Certain statements in this annual report on Form 10-K, including, without limitation, statements regarding the following matters, are forward-looking statements made pursuant to the safe harbor provisions of the Private Securities Litigation Reform Act of 1995:

These forward-looking statements are subject to various risks, uncertainties and assumptions, including those we refer to under the headings " Cautionary Statement Concerning Forward-Looking Statements " and " Risk Factors " in Part I of this report. Although we believe that the expectations reflected in such forward-looking statements are reasonable, because of the inherent limitations in the forecasting process, as well as the relatively volatile nature of the industries in which we operate, we can give no assurance that those expectations will prove to have been correct. Accordingly, evaluation of our future prospects must be made with caution when relying on forward-looking information.

Overview

The table that follows sets out our revenue and operating results for 2018 , 2017 and 2016 .

Our business depends substantially on the level of spending on offshore developments by our customers in the energy industry. During 2018 , we generated approximately 78% of our revenue, from services and products we provide to the energy industry. The full year of 2018 unfolded as we expected, with increased levels of energy services and products activity being more than offset by

lower pricing for our energy services and products. Overall, our 2018 revenue approximated our 2017 revenue, with increases in our ROV, Subsea Projects, Asset Integrity and Advance Technologies segments, offset by a substantial decrease in our Subsea Products segment.

In 2018 , on a consolidated level, we had a net loss of $212 million , or diluted loss of $2.16 per share, compared to net income of $166 million , or diluted earnings of $1.68 per share, in 2017 . The $378 million decrease from 2017 net income was primarily attributable to income taxes. In 2018, we had income tax expense of $26 million, due primarily to discrete tax expense adjustments, and in 2017, we had an income tax benefit of $184 million, due primarily to a $189 million tax benefit resulting from the December 2017 enactment of U.S. tax reform legislation commonly referred to as the 2017 Tax Cuts and Jobs Act (the "Tax Act"). Year-over-year, our change in tax expense (benefit) represented $210 million of the previously mentioned decrease in net income.

Additionally, we had an operating loss of $145 million in 2018 compared to operating income of $11 million in 2017. For 2018, our revenue was essentially flat with 2017 as we experienced increased levels of offshore energy activities, however, competitive pressures resulted in lower pricing for our services and products in our energy related segments. Due to lower profit contributions from our energy services and products businesses, operating results decreased $156 million from 2017. The declines in profitability were most notably in:

In 2018 , we invested in the following capital initiatives:

We expect our 2019 operating results to improve year-over-year based on increased activity across all of our segments. Apart from seasonality, we view pricing and margins in the current market to be relatively stable. Operationally, we anticipate all of our segments, with the exception of Asset Integrity, to generate improved yearly results, with the largest increase in profitability occurring in Subsea Products and Advanced Technologies, beginning in the second quarter. Our 2019 forecast is based on the expectation of higher overall activity and stabilized pricing within our energy segments, modest activity improvement within our government businesses and improved performance in our commercial businesses.

We use our ROVs to provide drilling support, vessel-based inspection, maintenance and repair, subsea hardware installation, construction, and pipeline inspection services to customers in the energy industry. Most of our ROVs have historically been used to provide drill support services. Therefore, the number of floating drilling rigs on hire is a leading market indicator for this business. The following table shows average floating rigs under contract and our ROV utilization.

Demand for floating rigs is the primary leading indicator of the strength of the deepwater market. According to industry data published by IHS Petrodata, excluding rigs under construction, at the end of 2018 there were 244 floating drilling rigs in operation or available for work throughout the world, with 146 of those rigs under contract. Of the 146 rigs under contract, 37 have contract terms expiring during the first six months of 2019 . The offshore rig count in 2018 was relatively stable, at approximately 148 rigs.

In addition to floating rig demand, the number of subsea tree completions is another leading indicator, and the primary demand driver for our Subsea Products lines. According to industry data published by Wood MacKenzie in December 2018, there will be 254 subsea tree installations in 2019 , compared to 275 in 2018 , 274 in 2017 and 280 in 2016 . As many as 25 projects in water depths greater than 400 meters are expected to reach "final investment decision" in 2019, up from less then 10 in 2018.

Below the operating income line, we expect:

In 2019 , our income tax payments, estimated to total $25 million, are expected to relate to taxes incurred in countries that impose tax on the basis of in-country revenue, without regard to the profitability of such operations. At this time, we do not foresee realizing a current-year tax benefit from our projected consolidated pre-tax loss, so any discussion of an estimated effective tax rate would not be meaningful.

Critical Accounting Policies and Estimates

We have based the following discussion and analysis of our financial condition and results of operations on our consolidated financial statements, which we have prepared in conformity with accounting principles generally accepted in the United States. These principles require us to make various estimates, judgments and assumptions that affect the reported amounts of assets and liabilities at the date of the financial statements and the reported amounts of revenue and expense during the periods we present. We base our estimates on historical experience, available information and other assumptions we believe to be reasonable under the circumstances. On an ongoing basis, we evaluate our estimates; however, our actual results may differ from these estimates under different assumptions or conditions. The following discussion summarizes the accounting policies we believe (1) require our management's most difficult, subjective or complex judgments and (2) are the most critical to our reporting of results of operations and financial position.

Revenue Recognition. Effective January 1, 2018, we adopted Accounting Standard Update ("ASU") 2014-09, "Revenue from Contracts with Customers," which implemented Accounting Standards Codification Topic 606 ("ASC 606"). We have used the modified retrospective method applied to those contracts that were not completed as of January 1, 2018, and have utilized the practical expedient to reflect the effect on contract modifications in the aggregate. The cumulative effect of applying ASC 606 has been recognized as an adjustment to retained earnings as of January 1, 2018. The comparative information with respect to prior periods has not been retrospectively restated and continues to be reported under the accounting standards in effect for those periods.

All of our revenue is realized through contracts with customers. We recognize our revenue according to the contract type. On a daily basis, we recognize service revenue over time for contracts that provide for specific time, material and equipment charges, which we bill periodically, ranging from weekly to monthly. We use the input method to faithfully depict revenue recognition, because each day of service provided represents value to the customer. The performance obligations in these contracts are satisfied, and revenue is recognized, as the work is performed. We have used the

expedient available to recognize revenue when the billing corresponds to the value realized by the customer where appropriate.

We account for significant fixed-price contracts, mainly relating to our Subsea Products segment, and to a lesser extent in our Subsea Projects and Advanced Technologies segments, by recognizing revenue over time using an input, cost-to-cost measurement percentage-of-completion method. We use the input cost-to-cost method to faithfully depict revenue recognition. This commonly used method allows appropriate calculation of progress on our contracts. A performance obligation is satisfied as we create a product on behalf of the customer over the life of the contract. The remainder of our revenue is recognized at the point in time when control transfers to the customer, thus satisfying the performance obligation.

We have elected to recognize the cost for freight and shipping as an expense when incurred. Taxes assessed by a governmental authority that are both imposed on and concurrent with a specific revenue-producing transaction, and that are collected by us from customers, are excluded from revenue.

In our service-based business lines, which principally charge on a day rate basis for services provided, there is no significant impact in the pattern of revenue and profit recognition as a result of implementation of ASC 606. In our product-based business lines, there are impacts on the pattern of our revenue and profit recognition in our contracts using the percentage-of-completion method, as a result of the requirement to exclude uninstalled materials and significant inefficiencies from the measure of progress. This occurs in our Subsea Products segment.

We apply judgment in the determination and allocation of transaction price to performance obligations, and the subsequent recognition of revenue, based on the facts and circumstances of each contract. We routinely review estimates related to our contracts and, where required, reflect revisions to profitability in earnings immediately. If an element of variable consideration has the potential for a significant future reversal of revenue, we will constrain that variable consideration to a level intended to remove the potential future reversal. If a current estimate of total contract cost indicates an ultimate loss on a contract, we recognize the projected loss in full when we determine it. In prior years, we have recorded adjustments to earnings as a result of revisions to contract estimates. We strive to estimate our contract costs and profitability accurately. However, there could be significant adjustments to overall contract costs in the future, due to changes in facts and circumstances.

In general, our payment terms consist of those services billed regularly as provided and those products delivered at a point in time, which are invoiced after the performance obligation is satisfied. Our product and service contracts with milestone payments due at agreed progress points during the contract are invoiced when those milestones are reached, which may differ from the timing of revenue recognition. Our payment terms generally do not provide financing of contracts to customers, nor do we receive financing from customers as a result of these terms.

Property and Equipment and Long-lived Intangible Assets. We periodically and upon the occurrence of a triggering event review the realizability of our property and equipment and long-lived intangible assets to determine whether any events or changes in circumstances indicate that the carrying amount of the asset may not be recoverable. For long-lived assets to be held and used, we base our evaluation on impairment indicators such as the nature of the assets, the future economic benefits of the assets, any historical or future profitability measurements and other external market conditions or factors that may be present. If such impairment indicators are present or other factors exist that indicate that the carrying amount of an asset may not be recoverable, we determine whether an impairment has occurred through the use of an undiscounted cash flows analysis of the asset at the lowest level for which identifiable cash flows exist. If an impairment has occurred, we recognize a loss for the difference between the carrying amount and the fair value of the asset. For assets held for sale or disposal, the fair value of the asset is measured using fair market value less cost to sell. Assets are classified as held-for-sale when we have a plan for disposal of certain assets and those assets meet the held for sale criteria.

We charge the costs of repair and maintenance of property and equipment to operations as incurred, while we capitalize the costs of improvements that extend asset lives or functionality.

Goodwill. Our goodwill is evaluated for impairment annually and whenever we identify certain triggering events or circumstances that would more likely than not reduce the fair value of a reporting unit below its carrying amount. Events or circumstances that might indicate an interim evaluation is warranted include, among other things, unexpected adverse business conditions, macro and reporting unit specific economic factors (for example, interest rate and foreign exchange rate fluctuations, and loss of key personnel), supply costs, unanticipated competitive activities and acts by governments and courts.

In our evaluation of goodwill, we perform a qualitative or quantitative impairment test. Under the qualitative approach, if we determine that it is more likely than not that the fair value of a reporting unit is less than its carrying amount, we are required to perform the quantitative analysis to determine the fair value for the reporting unit. Thereafter, we compare the fair value of the reporting unit with its carrying amount and recognize an impairment loss for the amount by which the carrying amount exceeds the fair value of the reporting unit. The loss recognized should not exceed the total amount of goodwill allocated to the reporting unit. We also consider income tax effects from any tax deductible goodwill on the carrying amount of the reporting unit when measuring the goodwill impairment loss, if applicable.

The fair value of all our reporting units in our 2017 quantitative analysis exceeded their respective carrying amounts by a significant margin with the exception of one reporting unit, Subsea Projects, the fair value of which only exceeded its carrying value by approximately 20%. Our Subsea Projects reporting unit had the largest balance of goodwill and newer goodwill that would be subject to impairment if business conditions deteriorated subsequent to the acquisitions generating the goodwill.

In our 2018 annual goodwill evaluation, we performed a qualitative assessment for our Subsea Projects reporting unit. Due to the protracted downturn in survey and vessel activity, we determined that it was more likely than not that the fair value was less than the carrying value. As a result, we determined that a quantitative assessment was necessary for our Subsea Projects reporting unit.

In our 2018 quantitative analysis for the Subsea Projects reporting unit, we estimated the fair value by weighing the results from the income approach and the market approach. These valuation approaches consider a number of factors that include, but are not limited to, prospective financial information, growth rates, terminal value, discount rates and comparable multiples of similar companies in our industry and require us to make certain assumptions and estimates regarding industry economic factors and future profitability of our business. Based on this quantitative test, we determined that the fair value for Subsea Projects was less than its carrying value and, as a result, we recorded a pre-tax goodwill impairment loss of $76 million in the Subsea Project reporting unit. The goodwill impairment was included as a component of "Income (Loss) From Operations" in our Consolidated Statement of Operations for the year ended December 31, 2018 . For the remaining reporting units, qualitative assessments were performed and we concluded that it was more likely than not that the fair value of the reporting unit was more than the carrying value of the reporting unit.

Income Taxes. Our tax provisions are based on our expected taxable income, statutory rates and tax-planning opportunities available to us in the various jurisdictions in which we operate. The determination of taxable income in any jurisdiction requires the interpretation of the related tax laws. We are at risk that a taxing authority's final determination of our tax liabilities may differ from our interpretation. Our effective tax rate may fluctuate from year to year, as our operations are conducted in different taxing jurisdictions, the amount of pre-tax income fluctuates and our estimates regarding the realizability of items such as foreign tax credits may change.

We account for any applicable interest and penalties on uncertain tax positions as a component of our provision for income taxes on our financial statements. Current income tax expense represents either nonresident withholding taxes or the liabilities expected to be reflected on our income tax returns for the current year, while the net deferred income tax expense or benefit represents the change in the balance of deferred tax assets or liabilities as reported on our balance sheet.

We establish valuation allowances to reduce deferred tax assets when it is more likely than not that some portion or all of the deferred tax assets will not be realized in the future. Provisions for valuation allowances impact our income tax provision in the period in which such adjustments are identified and recorded.

In March 2016, the FASB issued ASU 2016-09, " Compensation – Stock Compensation Improvements to Employee Share-Based Payment Accounting ." This update requires that all excess tax benefits and tax deficiencies (including tax benefits of dividends on share-based payment awards) should be recognized as income tax expense or benefit in the statement of operations. The tax effects of exercised or vested awards should be treated as discrete items in the reporting period in which they occur. An entity also should recognize excess tax benefits regardless of whether the benefit reduces taxes payable in the current period. Currently, an entity must determine, for each award, whether the difference between the deduction for tax purposes and the compensation cost recognized for financial reporting purposes results in either an excess tax benefit or a tax deficiency. The amendments in this update are effective for us beginning January 1, 2017. Through December 31, 2016, we recognized excess tax benefits in additional paid-in capital, and tax deficiencies have been recognized as an offset to accumulated excess tax benefits. In 2017 and 2018, we recorded a tax deficiency in the first quarter and, under this new standard, we recognized it as a discrete item in our statement of operations rather than in additional paid-in capital. We also expect a tax deficiency in the first quarter of 2019, which will be recognized as a discrete item in our statement of operations.

As further discussed in Note 4, "Income Taxes," of our Notes to Consolidated Financial Statements included in this report, the Tax Act was enacted on December 22, 2017, and significantly affected how the United States imposes income tax on multinational corporations. The U.S. Department of the Treasury and other regulatory bodies continue to finalize changes to existing laws and regulations which may result from the Tax Act. In accordance with SEC Staff Accounting Bulletin No. 118 ("SAB No. 118"), we recorded provisional estimates to reflect the effects of the provisions of the Tax Act on our income tax assets and liabilities as of December 31, 2017. We have collected additional information to complete our assessment of the impacts of these changes on our operations and recorded income tax assets and liabilities as of December 31, 2018 .

For a summary of our major accounting policies and a discussion of recently adopted accounting standards, please see Note 1 of our Notes to Consolidated Financial Statements included in this report.

Liquidity and Capital Resources

We consider our liquidity and capital resources adequate to support our operations and growth initiatives. At December 31, 2018 , we had working capital of $750 million , including cash and cash equivalents of $354 million . Additionally, we had $500 million available through our revolving credit facility under a credit agreement further described below.

In November 2014, we completed the public offering of $500 million aggregate principal amount of 4.650% Senior Notes due 2024 (the "2024 Senior Notes"). We pay interest on the 2024 Senior Notes on May 15 and November 15 of each year. The 2024 Senior Notes are scheduled to mature on November 15, 2024.

In February 2018, we completed the public offering of $300 million aggregate principal amount of 6.000% Senior Notes due 2028 (the "2028 Senior Notes"). We pay interest on the 2028 Senior Notes on February 1 and August 1 of each year. The 2028 Senior Notes are scheduled to mature on February 1, 2028.

We may redeem some or all of the 2024 Senior Notes and the 2028 Senior Notes (collectively, the "Senior Notes") at specified redemption prices. We used the net proceeds from the 2028 Senior Notes to repay our term loan indebtedness described further below.

In October 2014, we entered into a credit agreement (as amended, the "Credit Agreement") with a group of banks. The Credit Agreement initially provided for a $500 million five-year revolving credit

facility (the "Revolving Credit Facility"). Subject to certain conditions, the aggregate commitments under the Revolving Credit Facility may be increased by up to $300 million at any time upon agreement between us and existing or additional lenders. Borrowings under the Revolving Credit Facility may be used for general corporate purposes. The Credit Agreement also provided for a $300 million term loan, which we repaid in full in February 2018, using net proceeds from the issuance of our 2028 Senior Notes referred to above, and cash on hand.

In February 2018, we entered into Agreement and Amendment No. 4 to the Credit Agreement ("Amendment No. 4"). Amendment No. 4 amended the Credit Agreement to, among other things, extend the maturity of the Revolving Credit Facility to January 25, 2023 with the extending Lenders, which represent 90% of the existing commitments of the Lenders, such that the total commitments for the Revolving Credit Facility will be $500 million until October 25, 2021, and thereafter $450 million until January 25, 2023.

Borrowings under the Revolving Credit Facility bear interest at an Adjusted Base Rate or the Eurodollar Rate (both as defined in the Credit Agreement), at our option, plus an applicable margin based on our Leverage Ratio (as defined in the Credit Agreement) and, at our election, based on the ratings of our senior unsecured debt by designated ratings services, thereafter to be based on such debt ratings. The applicable margin varies: (1) in the case of advances bearing interest at the Adjusted Base Rate, from 0.125% to 0.750% ; and (2) in the case of advances bearing interest at the Eurodollar Rate, from 1.125% to 1.750% . The Adjusted Base Rate is the highest of (1) the per annum rate established by the administrative agent as its prime rate, (2) the federal funds rate plus 0.50% and (3) the daily one-month LIBOR plus 1% . We pay a commitment fee ranging from 0.125% to 0.300% on the unused portion of the Revolving Credit Facility, depending on our Leverage Ratio. The commitment fees are included as interest expense in our consolidated financial statements.

The Credit Agreement contains various covenants that we believe are customary for agreements of this nature, including, but not limited to, restrictions on our ability and the ability of each of our subsidiaries to incur debt, grant liens, make certain investments, make distributions, merge or consolidate, sell assets and enter into certain restrictive agreements. We are also subject to a maximum adjusted total Capitalization Ratio (as defined in the Credit Agreement) of 55%. The Credit Agreement includes customary events of default and associated remedies. As of December 31, 2018 , we were in compliance with all the covenants set forth in the Credit Agreement.

We have two interest rate swaps in place on a total of $200 million of the 2024 Senior Notes for the period to November 2024. See Note 7 of Notes to Consolidated Financial Statements included in this report for a description of these interest rate swaps.

We incurred $6.9 million and $4.2 million of issuance costs related to the 2024 Senior Notes and the 2028 Senior Notes, respectively, and $2.6 million of new loan costs, including costs of the amendments prior to Amendment No. 4, related to the Credit Agreement. The costs, net of accumulated amortization, are included as a reduction of Long-term debt in our Consolidated Balance Sheet, as it pertains to the Senior Notes, and in Other non-current assets as it pertains to the Credit Agreement. We are amortizing these costs to Interest expense through the maturity date for the Senior Notes and to January 2023 for the Credit Agreement.

Our maximum outstanding indebtedness during 2018 under the Credit Agreement and the Senior Notes was $800 million, and our total interest costs, including commitment fees, were $45 million .

Our capital expenditures, including business acquisitions, for 2018 , 2017 and 2016 were $178 million , $105 million and $143 million , respectively. Our capital expenditures in 2018 included $46 million in our ROV segment, $25 million in our Subsea Products segment and $100 million in our Subsea Projects segment. Our capital expenditures in 2018 included the acquisition of Ecosse for approximately $68 million in our Subsea Projects segment. Ecosse builds and operates seabed preparation, route clearance and trenching tools for submarine cables and pipelines on an integrated basis that includes vessels, ROVs and survey services.  Enabling technologies acquired in the transaction include Ecosse's modular seabed system, capable of completing the entire trenching

work scope (route preparation, boulder clearance, trenching and backfill), and its newly developed trenching system. These systems primarily serve the shallow water offshore renewables market.

Our capital expenditures in 2017 included $40 million in our ROV segment, $28 million in our Subsea Products segment and $30 million in our Subsea Projects segment. Our capital expenditures in 2016 included: $50 million in our ROV segment; $57 million in our Subsea Products segment and $26 million in our Subsea Projects segment.

 

For 2019 , we expect our capital expenditures to be in the range of $105 million to $125 million , exclusive of business acquisitions. This includes approximately $40 million to $50 million of maintenance capital expenditures and $65 million to $75 million of growth capital expenditures, including the purchase of equipment needed to support the Brazil drill pipe riser contract awarded in 2018 and the final payments to complete the Jones Act vessel Ocean Evolution in our Subsea Projects segment. We expect to place the Ocean Evolution into service during the second quarter of 2019 .

Our capital expenditures during 2018 , 2017 and 2016 included $46 million , $40 million and $50 million , respectively, in our ROV segment, principally for upgrades to our ROV fleet and to replace certain units we retired and for facilities infrastructure to support our ROV fleet. We currently plan to add new ROVs only to meet contractual commitments. We added six , seven and six ROVs to our fleet and retired ten , eight and 41 units during 2018 , 2017 and 2016 , respectively, resulting in a total of 275 work-class systems in our fleet at December 31, 2018 . Over the past three years, we retired a greater number of ROVs than we have added due to market conditions and outlook.

We previously had several deepwater vessels under long-term charter. The last of our long-term charters expired in March 2018. With the current market conditions, our philosophy is to attempt to charter vessels for specific projects on a back-to-back basis with the vessel owners. This generally minimizes our contract exposure by closely matching our obligations with our revenue. Unless indicated otherwise, each of the chartered vessels discussed below is a deepwater multiservice subsea support vessel outfitted with two of our high-specification work-class ROVs.

In 2012, we moved the chartered vessel Ocean Intervention III to Angola and also chartered the Bourbon Oceanteam 101 to work on a three-year field support vessel services contract for a unit of BP plc. We had extended the charter of the Bourbon Oceanteam 101 to January 2017. However, in early 2016, the customer exercised its right, under the field support vessel services contract, to terminate its use of the Bourbon Oceanteam 101 at the end of May 2016. Under the terms of the contract, the costs incurred by us associated with the early release and demobilization of the vessel were reimbursed by the customer. Following the release of the vessel, we redelivered it to the vessel supplier. The charter for the Ocean Intervention III expired at the end of July 2017. Under the field support vessel services contract, which was extended through January 2022, we are continuing to supply project management and engineering services. We also provide ROV tooling and asset integrity services as requested by the customer. Chartered vessels and barges are provided to the customer upon request.

In March 2013, we commenced a five-year bareboat charter for a Jones Act-compliant multiservice support vessel, the Ocean Alliance , we have been using in the U.S. Gulf of Mexico. In January 2015, we commenced a two-year contract with a customer for the use of the Ocean Alliance, which expired in January 2017. We returned the Ocean Alliance to the vessel owner in the first quarter of 2018 and continue to market the vessel, now renamed the Cade Candies , for spot market work in the U.S. Gulf of Mexico on a back-to-back basis with the owner.

In December 2013, we commenced a three-year charter for the Normand Flower, a multiservice subsea marine support vessel. We made modifications to the vessel and used the vessel in the U.S. Gulf of Mexico to perform inspection, maintenance and repair projects and hardware installations. In December 2016, we declined our option to extend the charter and the vessel was released.

In November 2015, we commenced a two-year charter for the use of the Island Pride, a multiservice subsea marine support vessel. We used the vessel under a two-year contract to provide field support services off the coast of India for an oil and gas customer based in India. In

November 2017, that field services contract expired and we declined our option to extend the vessel charter.

We also charter or lease vessels on a short-term basis as necessary to augment our fleet.

During the third quarter of 2013, we signed an agreement with a shipyard for the construction of a subsea support vessel, to be named the Ocean Evolution . We expect to take delivery in the first quarter and place the vessel into service in the second quarter of 2019. We intend for the vessel to be U.S. flagged and documented with a coastwise endorsement by the U.S. Coast Guard. The vessel has an overall length of 353 feet, a Class 2 dynamic positioning system, accommodations for 110 personnel, a helideck, a 250-ton active heave-compensated crane, a working moonpool, and two of our high specification 4,000 meter work-class ROVs. The vessel is also equipped with a satellite communications system capable of transmitting streaming video for real-time work observation by shore personnel. We anticipate the vessel will be used to augment our ability to provide subsea intervention services in the U.S. Gulf of Mexico. These services are required to perform inspection, maintenance and repair projects and hardware installations.

Our principal source of cash from operating activities is our net income (loss), adjusted for the non-cash expenses of depreciation and amortization, deferred income taxes and noncash compensation under our restricted stock plans. Our $37 million , $136 million and $339 million of cash provided from operating activities in 2018 , 2017 and 2016 , respectively, were affected by cash increases (decreases) of: (1) $(87) million , $13 million and $123 million , respectively, of changes in accounts receivable; (2) $(12) million , $66 million and $18 million , respectively, of changes in inventory; and (3) $29 million , $(76) million and $(115) million , respectively, of changes in accounts payable and accrued liabilities. The decrease in cash related to accounts receivable in 2018 reflected higher business levels in the fourth quarter of 2018 , as compared to the fourth quarter of 2017 , along with timing of customer payments. The increase in cash related to changes in current liabilities in 2018 reflected timing of vendor payments. In each of 2017 and 2016 , our accounts receivable, inventory and accounts payable and accrued liabilities all decreased as a result of lower revenue and activity in general from the immediately preceding year. The 2016 decrease in inventory was in addition to write-downs totaling $30 million in our ROV and Subsea Products segments.

In 2018 , we used $99 million in net investing activities. We used $109 million to purchase property and equipment, $68 million for the acquisition of Ecosse and $10 million for the purchase of Angolan central bank bonds indexed to the U.S. dollar. These outlays were partially offset by $70 million of proceeds received from maturities and redemptions of Angola bonds and $15 million of proceeds received from the sale of a cost method investment. In 2017 , we used a net of $112 million in investing activities, with $105 million used to fund the capital expenditures and business acquisitions and $11 million used to purchase Angolan central bank bonds indexed to the U.S. dollar. In 2016 , we used a net of $169 million in investing activities, with $143 million used to fund the capital expenditures and business acquisitions, and $39 million used to purchase Angolan central bank bonds indexed to the U.S. dollar.

In 2018 , we used $6 million in financing activities, with $300 million for a repayment of the term loan facility, substantially offset by $296 million of the proceeds received from the issuance of the 2028 Senior Notes, net of issuance costs. In 2017 , we used $46 million in financing activities, primarily for the $44 million of cash dividends we paid. In 2016 , we used $96 million in financing activities, primarily for the $94 million of cash dividends we paid.

In December 2014, our Board of Directors approved a share repurchase program under which we may repurchase up to 10 million shares of our common stock on a discretionary basis. The program calls for the repurchases to be made in the open market, or in privately negotiated transactions from time to time, in compliance with applicable laws, rules and regulations, including Rule 10b-18 under the Securities Exchange Act of 1934, as amended, subject to market and business conditions, levels of available liquidity, cash requirements for other purposes, applicable legal requirements and other relevant factors. The timing and amount of any repurchases will be determined by management based on its evaluation of these factors. We expect that any shares repurchased under the new program will be held as treasury stock for future use. The program does not obligate us to repurchase any particular number of shares. We account for the shares we hold in treasury under

the cost method, at average cost. Through December 31, 2015 under the program, we repurchased 2 million shares of our common stock for $100 million . We have not repurchased any shares under the program since December 31, 2015 .

As of December 31, 2018 , we retained 12.3 million of the shares we had repurchased through this and a prior program. We expect to hold the shares repurchased for future use.

Because of our significant foreign operations, we are exposed to currency fluctuations and exchange rate risks. We generally minimize these risks primarily through matching, to the extent possible, revenue and expense in the various currencies in which we operate. Cumulative translation adjustments as of December 31, 2018 relate primarily to our net investments in, including long-term loans to, our foreign subsidiaries. A stronger U.S. dollar against the U.K. pound sterling, Norwegian kroner and Brazilian real would result in lower operating income. See Item 7A – "Quantitative and Qualitative Disclosures About Market Risk."

Results of Operations

Additional information on our business segments is shown in Note 8 of the Notes to Consolidated Financial Statements included in this report.

Energy Services and Products. The table that follows sets out revenue and profitability for the business segments within our Energy Services and Products business. In the ROV section of the table that follows, "Days available" includes all days from the first day that an ROV is placed in service until the ROV is retired. All days in this period are considered available days, including periods when an ROV is undergoing maintenance or repairs. Our ROVs do not have scheduled maintenance or repair that requires significant time when the ROVs are not available for utilization.