after one year—
 —
Contracts in progress:   
Current receivables14,248
 31,148
Retainage due within one year113
 52
Total contracts receivable21,173
 47,104
Less allowance for doubtful accounts1,004
 44
Net contracts receivable$20,169
 $47,060
Our allowance for doubtful accounts as of December 31, 2016 primarily relates to a customer funds,in our Fabrication division for the storage of an offshore drilling platform which was fully reserved in 2016. Our allowance for doubtful accounts as of December 31, 2015 related to a customer that had declared bankruptcy and are recognized as pass-through costswas fully reserved in 2015.

5. PROPERTY, PLANT AND EQUIPMENT
Property, plant and equipment consisted of the following at December 31, (in thousands):
 
Estimated
Useful Life
 2016 2015
 (in Years)    
Land- $10,463
 $10,463
Buildings25 65,894
 64,154
Machinery and equipment3 to 25 238,029
 223,521
Furniture and fixtures3 to 5 5,570
 5,354
Transportation equipment3 to 5 3,814
 3,481
Improvements15 128,437
 127,727
Construction in progress- 5,303
 2,488
Total cost  457,510
 437,188
Less accumulated depreciation  251,288
 236,804
Net book value  $206,222
 $200,384
We lease certain equipment used in the periodnormal course under month-to-month lease agreements cancelable only by us. During 2016, 2015, and 2014, we expensed $2.5 million, $5.9 million, and $5.6 million, respectively, related to these leases.
GULF ISLAND FABRICATION, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS-(Continued)

We lease our corporate office and parking facilities located in Houston, Texas. Leased premises consist of office space of approximately 8,000 square feet. The term of the materialslease matures on January 31, 2020. We also lease and/or sublease facilities in Lake Charles, Jennings and Houma, Louisiana. See note 2 "LEEVAC Transaction" for additional description of these leases. The schedule of minimum rental payments under our leases/sublease is as follows (in thousands):
 Minimum Payments
2017$852
2018439
2019325
2020115
202196
Thereafter295
Total$2,122
6. FAIR VALUE MEASUREMENTS
Recurring fair value measurements and financial instruments - The carrying amounts that we have reported for financial instruments, including cash and cash equivalents, accounts receivables and accounts payables approximate their fair values.

LEEVAC transaction - We recorded the assets and liabilities acquired from LEEVAC at their estimated fair values. See Note 2. The values assigned for the valuation of the machinery and equipment we acquired were estimated primarily using the cost method. The cost method uses the concept of replacement and/or reproductive cost of the asset less depreciation due to physical, functional and economic factors, including obsolescence. The preliminary values assigned to the intangible assets (leasehold interest) and below market contracts were calculated using the income method by applying a discounted cash flow model to the differences between the forecasted cash flows and market rates. The significant estimates and assumptions used in calculating these estimates are installed.

generally unobservable in the marketplace and reflect management’s estimates of assumptions that market participants would use. Accordingly, we have determined that the fair values assigned to the assets and liabilities acquired in the LEEVAC transaction fall within Level 3 of the fair value hierarchy.


13.Impairment of long-lived assets - We evaluate long-lived assets or asset groups used in operations for impairment losses when events and circumstances indicate that the assets or asset groups might not be recoverable. If events and circumstance indicate that the assets or asset groups might not be recoverable, the expected future undiscounted cash flows from the assets or asset groups are estimated and compared with the carrying amount of the assets or asset groups. If the sum of the estimated undiscounted cash flows is less than the carrying amount of the assets or asset groups, an impairment loss is recorded.
An impairment loss is measured by comparing the fair value of the asset or asset group to its carrying amount and recording the excess of the carrying amount of the asset or asset group over its fair value as an impairment charge. An asset group constitutes the minimum level for which identifiable cash flows are principally independent of the cash flows of other asset or liability groups. Fair value is determined based on discounted cash flows or appraised values, as appropriate. As a result of the indicators of impairment identified for the South Texas properties asset group, and the uncertainty with respect to the future undiscounted cash flows, we have obtained appraisals, level 3 inputs, to determine the fair value of the asset group, which did not result in impairment.
Assets held for sale - We measure and record assets held for sale at the lower of their carrying amount or fair value less cost to sell. The determination of fair value can require the use of significant judgment and can vary on the facts and circumstances.

We had no assets held for sale at December 31, 2016. Assets held for sale at December 31, 2015 consist of equipment that was subsequently sold during the first quarter of 2016. We estimated the fair value as the actual cash proceeds received less costs incurred to sell. We recorded an impairment of $0.6 million related to this equipment during the fourth quarter of 2015.

During 2015, we recorded an impairment related to a partially constructed topside, related valves, piping and equipment that we acquired from a customer following its default under a contract for a deepwater project in 2012 in the amount of $6.6 million. We reclassified the asset’s net realizable value of $3.7 million from assets held for sale to inventory based on the estimated scrap value of these materials. The impairment was the result of our limited ability to effectively market these assets held for sale due to the sustained downturn in the energy sector and a potential buyer that was no longer expressing interest in the assets.
During the fourth quarter of 2014, management recorded an impairment charge of $3.2 million related to these same assets based upon a fair value $10.3 million for these assets with the assistance of third party valuation specialists, relying primarily on the cost approach and applied the market approach where comparable sales transaction information was readily available. The
GULF ISLAND FABRICATION, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS-(Continued)

cost approach is based on current replacement or reproduction costs of the subject assets less depreciation attributable to physical, functional, and economic factors. The market approach involves gathering data on sales and offerings of similar assets in order to value the subject assets. This approach also includes an assumption for the measurement of the loss in value from physical, functional, and economic factors.
We have determined that our impairments of assets held for sale and inventory are non-recurring fair value measurements that fall within Level 3 of the fair value hierarchy.

7. EARNINGS PER SHARE AND STOCK REPURCHASE PLAN
The following table sets forth the computation of basic and diluted earnings per share (in thousands, except per share data):
 2016 2015 2014
Numerator:     
Net income (loss)$3,515
 $(25,364) $15,320
Less: distributed loss / distributed and undistributed income (unvested restricted stock)30
 84
 104
Net income (loss) attributable to common shareholders$3,485
 $(25,448) $15,216
      
Denominator (basic and fully diluted):     
Denominator for basic earnings per share-weighted-average shares14,631
 14,546
 14,505
Basic and fully diluted earnings (loss) per share—common shareholders$0.24
 $(1.75) $1.05
On July 30, 2015, our Board of Directors authorized the Company to repurchase up to $10.0 million in shares of our common stock under a share repurchase program that remains in effect through July 30, 2017. Repurchases may be effected through open market purchases or in privately negotiated transactions at such times and in such amounts as management deems appropriate, depending on market conditions and other factors. The repurchase program does not obligate the Company to acquire any particular amount of common stock and may be modified, suspended or discontinued at any time. To date, we have made no repurchases of our common stock. Due to the severity of the industry downturn, management has recommended and our Board of Directors has approved a suspension of our stock repurchase program in an effort to conserve cash.

8. LINE OF CREDIT
We have a credit agreement with Whitney Bank and JPMorgan Chase Bank N.A. that provides for an $40.0 million revolving credit facility, which was amended and restated on December 16, 2016. The amended and restated credit facility: (i) is secured by substantially all of our assets (other than real estate); (ii) extends the term of the facility from January 2, 2017 to November 29, 2018; (iii) reduces the borrowing base from $80.0 million to $40.0 million; and (iv) permits the full borrowing base to be used for issuing letters of credit and/or general corporate and working capital purposes. Under the prior facility, only $20.0 million of the $80.0 million borrowing base could be used for general corporate and working capital purposes. Given the historically low levels of borrowings under our prior credit facility and our cash position, we requested a reduction in the amount of available credit under the facility from $80.0 million to $40.0 million during negotiations with the lenders to decrease the commitment fees payable on the undrawn portion of the facility. We must comply with the following financial covenants each quarter beginning with the quarter ending December 31, 2016:

(i)minimum net worth requirement of not less than $255.0 million,
(a)plus 50% of net income earned in each quarter beginning December 31, 2016 and
(b)100% of proceeds from any issuance of common stock,
(c)less the amount of any impairment on assets owned by Gulf Marine Fabricators, L.P. up to $30.0 million;
(ii)debt to EBITDA ratio not greater than 2.5 to 1.0; and
(iii) interest coverage ratio not less than 2.0 to 1.0.

The annual interest rates applicable to amounts outstanding under the amended and restated credit facility continue to remain, at the Company’s option, at either (i) a prime rate established by JPMorgan Chase Bank, N.A., or (ii) a LIBOR rate (defined in the amended and restated credit agreement) plus 2.0% per annum. In addition, the commitment fee on the undrawn portion of the facility and the letter of credit fee on undrawn stated amounts under letters of credit issued by the lenders remain at 0.50% per annum and 2.0% per annum, respectively. At December 31, 2016 we had no outstanding borrowings under the credit agreement,
GULF ISLAND FABRICATION, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS-(Continued)

and we had outstanding letters of credit totaling $7.7 million. After consideration of outstanding letters of credit, the availability of the unused portion of the revolving credit agreement (as amended) for additional letters of credit and for general corporate purposes was $32.3 million. We were in compliance with our covenants at December 31, 2016.

9. INCOME TAXES
Significant components of the Company’s deferred tax assets and liabilities as of December 31 were as follows (in thousands):
 2016 2015
Deferred tax liabilities:   
Property, plant and equipment$27,468
 $31,943
Prepaid insurance766
 1,209
Total deferred tax liabilities:28,234
 33,152
Deferred tax assets:   
Employee benefits1,303
 924
Uncompleted contracts106
 3,321
Stock based compensation expense1,488
 825
Allowance for uncollectible accounts192
 16
Long term incentive awards264
 —
Federal net operating loss617
 5,478
AMT credit carryforwards1,030
 763
Total deferred tax assets:5,000
 11,327
Net deferred tax liabilities:$23,234
 $21,825
Significant components of income tax expense for the years ended December 31 were as follows (in thousands):
 2016 2015 2014
Current:     
Federal$302
 $219
 $(105)
State361
 473
 459
Total current663
 692
 354
Deferred:     
Federal1,549
 (13,614) 8,120
State(171) (447) 30
Total deferred1,378
 (14,061) 8,150
Income taxes$2,041
 $(13,369) $8,504
A reconciliation of income taxes computed at the U.S. federal statutory tax rate to the Company’s income tax (benefit) expense for the years ended December 31 is as follows (in thousands):
 2016 % 2015 % 2014 %
U.S. statutory rate$1,945
 35.0% $(13,556) 35.0% $8,338
 35.0%
Increase (decrease) resulting from:           
State income taxes64
 1.1% 275
 (0.7)% 311
 1.0%
Other32
 0.6% (88) 0.2% (145) (0.3)%
Income tax (benefit) expense$2,041
 36.7% $(13,369) 34.5% $8,504
 35.7%
GULF ISLAND FABRICATION, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS-(Continued)

10. RETIREMENT PLAN

AND LONG-TERM INCENTIVE PLANS

401(k) Plan
The Company has a defined contribution plan for all employees that are qualified under Section 401(k) of the Internal Revenue Code. Gulf Island Resources employees are not eligible for the retirement plan. Contributions to the retirement plan by the Company are based on the participants’ contributions, with an additional year-end discretionary contribution determined by the Board of Directors. Effective April 1, 2016, the Company temporarily suspended its matching contribution in response to the downturn in the oil and gas industry. For the years ended December 31, 20142016, 2015 and 2013,2014, the Company contributed a total of $670,000, $2.3 million, and $2.6 million, and $2.7 million, respectively.

14. EARNINGS PER SHARE

The following table sets forth

Long-Term Incentive Plans
Under our long-term incentive plans, the computationcompensation committee of basic and diluted earnings per share (in thousands, except per share data):

   2014   2013   2012 

Basic:

      

Numerator:

      

Net Income (loss)

  $15,320    $7,232    $(4,091) 

Less: Distributed loss / distributed and undistributed income (unvested restricted stock)

   104     75     46  
  

 

 

   

 

 

   

 

 

 

Net income (loss) attributable to common shareholders

  $15,216    $7,157    $(4,137) 
  

 

 

   

 

 

   

 

 

 

Denominator:

      

Denominator for basic earnings per share-weighted-average shares

   14,505     14,463     14,400  
  

 

 

   

 

 

   

 

 

 

Basic earnings per share—common shareholders

  $1.05    $0.50    $(0.29) 
  

 

 

   

 

 

   

 

 

 

Diluted:

      

Numerator:

      

Net income

  $15,320    $7,232    $(4,091) 

Less: Distributed loss / distributed and undistributed income (unvested restricted stock)

   104     75     46  
  

 

 

   

 

 

   

 

 

 

Net income attributable to common shareholders

  $15,216    $7,157    $(4,137) 
  

 

 

   

 

 

   

 

 

 

Denominator:

      

Denominator for basic earnings per share-weighted-average shares

   14,505     14,463     14,400  

Effect of dilutive securities:

      

Employee stock options

   —       6     —    
  

 

 

   

 

 

   

 

 

 

Denominator for dilutive earnings per share-weighted-average shares

   14,505     14,469     14,400  
  

 

 

   

 

 

   

 

 

 

Diluted earnings per share—common shareholders

  $1.05    $0.50    $(0.29) 
  

 

 

   

 

 

   

 

 

 

GULF ISLAND FABRICATION, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—(Continued)

15. LONG-TERM INCENTIVE PLANS

On February 13, 1997,our Board of Directors may award shares of restricted stock and/or options to eligible participants as the shareholders approved the adoptioncompensation committee determines are warranted. A summary of the our long-term incentive plans is as follows:

Long-Term Incentive Plan (the “Plan”). The Plan (approved by our shareholders on February 13, 1997)
authorizes the grant of options to purchase an aggregate of 1,000,000 (split adjusted) shares of the Company’s common stock to certain officers, and key employees, directors and consultants of the Company chosen by a committee appointed by the board of directors (the “compensation committee”) to administer such Plan. Under the Plan, all options granted have 10-year terms, and the conditions relating to the vesting and exercise of the options result in their being classified as “nonstatutory options” (options which do not afford income tax benefits to recipients, but the exercise of which may provide tax deductions for the Company). Each option will have an exercise price per share not less than the market price of the common stock on the date of grant and nocompensation committee.
No individual employee may be granted options to purchase more than an aggregate of 400,000 shares of common stock.

On April 24, 2002, the shareholders approved the adoption of the


2002 Long-Term Incentive Plan which was amended(approved by theour shareholders on April 24, 2002, and amended on April 26, 2006 (the “2002 Plan”)2006). The 2002 Plan
authorizes the grant of awards, including options, to purchase an aggregate of 500,000 shares of the Company’s common stock to certain officers, key employees, directors and consultants of the Company chosen by the compensation committee. Under the 2002 Plan, all options granted have 10-year terms, and the conditions relating to the vesting and exercise of the options result in their being classified as nonstatutory options. Each option will have an exercise price per share not less than the market price of the common stock on the date of grant and
no individual employee may be granted options to purchase more than an aggregate of 200,000 shares of common stock.

On April 28, 2011, the shareholders approved the adoption of the


2011 Stock Incentive Plan (the “2011 Plan”). The 2011 Plan (approved by our shareholders on April 28, 2011)
authorizes the grant of awards, including options, to purchase an aggregate of 500,000 shares of the Company’s common stock to certain officers, key employees, directors and consultants of the Company chosen by the compensation committee. Under the 2011 Plan, all options granted have 10-year terms, and the conditions relating to the vesting and exercise of the options result in their being classified as nonstatutory options. Each option will have an exercise price per share not less than the market price of the common stock on the date of grant and
no individual employee may be granted options to purchase more than an aggregate of 200,000 shares of common stock.


2015Stock Incentive Plan (approved by our shareholders on April 23,2015)

authorizes the grant of awards, including options, to purchase an aggregate of 1,000,000 shares of the Company’s common stock to certain officers, key employees, directors and consultants of the Company chosen by the compensation committee.
no individual employee may be granted options to purchase more than an aggregate of 200,000 shares of common stock and no outside director may receive awards that relate to more than 25,000 shares in any fiscal year.

At December 31, 2014,2016, there were approximately 542,0001,123,482 shares in the aggregate remaining available for future issuance under the Long-Term Incentive Plan, the 2002 Long-Term Incentive Plan, the 2011 Stock Incentive Plan and the 20112015 Stock Incentive Plan (together, the “Incentive Plans”). The Company issues new shares through its transfer agent upon stock option exercises or restricted share issuances. The compensation committee did not grant any stock options under the Incentive Plans during the years ended December 31, 2014, 2013, or 2012.

GULF ISLAND FABRICATION, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—(Continued)

A summary of the Company’s stock option activity as of December 31, 2014, and changes during the year then ended is presented below:

   Options  Weighted-
Average
Exercise
Price		   Weighted-
Average
Remaining
Contractual
Term		   Aggregate
Intrinsic
Value
($000)		 

Outstanding at December 31, 2011

   91,800   $19.07      

Granted

   —         

Exercised

   (15,065)   18.15      

Forfeited or expired

   (43,835)   18.82      
  

 

 

      

Outstanding at December 31, 2012

   32,900   $19.83     1.5    $138  

Granted

   —      —        

Exercised

   (2,900)   16.69      

Forfeited or expired

   (10,000)   16.69      
  

 

 

      

Outstanding at December 31, 2013

   20,000   $21.85     0.9    $27  

Granted

   —      —       —       —    

Exercised

   —      —       —       —    

Forfeited or expired

   (20,000)  $21.85      
  

 

 

      

Outstanding at December 31, 2014

   —      —       —       —    
  

 

 

  

 

 

   

 

 

   

 

 

 

The total intrinsic value of options exercised during the years ended December 31, 2014, 2013, and 2012, was $0, $26,000, and $250,000, respectively.

Cash received from option exercises for the years ended December 31, 2014, 2013 and 2012 was $0, $48,000, and $17,000, respectively. The excess tax benefit realized for the tax deductions from option exercise of the share-based payment arrangements totaled $0, $116,000 and $259,000, respectively, for the years ended December 31, 2014, 2013 and 2012.

As of December 31, 2014, all compensation costs related to options granted under the Incentive Plans were recognized. All options granted under the Incentive Plans have vested as of December 31, 2009.

Under the Incentive Plans, the compensation committee may award shares


Restricted Stock Awards
Awards of restricted stock to eligible participants as the Committee determines pursuant to the terms of the Incentive Plans. An award of restricted stock shall beare subject to transfer restrictions, forfeit provisions and other terms and conditions subject to the provisions of the Incentive Plans.our long-term incentive plans. At the time an award of restricted stock is made, the compensation committee shallwill establish a period of time during which the transfer of the shares of restricted stock shall be restricted and after which the shares of restricted stock shall be vested. Except for the shares of restricted stock that vest based on the attainment of performance goals, the restricted period shall be a minimum of three years, with incremental vesting of portions of the award over the three-year period permitted.

The Incentive Plans

Our long-term incentive plans do not have any limitations on the amount of shares that can be specifically awarded as restricted stock. Restricted stock granted to our non-employee directors have six-month vesting periods. Awards of restricted stock granted to employees during 2013 vest in annual 20% installments beginning on the first anniversary of the date of the grant. The fair value of restricted stock is determined based on the closing price of the Company’s common stock on the date of the grant. In 2014, the compensation committee granted 6,000 shares with a weighted average grant-date fair value of $23.19. The compensation committee granted 100,150

GULF ISLAND FABRICATION, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—STATEMENTS-(Continued)

shares of restricted stock in 2013 with a weighted-average grant date fair value of $23.22. The compensation committee granted 60,250 shares of restricted stock in 2012 with a weighted-average grant date fair value of $23.53.


A summary of the status of our restricted stock awards activity for the years ended December 31, 2016, 2015 and 2014 is presented in the table below.

   Number
of Shares		  Weighted-
Average
Grant-Date
Fair Value
Per  Share		 

Restricted shares at December 31, 2011

   203,730   $22.99  

Granted

   60,250    23.53  

Vested

   (61,152)   21.29  

Forfeited

   (59,678)   22.20  
  

 

 

  

 

 

 

Restricted shares at December 31, 2012

   143,150   $24.28  

Granted

   100,150    23.22  

Vested

   (38,188)   23.14  

Forfeited

   (26,162)   23.82  
  

 

 

  

 

 

 

Restricted shares at December 31, 2013

   178,950   $24.00  

Granted

   6,000    23.19  

Vested

   (45,356)   23.35  

Forfeited

   (31,754)   23.85  
  

 

 

  

 

 

 

Restricted shares at December 31, 2014

   107,840   $24.27  

 2016 2015 2014
 
Number
of Shares
 
Weighted-
Average
Grant-Date
Fair Value
Per  Share
 
Number
of Shares
 
Weighted-
Average
Grant-Date
Fair Value
Per  Share
 
Number
of Shares
 
Weighted-
Average
Grant-Date
Fair Value
Per  Share
Restricted shares at the beginning of period262,964
 $18.33
 107,840
 $24.27
 178,950
 $24.00
Granted259,699
 8.55
 215,034
 16.33
 6,000
 23.19
Vested(114,804) 14.37
 (41,112) 22.04
 (45,356) 23.35
Forfeited(37,294) 15.48
 (18,798) 21.39
 (31,754) 23.85
Restricted shares at the end of period370,565
 $12.99
 262,964
 $18.33
 107,840
 $24.27
As of December 31, 2014,2016, there was $2.0$2.6 million of total unrecognized compensation cost related to restricted share-based compensation arrangements granted under the Incentive Plans. This cost is expected to be recognized over a weighted-average period of 3.21.7 years. The total fair value of shares vested during the year ended December 31, 20142016 was $1.3$1.2 million.

Share-based compensation cost that has been charged against income for the Incentive Plans was $2.1 million, $2.7 million and $1.1 million $0.7 millionfor 2016, 2015 and $1.2 million for 2014, 2013 and 2012, respectively. The total income tax benefit recognized in the income statement for share-based compensation arrangements was $0, $0 and $49,000 $116,000for 2016, 2015 and $297,0002014, respectively.
Performance share awards

We issue performance share awards to our executives and certain members of management. Performance targets are communicated to employees at the beginning of a performance period and are based upon our total shareholder return compared to an industry peer group as determined by our Board of Directors. There were no performance based share awards for the year ended December 31, 2014. Awards granted during 2015 are based upon a two-year performance period ending December 31, 2016 and payable in shares. The shares vest at the completion of the performance period with compensation expense recognized on a straight line basis. Awards granted during 2016 are based upon a three-year performance period ending in December 31, 2018 and are payable in cash. The fair value of the 2016 awards is calculated each reporting period and compensation expense (including fair value adjustments) are recognized on a straight line basis.

For the years ended December 31, 2016, 2015 and 2014, 2013expense recognized for performance based share compensation was $1.3 million, $1.1 million and 2012,$0, respectively.

The fair value of the performance based shares granted for the years ended December 31, 2016 and 2015 was $1.6 million and $2.7 million, respectively, as determined using a Monte Carlo simulation model.


11. CONTINGENCIES AND COMMITMENTS
The Company is subject to various routine legal proceedings in the normal conduct of its business, primarily involving commercial claims, workers’ compensation claims, and claims for personal injury under general maritime laws of the United States and the Jones Act. While the outcome of these lawsuits, legal proceedings and claims cannot be predicted with certainty, management believes that the outcome of any such proceedings, even if determined adversely, would not have a material adverse effect on the financial position, results of operations or cash flows of the Company.

12. OPERATING SEGMENTS

In connection with the LEEVAC Transaction (See Note 2), management restructured the operation of our business units into three divisions which we believe meet the criteria of reportable segments under GAAP. These divisions consist of Fabrication, Shipyards and Services.

16.Fabrication Division -Our Fabrication division primarily fabricates structures such as offshore drilling and production platforms and other steel structures for customers in the oil and gas industries including jackets and deck sections of fixed production platforms, hull, tendon, and/or deck sections of floating production platforms (such as TLPs, SPARs, FPSOs and MinDOCs), piles, wellhead protectors, subsea templates, and various production, compressor, and utility modules along with pressure vessels.
GULF ISLAND FABRICATION, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS-(Continued)

Our Fabrication division also fabricates structures for alternative energy customers (such as the five jackets and piles we constructed for the first offshore wind power project in the United States during 2015) as well as modules for petrochemical facilities. We perform these activities out of our fabrication yards in Houma, Louisiana, and Aransas Pass and Ingleside, Texas.

Shipyards Division - Our Shipyards division primarily manufactures newbuild and repairs various steel marine vessels in the United States including offshore supply vessels, anchor handling vessels and liftboats to support the construction and ongoing operation of offshore oil and gas production platforms, tug boats, towboats, barges and other marine vessels. We also construct dry docks to lift marine vessels out of the water. Our marine repair activities include steel repair, blasting and painting services, electrical systems repair, machinery and piping system repairs, and propeller, shaft, and rudder reconditioning. In addition, we perform conversion projects that consist of lengthening vessels, modifying vessels to permit their use for a different type of activity, and other modifications to enhance the capacity or functionality of a vessel. Our Houma dry dock has a current lift capacity of 9,000 tons and is used to maintain and repair third party marine vessels, as well as to launch vessels fabricated at our facilities. We are in process of enhancing our Houma dry dock to increase this capacity to 15,000 tons. We perform these activities out of our shipyards in Houma, Jennings and Lake Charles, Louisiana.

Services Division- Our Services division primarily provides interconnect piping services on offshore platforms and inshore structures. Interconnect piping services involve sending employee crews to offshore platforms in the Gulf of Mexico to perform welding and other activities required to connect production equipment, service modules and other equipment on a platform. We also contract with oil and gas companies that have platforms and other structures located in the inland lakes and bays throughout the southeastern United States for various on-site construction and maintenance activities. In addition, our Services division fabricates packaged skid units and perform various municipal and drainage projects, such as pump stations, levee reinforcement, bulkheads and other public works projects for state and local governments. We perform these services at our customer's facilities or out of our Houma Service Yard.

We generally evaluate the performance of, and allocate resources to, our divisions based upon gross profit (loss) and operating income (loss). Segment assets are comprised of all assets attributable to each division. Corporate administrative costs and overhead are generally allocated to our segments except for those costs that are not directly related to the operations of our divisions. Intersegment revenues are priced at the estimated fair value of work performed. Summarized financial information concerning our segments as of and for the three-year period ended December 31, 2016 is as follows (in thousands):
 December 31, 2016
 Fabrication
Shipyards (1), (2)
ServicesCorp. & EliminationsConsolidated
Revenue$88,683
$109,502
$91,414
$(3,273)$286,326
Gross profit5,061
7,587
12,205
—
24,853
Operating income (loss)(1,039)(163)6,568
(183)5,183
      
Depreciation expense18,566
4,686
1,775
421
25,448
Capital expenditures2,633
1,861
1,495
806
6,795
Total Assets$272,292
$81,928
$96,404
$(128,216)$322,408
      
 December 31, 2015
 FabricationShipyardsServicesCorp. & EliminationsConsolidated
Revenue$151,576
$59,601
$100,431
$(5,488)$306,120
Gross profit (loss)(37,541)8,665
13,726
(6)(15,156)
Operating income (loss)(54,036)6,973
9,548
(1,099)(38,614)
      
Depreciation expense22,045
1,921
1,733
505
26,204
Capital expenditures3,360
1,206
1,379
73
6,018
Total Assets$310,790
$54,543
$94,618
$(143,028)$316,923
      
GULF ISLAND FABRICATION, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS-(Continued)

 December 31, 2014
 FabricationShipyardsServicesCorp. & EliminationsConsolidated
Revenue$303,880
$79,197
$132,107
$(8,545)$506,639
Gross profit (loss)19,418
4,922
20,258
(42)44,556
Operating income (loss)4,079
3,262
17,502
(896)23,947
      
Depreciation expense22,524
1,805
1,612
495
26,436
Capital expenditures23,245
2,135
2,083
195
27,658
Total Assets$396,806
$63,090
$95,385
$(157,338)$397,943
      
____________
(1)Included in our results of operations for our Shipyards division was revenue and net (loss) income of $75.6 million and ($1.8 million), for the year ended December 31, 2016, respectively, attributable to the assets and operations acquired in the LEEVAC transaction. No amounts were included in the comparable 2015 or 2014 periods as the LEEVAC transaction was effective January 1, 2016. See also Note 2.
(2)Revenue for the year ended December 31, 2016 includes $5.2 million of non-cash amortization of deferred revenue, related to the values assigned to contracts acquired in the LEEVAC transaction.
13. QUARTERLY OPERATING RESULTS (UNAUDITED)

A summary of quarterly results of operations for the years ended December 31, 20142016 and 20132015 were as follows (in thousands, except per share data):

   March 31,
2014		   June 30,
2014 (a)		   September 30,
2014 (a)		   December 31,
2014 (a)(b)		 

Revenue

  $134,690    $129,169    $118,020    $124,760  

Gross profit

   8,773     10,322     14,653     10,808  

Net Income (loss)

   3,535     4,310     7,586     (111) 

Basic EPS

   0.24     0.30     0.52     (0.01) 

Diluted EPS

   0.24     0.30     0.52     (0.01) 

 
March 31,
2016
 
June 30,
2016
 
September 30,
2016
 
December 31,
2016
Revenue$83,979
 $81,502
 $65,384
 $55,461
Gross profit (loss)5,701
 14,066
 5,259
 (172)
Net income (loss)989
 5,540
 541
 (3,555)
Basic and fully diluted EPS$0.07
 $0.37
 $0.04
 $(0.24)
 
March 31,
2015
 
June 30,
2015
 
September 30,
2015 (1)
 
December 31,
2015 (1)
Revenue$99,233
 $84,338
 $67,531
 $55,018
Gross profit (loss)4,448
 5,805
 (7,837) (17,572)
Net income (loss)83
 1,357
 (12,137) (14,667)
Basic and fully diluted EPS$—
 $0.09
 $(0.84) $(1.01)
(1)During the third quarter of 2015, we recorded contract losses of $14.3 million as a result of our inability to recover certain costs related to a deck and jacket for one of our large deepwater projects, and we recorded an impairment of $6.6 million related to assets held for sale. During the fourth quarter of 2015, we recorded additional contract losses of $10.3 million related to a decrease in the contract price due to final weight re-measurements and our inability to recover certain costs on disputed change orders related to a large deepwater project which was delivered in 2015. In addition, during the fourth quarter of 2015, we accrued contract losses of approximately $7.6 million resulting from increases in our projected unit labor rates of our fabrication facilities. Our increases in unit labor rates were driven by our inability to absorb fixed costs due to decreases in expected oil and gas fabrication activity.
GULF ISLAND FABRICATION, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—STATEMENTS-(Continued)

   March 31,
2013		   June 30,
2013 (a)		   September 30,
2013 (a)		   December 31,
2013 (a)		 

Revenue

  $150,422    $154,575    $168,191    $135,138  

Gross profit (loss)

   6,704     9,677     9,055     (1,775) 

Net income (loss)

   2,787     4,279     3,276     (3,110) 

Basic EPS

   0.19     0.30     0.23     (0.22) 

Diluted EPS

   0.19     0.30     0.23     (0.22) 

(a)We recognized contract losses of $1.6 million for the three-month period ended December 31, 2014, $0.3 million for the three-month period ended September 30, 2014, and $4.7 million for the three-month period ended June 30, 2014. We recognized contract losses of $18.2 million in the three-month period ended December 31, 2013, $10.9 million in the three-month period ended September 30, 2013, and $0.6 million in the three-month period ended June 30, 2013, as required under the accounting for loss contracts under percentage of completion accounting. Contract losses for the year ended December 31, 2014 were primarily related to tank barge projects for a marine transportation company, platform supply vessels for an offshore marine company and a production platform jacket for a deepwater customer. Contract losses in 2013 were primarily due to the impact of the de-scoping and final close-out of one of our major deepwater projects, as further discussed in the Note 1 under “Revenue Recognition” above.
(b)We recognized an impairment charge of $3.2 million related to a reduction in the fair value of assets held for sale and a $3.6 million charge related to an increase in the allowance for doubtful accounts for negotiations of an outstanding contract receivable balance for the three-month period ended December 31, 2014.

17.


14. SUBSEQUENT EVENTS

Dividends
On February 26, 2015,23, 2017, our Board of Directors declared a dividend of $0.10$0.01 per share on the shares of our common stock outstanding, payable March 27, 201524, 2017 to shareholders of record on March 13, 2015.

10, 2017.

Our South Texas Properties
On February 23, 2017, our Board of Directors approved a recommendation of management to place our South Texas properties located in Aransas Pass and Ingleside, Texas, up for sale. Our Texas South Yard in Ingleside, Texas, is located on the northwest corner of the U.S. Intracoastal Waterway and the Corpus Christi Ship Channel. The 45-foot deep Corpus Christi Ship Channel provides direct and unrestricted access to the Gulf of Mexico. Our Texas North Yard in Aransas Pass, Texas, is located along the U.S. Intracoastal Waterway and is approximately three miles north of the Corpus Christi Ship Channel. These properties are currently underutilized and represent excess capacity within our Fabrication division. The net book value of property, plant and equipment for these assets was $107.6 million at December 31, 2016. We are working to wind down all fabrication activities at these locations and re-allocate remaining backlog and workforce to our Houma Fabrication Yard as necessary. As a result of the decision to place our South Texas properties for sale and the underutilization currently being experienced, we expect to incur costs associated with the maintaining of the facility through its sale that will not be recoverable. These costs include insurance, general maintenance of the property in its current state, property taxes, and retained employees.

We do not expect the sale of these properties to impact our ability to service our deepwater customers or operate our Fabrication division.

Customer Matter
On October 21, 2016, a customer of our Shipyards division announced it had received limited waivers from its lenders and noteholders through November 11, 2016, which was extended through March 3, 2017 with respect to noncompliance with certain financial covenants included in the customer’s debt agreements. The customer also announced its debt agreements will require further negotiation and amendment. In the event our customer is unsuccessful in these efforts, the customer has publicly stated that it will consider other options including a possible reorganization under Chapter 11 of the Federal bankruptcy laws. At December 31, 2016, we had two vessels under construction for this customer with no contracts receivable outstanding and deferred revenue exceeded our contracts in progress.

We completed and tendered to this customer for delivery the first vessel on February 6, 2017. Upon our tender of delivery, our customer alleged certain technical deficiencies associated with the vessel. We disagree with our customer concerning these alleged technical deficiencies and have put the customer in default under the terms of the contract. As of February 6, 2017, approximately $4.5 million remained due and outstanding from our customer under this contract. We continue to hold discussions with our customer in an effort to resolve this matter and intend to take all legal action as may be necessary to protect our rights under the contract and recover the remaining balance owed to us. The second offshore supply vessel for this customer is scheduled for delivery in May 2017. As of the date of this Report, the balance due to us for this second vessel is approximately $4.9 million and both we and our customer remain in compliance with the terms of this contract.

We continue to monitor our work performed in relation to our customer’s status and its ability to pay under the terms of these contracts. Because these vessels have been completed or are substantially complete, we believe that they have significant fair value, and that we would be able to fully recover any amounts due to us. Based on our evaluation to date, we do not believe that any loss on this contract is probable or estimatable at this time.



SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized, on March 5, 2015.

2, 2017.

GULF ISLAND FABRICATION, INC.
(Registrant)

By:

/S/ KIRK J. MECHE
 

        /S/ KIRK J. MECHE

Kirk J. Meche
 President and Chief Executive Officer

Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities indicated on March 5, 2015.

2, 2017.

Signature

 

Title

SignatureTitle

/S/ KIRK J. MECHE

Kirk J. Meche

 

President, Chief Executive Officer and Director

(Principal Executive Officer)

Kirk J. Meche

/S/ JEFFREY M. FAVRET

Jeffrey M. Favret

DAVID S. SCHORLEMER		 Executive Vice President, Chief Financial Officer, Treasurer, and Secretary (PrincipalTreasurer(Principal Financial and Accounting Officer)
David S. Schorlemer

/S/ MURRAY W. BURNS

Murray W. Burns

  Director
Murray W. Burns

/S/ WILLIAM E. CHILES

William E. Chiles

  Director
William E. Chiles

/S/ GREGORY J. COTTER

Gregory J. Cotter

  Director
Gregory J. Cotter

/S/ JERRY D. DUMAS, Sr.

Jerry D. Dumas, Sr.

SR.		  Director
Jerry D. Dumas, Sr.

/S/ MICHAEL A. FLICK

Michael A. Flick

  Director
Michael A. Flick

/S/ CHRISTOPHER M. HARDING

Christopher M. Harding

  Director
Christopher M. Harding

/S/ MICHAEL J. KEEFFE

Michael J. Keeffe

  Director
Michael J. Keeffe

/S/ JOHN P. LABORDE

John P. Laborde

  Chairman of the Board
John P. Laborde




GULF ISLAND FABRICATION, INC.

EXHIBIT INDEX

EXHIBIT

NUMBER

   
2.1Asset Purchase Agreement, dated December 23, 2015, among the Company, LEEVAC and certain other parties thereto, incorporated by reference to Exhibit 2.1 of the Company’s Form 8-K filed December 23, 2015.
 
3.1  Composite Articles of Incorporation of the Company incorporated by reference to Exhibit 3.1 of the Company’s Form 10-Q filed April 23, 2009.
3.2  Amended and Restated Bylaws of the Company, as Amended and Restated through April 26, 2012, incorporated by reference to Exhibit 3.1 of the Company’s Form 8-K filed April 30, 2012.
November 4, 2016.
 
4.1  Specimen Common Stock Certificate, incorporated by reference to the Company’s Form S-1/A filed March 19, 1997 (Registration No. 333-21863). *
10.1  Form of Indemnity Agreement by and between the Company and each of its directors and executive officers. *officers, incorporated by reference to Exhibit 10.1 of the Company's Form 8-K filed November 4, 2016. †
10.2Registration Rights Agreement between the Company and Alden J. Laborde. *
10.3  The Company’s Long-Term Incentive Plan. * †
10.410.3  The Company’s 2002 Long-Term Incentive Plan, as amended and restated, incorporated by reference to Exhibit 10.2 to the Company’s Quarterly Report on Form 10-Q for the period ended June 30, 2006 . † ^
10.510.4  The Company’s 2011 Stock Incentive Plan, incorporated by reference to Exhibit 99 to the Company’s Form S-8 filed August 9, 2011 (Registration No. 333-176187).
10.5The Company’s 2015 Stock Incentive Plan, incorporated by reference to Exhibit 10.1 of the Company’s Form 8-K filed April 28, 2015.
10.6  The Company’s Annual Incentive Program,
Form of Performance Share Unit Agreement. (1)
10.7Form of Restricted Stock Unit Agreement, incorporated by reference to Exhibit 10.2 toof the Company’s Quarterly Report on Form 8-K filed July 29, 2014.10-Q for the period ended March 31, 2015.
10.710.8  The Company’s Annual Incentive Program,Form of Long-Term Performance-Based Cash Award Agreement, incorporated by reference to Exhibit 10.210.1 to the Company’sCompany's Quarterly Report on Form 8-K filed July 29, 2014.10-Q for the quarter ended September 30, 2016. †
10.810.9  The Company’s Amended and Restated Annual Incentive Program, incorporated by reference to Exhibit 10.4 to the Company’s Form 8-K filed March 4, 2015.
10.9 Form of Restricted Stock Agreement, incorporated by reference to Exhibit 10.8 to the Company’s Annual Report or Form 10-K for the year ended December 31, 2005. † ^
10.10  Form of Restricted Stock Agreement, incorporated by reference to Exhibit 10.8 to the Company’s Annual Report or Form 10-K for the year ended December 31, 2005. † ^
10.11  Ninth Amended and Restated CreditForm of Indemnification Agreement among the Company, Bank One, N.A. and Whitney National Bank, dated as of December 31, 2003, incorporated by reference to Exhibit 10.9 to the Company’s Annual Report on Form 10-K for the year ended December 31, 2003. ^
10.12First Amendment to Ninth Amended and Restated Credit Agreement among the Company and Bank One, N.A. and Whitney National Bank dated as of June 30, 2004November 4, 2016, incorporated by reference to Exhibit 10.1 to the Company’s Quarterly ReportCompany's Form 8-K filed on Form 10-Q for the period ended June 30, 2004. ^November 4, 2016.
10.13 Second Amendment to Ninth
10.12Tenth Amended and Restated Credit Agreement, among the Company and JP Morgan Chase Bank, N.A. and Whitney National Bank dated as of December 21, 2004, incorporated by reference to Exhibit 10.12 to the Company’s Annual Report on Form 10-K for the year ended December 31, 2004. ^
10.14Third Amendment to Ninth Amended and Restated Credit Agreement among the Company and JP Morgan Chase Bank, N.A. and Whitney National Bank dated June 30, 2005, incorporated by reference to Exhibit 10.1 to the Company’s Quarterly ReportCompany's Form 8-K filed on Form 10-Q for the period ended June 30, 2005. ^

December 16, 2016.

EXHIBIT

NUMBER

  
10.15Fourth Amendment to Ninth Amended and Restated Credit Agreement among the Company and JP Morgan Chase Bank, N.A. and Whitney National Bank dated January 30, 2006, incorporated by reference to Exhibit 10.1 to the Company’s Form 8-K filed February 3, 2006. ^
10.16Fifth Amendment to the Ninth Amended and Restated Credit Agreement among the Company, JP Morgan Chase Bank N.A. and Whitney National Bank dated March 31, 2006, incorporated by reference to Exhibit 10.1 to the Company’s Quarterly Report on Form 10-Q for the period ended June 30, 2006. ^
10.17Sixth Amendment to the Ninth Amended and Restated Credit Agreement among the Company and JP Morgan Chase Bank, N.A. and Whitney National Bank dated as of February 19, 2007, incorporated by reference to Exhibit 10.19 to the Company’s Annual Report on Form 10-K for the year ended December 31, 2006. ^
10.18Seventh Amendment to the Ninth Amended and Restated Credit Agreement among the Company and JP Morgan Chase Bank, N.A. and Whitney National Bank dated as of August 6, 2008, incorporated by reference to Exhibit 10.1 to the Company’s Form 8-K filed August 11, 2008.
10.19Eighth Amendment to the Ninth Amended and Restated Credit Agreement among the Company and JPMorgan Chase Bank, N.A. and Whitney National Bank dated as of June 2, 2009, incorporated by reference to Exhibit 10.1 of the Company’s Form 8-K filed June 3, 2009.
10.20Ninth Amendment to the Ninth Amended and Restated Credit Agreement dated July 15, 2010, incorporated by reference to Exhibit 10.1 of the Company’s Form 8-K filed July 16, 2010.
10.21Tenth Amendment to the Ninth Amended and Restated Credit Agreement dated May 31, 2011, incorporated by reference to Exhibit 10.1 of the Company’s Form 8-K filed June 3, 2011.
10.22Eleventh Amendment to the Ninth Amended and Restated Credit Agreement dated October 29, 2012, incorporated by reference to Exhibit 10.1 of the Company’s Form 10-Q filed October 30, 2012.
10.23Twelfth Amendment to the Ninth Amended and Restated Credit Agreement dated September 12, 2013, incorporated by reference to Exhibit 10.1 of the Company’s Form 8-K filed September 13, 2013.
10.24Thirteenth Amendment to the Ninth Amended and Restated Credit Agreement dated September 12, 2013, incorporated by reference to Exhibit 10.1 of the Company’s Form 10-Q filed October 29, 2014.
10.25Retirement and Consulting Agreement, dated December 28, 2012, between the Company and Kerry J. Chauvin, incorporated by reference to Exhibit 10.1 of the Company’s Form 8-K filed January 2, 2013.
10.26Change of Control Agreement, dated January 1, 2014, between the Company and Jeffrey M. Favret, incorporated by reference to Exhibit 10.1 of the Company’s Form 8-K filed January 3, 2014.
10.27Change of Control Agreement, dated January 1, 2014, between the Company and Todd F. Ladd, incorporated by reference to Exhibit 10.2 of the Company’s Form 8-K filed January 3, 2014.
10.28Change of Control Agreement, dated January 1, 2014, between the Company and Kirk J. Meche, incorporated by reference to Exhibit 10.3 of the Company’s Form 8-K filed January 3, 2014.
10.2910.13 Change of Control Agreement, dated February 26, 2015, between the Company and Kirk J. Meche, incorporated by reference to Exhibit 10.1 of the Company’s Form 8-K filed March 4, 2015.

EXHIBIT

NUMBER

  
10.30Change of Control Agreement, dated February 26, 2015, between the Company and Jeffrey M. Favret, incorporated by reference to Exhibit 10.2 of the Company’s Form 8-K filed March 4, 2015.
10.3110.14 Change of Control Agreement, dated February 26, 2015, between the Company and Todd F. Ladd, incorporated by reference to Exhibit 10.3 of the Company’s Form 8-K filed March 4, 2015.
10.15Change of Control Agreement, dated March 1, 2017, between the Company and David S. Schorlemer.



EXHIBIT
NUMBER
21.1  Subsidiaries of the Company –- The Company’s significant subsidiaries, Gulf Island, L.L.C., Gulf Island Marine Fabricators, L.L.C., Gulf Island Shipyards, L.L.C., Dolphin Steel Sales, L.L.C., Gulf Island Resources, L.L.C. and Dolphin Services, L.L.C. (organized under Louisiana law) and Gulf Marine Fabricators, L.P. (a Texas limited partnership) are wholly owned and are included in the Company’s consolidated financial statements.
23.1  Consent of Ernst & Young LLP.
31.1  CEO Certifications pursuant to Rule 13a-14 under the Securities Exchange Act of 1934.
31.2  CFO Certifications pursuant to Rule 13a-14 under the Securities Exchange Act of 1934.
32  Section 906 Certifications furnished pursuant to 18 U.S.C. Section 1350.
101  Attached as Exhibit 101 to this report are the following items formatted in XBRL (Extensible Business Reporting Language):
  

(i)     Consolidated Balance Sheets,

(ii)    Consolidated Statements of Operations,

(iii)   Consolidated Statement of Changes in Shareholders’ Equity,

(iv)   Consolidated Statements of Cash Flows and

(v)    Notes to Consolidated Financial Statements.

(1)Filing intended to replace that certain Form of Performance Share Unit Agreement filed as Exhibit 10.1 to the Company's Quarterly Report on Form 10-Q for the period ended March 31, 2015. The original Form of Agreement filed with our Form 10-Q for the period ended March 31, 2015 was inadvertently filed in error by the Company.
†Management Contract or Compensatory Plan.
*Incorporated by reference to the Company’s Registration Statement on Form S-1 filed with the Commission on February 14, 1997 (Registration Number 333-21863).
^SEC File Number 000-22303.

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