10-K 1 d664462d10k.htm 10-K 10-K
Table of Contents

 

 

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

 

 

Form 10-K

(Mark One)

 

þ ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the fiscal year ended December 31, 2013

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: 001-34726

 

 

LyondellBasell Industries N.V.

(Exact name of registrant as specified in its charter)

 

The Netherlands   98-0646235

(State or other jurisdiction of

incorporation or organization)

 

(I.R.S. Employer

Identification No.)

 

1221 McKinney St.,

Suite 300

Houston, Texas

USA 77010

 

4th Floor, One Vine Street

London

W1J0AH

The United Kingdom

 

Stationsplein 45

3013 AK Rotterdam

The Netherlands

(Address of principal executive offices) (Zip Code)

 

(713) 309-7200   +44 (0) 207 220 2600   +31 (0)10 275 5500

(Registrant’s telephone numbers, including area codes)

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

 

Title of Each Class

 

Name of Each Exchange On Which Registered

Ordinary Shares, €0.04 Par Value   New York Stock Exchange

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.    þ  Yes    ¨  No

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    þ  No

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

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate website, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).    þ  Yes    ¨  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 the registrant’s knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K.  ¨

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

 

Large accelerated filer   þ    Accelerated filer   ¨
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    þ  No

The aggregate market value of common stock held by non-affiliates of the registrant on June 30, 2013, the last business day of the registrant’s most recently completed second fiscal quarter, based on the closing price on that date of $66.26, was $27.8 billion. For purposes of this disclosure, in addition to the registrant’s executive officers and members of its Supervisory Board, the registrant has included Access Industries, LLC and Apollo Management Holdings, L.P. and their affiliates as “affiliates.”

The registrant had 546,551,455 shares outstanding at February 18, 2014 (excluding 31,880,560 treasury shares).

 

 

Documents incorporated by reference:

Portions of the Proxy Statement for the Annual Meeting of Shareholders to be held on April 16, 2014 (Part III)

 

 

 


Table of Contents
PART I   

1 and 2. Business and Properties

     3   
  Overview      3   
  Segments      3   
 

Olefins and Polyolefins Segments Generally

     4   
 

Olefins and Polyolefins Americas Segment

     7   
 

Olefins and Polyolefins Europe, Asia and International Segment

     9   
 

Intermediates and Derivatives Segment

     10   
 

Refining Segment

     14   
 

Technology Segment

     15   
  General      16   
 

Intellectual Property

     16   
 

Environmental

     16   
 

Employee Relations

     17   
 

Executive Officers of the Registrant

     18   
 

Description of Properties

     20   
 

Website Access to SEC Reports

     21   

1A. Risk Factors

     22   

1B. Unresolved Staff Comments

     32   

3. Legal Proceedings

     33   

4. Mine Safety Disclosures

     33   
PART II   

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

     34   

6. Selected Financial Data

     37   

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

     39   

7A. Quantitative and Qualitative Disclosures About Market Risk

     62   

8. Financial Statements and Supplementary Data

     65   

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

     136   

9A. Controls and Procedures

     136   

9B. Other Information

     136   
PART III   

10. Directors, Executive Officers and Corporate Governance

     137   

11. Executive Compensation

     137   

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

     137   

13. Certain Relationships and Related Transactions, and Director Independence

     137   

14. Principal Accounting Fees and Services

     137   

15. Exhibits, Financial Statement Schedules

     138   

Signatures

     139   


Table of Contents

CAUTIONARY STATEMENT FOR THE PURPOSES OF THE “SAFE HARBOR” PROVISIONS OF THE PRIVATE SECURITIES LITIGATION REFORM ACT OF 1995

This report contains “forward-looking statements” within the meaning of Section 27A of the Securities Act and Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”). You can identify our forward-looking statements by the words “anticipate,” “estimate,” “believe,” “continue,” “could,” “intend,” “may,” “plan,” “potential,” “predict,” “should,” “will,” “expect,” “objective,” “projection,” “forecast,” “goal,” “guidance,” “outlook,” “effort,” “target” and similar expressions.

We based the forward-looking statements on our current expectations, estimates and projections about ourselves and the industries in which we operate in general. We caution you these statements are not guarantees of future performance as they involve assumptions that, while made in good faith, may prove to be incorrect, and involve risks and uncertainties we cannot predict. In addition, we based many of these forward-looking statements on assumptions about future events that may prove to be inaccurate. Accordingly, our actual outcomes and results may differ materially from what we have expressed or forecast in the forward-looking statements. Any differences could result from a variety of factors, including the following:

 

   

the cost of raw materials represents a substantial portion of our operating expenses, and energy costs generally follow price trends of crude oil and/or natural gas; price volatility can significantly affect our results of operations and we may be unable to pass raw material and energy cost increases on to our customers;

 

   

our U.S. operations have benefited from low-cost natural gas and natural gas liquids; decreased availability of these materials (for example, from their export or regulations impacting hydraulic fracturing in the U.S.) could reduce the current benefits we receive; similarly, if crude oil prices fell materially, we would see less benefit from low-cost natural gas and natural gas liquids;

 

   

industry production capacities and operating rates may lead to periods of oversupply and low profitability; for example, there has been substantial capacity expansion announced in the U.S. olefins industry;

 

   

we may face operating interruptions at any of our facilities, which would negatively impact our operating results; for example, because the Houston refinery is our only refining operation, we would not have the ability to increase production elsewhere to mitigate the impact of any outage at that facility;

 

   

regulations may negatively impact our business by, among other things, restricting our operations, increasing costs of operations or requiring significant capital expenditures;

 

   

we face significant competition due to the commodity nature of many of our products and may not be able to protect our market position or otherwise pass on cost increases to our customers;

 

   

changes in general economic, business, political and regulatory conditions in the countries or regions in which we operate could increase our costs, restrict our operations and reduce our operating results;

 

   

our ability to implement business strategies may be negatively affected or restricted by, among other things, governmental regulations or policies;

 

   

uncertainties associated with worldwide economies could create reductions in demand and pricing, as well as increased counterparty risks, which could reduce liquidity or cause financial losses resulting from counterparty default;

 

   

the negative outcome of any legal, tax and environmental proceedings or changes in laws or regulations regarding legal, tax and environmental matters may increase our costs or otherwise limit our ability to achieve savings under current regulations;

 

   

we may be required to reduce production or idle certain facilities because of the cyclical and volatile nature of the supply-demand balance in the chemical and refining industries, which would negatively affect our operating results;

 

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we rely on continuing technological innovation, and an inability to protect our technology, or others’ technological developments could negatively impact our competitive position;

 

   

we have substantial international operations, and continued economic uncertainties, fluctuations in exchange rates, valuations of currencies and our ability to access cash from operations in certain jurisdictions on a tax-efficient basis, if at all, could negatively affect our liquidity and our results of operations;

 

   

we are subject to the risks of doing business at a global level, including wars, terrorist activities, political and economic instability and disruptions and changes in governmental policies, which could cause increased expenses, decreased demand or prices for our products and/or disruptions in operations, all of which could reduce our operating results;

 

   

if we are unable to comply with the terms of our credit facilities and other financing arrangements, those obligations could be accelerated, which we may not be able to repay; and

 

   

we may be unable to incur additional indebtedness or obtain financing on terms that we deem acceptable, including for refinancing of our current obligations; higher interest rates and costs of financing would increase our expenses.

Any of these factors, or a combination of these factors, could materially affect our future results of operations and the ultimate accuracy of the forward-looking statements. These forward-looking statements are not guarantees of future performance, and our actual results and future developments may differ materially from those projected in the forward-looking statements. Our management cautions against putting undue reliance on forward-looking statements or projecting any future results based on such statements or present or prior earnings levels.

All subsequent written and oral forward looking statements attributable to us or any person acting on our behalf are expressly qualified in their entirety by the cautionary statements contained or referred to in this section and any other cautionary statements that may accompany such forward-looking statements. Except as otherwise required by applicable law, we disclaim any duty to update any forward-looking statements. Additional factors that could cause results to differ materially from those described in the forward-looking statements can be found in the “Risk Factors” section of this report on page 22.

 

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PART I

Items 1 and 2. Business and Properties

OVERVIEW

LyondellBasell Industries N.V. is a global, independent chemical company and was incorporated under Dutch law on October 15, 2009. Unless otherwise indicated, the “Company,” “we,” “our,” “us” and “LyondellBasell” are used in this report to refer to the businesses of LyondellBasell Industries N.V. and its consolidated subsidiaries. We are one of the world’s top five independent chemical companies based on revenues.

We participate globally across the petrochemical value chain and are an industry leader in many of our product lines. Our chemicals businesses consist primarily of large processing plants that convert large volumes of liquid and gaseous hydrocarbon feedstocks into plastic resins and other chemicals. Our chemical products tend to be basic building blocks for other chemicals and plastics, while our plastic products are typically used in large volume applications. Our customers use our plastics and chemicals to manufacture a wide range of products that people use in their everyday lives including food packaging, home furnishings, automotive components, paints and coatings. Our refining business consists of our Houston refinery, which processes crude oil into products such as gasoline, diesel and jet fuel.

Our financial performance is influenced in general by the supply and demand for the products that we produce, the cost and availability of feedstocks, global and regional competitor capacity, our operational efficiency and our ability to control costs. We have a strong operational focus and, as a producer of large volume commodities, continuously strive to differentiate ourselves through safe, reliable and low-cost operations in all our businesses. During recent years the cost of natural gas-derived raw materials in the U.S. versus the global cost of crude oil-derived raw materials has had a significant positive influence on the profitability of our North American operations. To a lesser extent, our differentiated assets and technology also positively influence our performance as compared to our peers and competitors. These include our propylene oxide and polypropylene technologies; flexible feedstock olefins plants in the U.S.; joint venture olefins and polyolefins plants with access to low-cost feedstock, particularly in Saudi Arabia; and our Houston refinery which is capable of processing heavy, high-sulfur crude.

SEGMENTS

We manage our operations through five operating segments. Our reportable segments are:

 

   

Olefins and Polyolefins—Americas (“O&P—Americas”). Our O&P—Americas segment produces and markets olefins, including ethylene and ethylene co-products, and polyolefins.

 

   

Olefins and Polyolefins—Europe, Asia, International (“O&P—EAI”). Our O&P–EAI segment produces and markets olefins, including ethylene and ethylene co-products, polyolefins and polypropylene compounds.

 

   

Intermediates and Derivatives (“I&D”). Our I&D segment produces and markets propylene oxide and its co-products and derivatives, acetyls, including methanol, ethanol, ethylene oxide and its derivatives, and oxygenated fuels, or oxyfuels.

 

   

Refining. Our Refining segment refines heavy, high-sulfur crude oil and other crude oils of varied types and sources available on the U.S. Gulf Coast.

 

   

Technology. Our Technology segment develops and licenses chemical and polyolefin process technologies and manufactures and sells polyolefin catalysts.

We regularly review our segments and the approach used by management to evaluate performance and resource allocation. In 2012, we moved the management responsibility for business decisions relating to oxyfuels

 

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to our I&D segment because profits generated by oxyfuels are more closely related to sourcing decisions regarding certain co-products of propylene oxide production, which is the core of our I&D segment. All comparable periods presented were revised to reflect this change.

Financial information about our business segments and geographical areas can be found in Note 22, Segment and Related Information, to the Consolidated Financial Statements. Information about the locations where we produce our primary products can be found under “Description of Properties.”

In 2013, 2012 and 2011, no single customer accounted for 10% or more of our total revenues.

Olefins and Polyolefins Segments Generally

We are a leading worldwide producer of olefins, including ethylene and propylene. We are also a leading producer of polyolefins, including polyethylene (“PE”), and the world’s largest producer of polypropylene (“PP”) and PP compounds. We manage our olefin and polyolefin business in two reportable segments, O&P–Americas and O&P–EAI.

Olefins—Ethylene is the most significant petrochemical in terms of worldwide production volume and is the key building block for PE and a large number of other chemicals, plastics and synthetics. The production of ethylene results in co-products such as propylene, butadiene and aromatics. Ethylene and its co-products are fundamental to many parts of the economy, including the production of consumer products, packaging, housing and automotive components and other durable and nondurable goods.

Polyolefins—Polyolefins are thermoplastics and comprise approximately two-thirds of worldwide thermoplastics demand. Since their industrial commercialization, thermoplastics have been used in wide-ranging applications and products that improve safety and comfort and enhance the everyday quality of life. Our products are used in consumer, automotive and industrial applications ranging from food and beverage packaging to housewares and construction materials. We produce high density polyethylene (“HDPE”), low density polyethylene (“LDPE”) and linear low density polyethylene (“LLDPE”). We also produce PP homopolymers, PP impact copolymers and PP random copolymers. We produce and market several specialty product lines including PP compounds, Catalloy process resins and polybutene-1 (“PB-1”), focusing on unique polyolefins and compounds that offer a wide range of performance characteristics. Typical properties of such specialty polyolefins and compounds include impact-stiffness balance, scratch resistance, soft touch and heat sealability. End uses include automotive and industrial products and materials. PP compounds are produced from blends of polyolefins and additives and are sold mainly to the automotive and home appliances industries. The Catalloy process is proprietary technology that is not licensed to third parties. As a result, we are the only manufacturer of Catalloy process resins, which are used primarily in roofing, packaging and automotive applications.

Sales of PE (HDPE, LDPE and LLDPE, collectively) accounted for 17% of our total revenues in 2013 and 15% in each of 2012 and 2011. Sales of PP, including Catalloy, accounted for approximately 21% of our total revenues in 2013 and 19% in each of 2012 and 2011.

 

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The following table outlines the primary products of our O&P segments, annual processing capacity as of December 31, 2013, and the primary uses for those products. Capacities, which are presented in pounds unless otherwise indicated, include 100% of the capacity of our joint venture facilities. The joint ventures’ proportional share of capacity is shown in the footnotes to the table, below.

 

Product

 

Annual Capacity(1)

 

Primary Uses

    

Americas

  

EAI

  

Total

   

Olefins:

       

Ethylene

  9.9 billion    6.5 billion    16.4 billion   Ethylene is used as a raw material to manufacture polyethylene, ethylene oxide, ethanol, ethylene dichloride, styrene, vinyl acetate monomer (“VAM”) and other products.

Propylene

  5.5 billion    6.0 billion    11.5 billion   Propylene is used to produce PP, acrylonitrile, propylene oxide (“PO”) and other products.

Butadiene

  1.1 billion    700 million    1.8 billion   Butadiene is used to manufacture styrene-butadiene rubber and polybutadiene rubber, which are used in the manufacture of tires, hoses, gaskets and other rubber products. Butadiene is also used in the production of paints, adhesives, nylon clothing, carpets, paper coatings and engineered plastics.

Polyolefins:

         

HDPE

  3.3 billion    4.2 billion    7.5 billion   HDPE is used to manufacture grocery, merchandise and trash bags; food containers for items from frozen desserts to margarine; plastic caps and closures; liners for boxes of cereal and crackers; plastic drink cups and toys; dairy crates; bread trays; pails for items from paint to fresh fruits and vegetables; safety equipment, such as hard hats; house wrap for insulation; bottles for household and industrial chemicals and motor oil; milk, water, and juice bottles; large tanks for storing liquids such as agricultural and lawn care chemicals; and pipe.

LDPE

  1.3 billion    2.8 billion    4.1 billion   LDPE is used to manufacture food packaging films; plastic bottles for packaging food and personal care items; dry cleaning bags; ice bags; pallet shrink wrap; heavy-duty bags for mulch and potting soil; boil-in-bags; coatings on flexible packaging products; and coatings on paper board such as milk cartons.

 

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Product

 

Annual Capacity(1)

  

Primary Uses

    

Americas

  

EAI

  

Total

    

LLDPE

  1.3 billion    —      1.3 billion    LLDPE is used to manufacture garbage and lawn-leaf bags; industrial can liners; housewares; lids for coffee cans and margarine tubs; dishpans, home plastic storage containers, and kitchen trash containers; large toys like outdoor gym sets; drip irrigation tubing; insulating resins and compounds used to insulate copper and fiber optic wiring; shrink wrap for multi-packaging canned food, bag-in-box bags, produce bags, and pallet stretch wrap.

PP

  4.4 billion    13.0 billion    17.4 billion    PP is primarily used to manufacture fibers for carpets, rugs and upholstery; housewares; medical products; automotive interior trim, fascia, running boards, battery cases, and bumpers; toys and sporting goods; fishing tackle boxes; and bottle caps and closures.

Specialty Polyolefins:

          

PP compounds

  —      2.6 billion    2.6 billion    PP compounds are used to manufacture automotive interior and exterior trims, dashboards, bumpers and under-hood applications; base material for products and parts used in appliances; anti-corrosion coatings for steel piping, wire and cable.

Catalloy process resins

  600 million    600 million    1.2 billion    Catalloy process resins are used primarily in modifying polymer properties in film applications and molded products; for specialty films, geomembrane liners, and roofing materials; in bitumen modification for roofing and asphalt applications; and for automotive bumpers.

PB-1 resins

  —      110 million    110 million    PB-1 resins are used in flexible pipes, resins for seal-peel film, film modification, hot melt applications, consumer packaging and adhesives.

Aromatics:

          

Benzene (in gallons)

  195 million    —      195 million    Benzene is used to produce styrene, phenol and cyclohexane. These products are used in the production of nylon, plastics, synthetic rubber and polystyrene. Polystyrene is used in insulation, packaging and drink cups.

 

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(1) Represents total annual name plate capacity, which includes approximately 1,650 million pounds of ethylene; approximately 2,500 million pounds of propylene; approximately 1,010 million pounds of HDPE; approximately 780 million pounds of LDPE; approximately 670 million pounds (Americas) and 4,960 million pounds (EAI) of PP; and approximately 200 million pounds of PP compounds of name plate capacity owned by third parties either through joint venture arrangements or other contractual relationships. In some situations, the Company and the third parties may have access to the other’s capacity through certain arrangements.

Olefins and Polyolefins—Americas Segment

Overview

Our O&P—Americas segment produces and markets olefins, polyolefins, aromatics, specialty products and ethylene co-products. In addition, we produce specialty products including Catalloy and Plexar resins.

Sales & Marketing / Customers

Our ethylene production is consumed internally as a raw material in the production of polymers and other derivatives, with the balance sold to third party customers under multi-year contracts or on a spot basis. We have announced ethylene expansion projects for our La Porte, Channelview and Corpus Christi, Texas facilities which are projected for completion in 2014 (La Porte) and 2015 (Channelview and Corpus Christi). In total, we expect that these projects will add additional ethylene capacity of approximately 1.85 billion pounds per year.

We are a net purchaser of propylene, a raw material used in the production of PO, PP and other derivatives. Our butadiene production is sold to the external market under multi-year contracts. All of our production of benzene is used as a raw material in the production of styrene by our I&D segment, and we purchase additional benzene to meet our needs.

In addition to purchases of propylene and benzene, at times we purchase ethylene and butadiene for resale, when necessary, to satisfy customer demand above our own production levels. Volumes of any of these products purchased for resale can vary significantly from period to period. However, purchased volumes have not historically had a significant impact on profits.

In the U.S., most of the ethylene and propylene production of our Channelview, Corpus Christi and La Porte, Texas facilities is shipped via a pipeline system, which has connections to numerous U.S. Gulf Coast consumers. This pipeline system, some of which is owned and some of which is leased, extends from Corpus Christi to Mont Belvieu to Port Arthur, Texas, as well as into the Lake Charles, Louisiana area. In addition, exchange agreements with other ethylene and co-products producers allow access to customers who are not directly connected to this pipeline system. Some ethylene is shipped by rail car from Clinton, Iowa to Morris, Illinois and also to customers. A pipeline owned and operated by an unrelated party is used to transport ethylene from Morris, Illinois to Tuscola, Illinois and is used as a raw material in the production of ethanol. Some propylene is shipped by ocean going vessel. Butadiene, benzene, toluene and other products are distributed by pipeline, rail car, truck, barge or ocean going vessel.

Our PP and PE production is typically sold through our sales organization to an extensive base of established customers and distributors servicing both the domestic and export markets either under annual contracts or on a spot basis. We have regional sales offices in various locations in North America and our polyolefins primarily are transported in North America by railcar or truck. Export sales are generally to customers in Central and South America. We also sell PP into our PP compounds business, which is managed worldwide by our O&P–EAI segment.

 

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Joint Venture Relationships

We participate in a joint venture arrangement in Mexico, which provides us with capacity for approximately 640 million pounds of PP production. The capacity is based on our percentage ownership of the joint ventures’ total capacity. We do not hold a majority interest in or have operational control of this joint venture.

Raw Materials

Raw material cost is the most significant cost component for the production of ethylene and its co-products. The primary raw materials that can be used are heavy liquids and natural gas liquids (“NGLs”). Heavy liquids include crude oil-based naphtha and gas oil, as well as domestically sourced condensate, a very light crude oil resulting from natural gas production (collectively referred to as “heavy liquids”). NGLs include ethane, propane and butane. The use of heavy liquid raw materials results in the production of a significant amount of co-products such as propylene, butadiene and benzene, as well as gasoline blending components, while the use of NGLs results in the production of a smaller amount of co-products.

Historically, facilities using heavy liquids as feedstock generated higher margins than those using ethane. However, in recent years ethane has had a significant cost advantage over heavy liquids due to technological advances for extracting shale gas which have led to increased supplies of NGLs. A plant’s flexibility to consume a wide range of raw materials generally will provide an advantage over plants that are restricted in their processing capabilities. We can process significant quantities of either heavy liquids or NGLs. We estimate that in the U.S. we can process more than 85% NGLs. Changes in the raw material feedstock utilized in the production process will result in variances in production capacities among products. We believe our raw material flexibility in the U.S. is a key advantage in our production of ethylene and its co-products.

In North America, we also purchase large amounts of natural gas to be used primarily as an energy source in our business and as the primary feedstock for methanol production by our I&D segment via market-based contractual arrangements from numerous suppliers.

Industry Dynamics / Competition

With respect to olefins and polyolefins, competition is based on price, product quality, product delivery, reliability of supply, product performance and customer service. Industry consolidation in North America has led to fewer, although larger, competitors. Profitability is affected not only by supply and demand for olefins and polyolefins, but also by raw material costs and price competition among producers, which may intensify due to, among other things, the addition of new capacity. In general, demand is a function of worldwide economic growth, which fluctuates.

We compete in North America with other large marketers and producers, including global chemical companies, chemical divisions of large oil companies and regional marketers and producers.

Based on published data, we believe we were, as of December 31, 2013:

 

   

the largest producer of ethylene in North America, with ethylene rated capacity of approximately 9.9 billion pounds per year, or approximately 13% of total North American ethylene production capacity;

 

   

the third largest producer of PE in North America with 5.9 billion pounds per year of capacity, or approximately 13% of North American capacity; and

 

   

the largest producer of PP in North America, including our share of our Indelpro joint venture capacity, with 3.3 billion pounds, or approximately 18% of the North American capacity.

 

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Olefins and Polyolefins–Europe, Asia, International Segment

Overview

Our O&P—EAI segment produces and markets olefins (ethylene and ethylene co-products) and polyolefins. We also produce significant quantities of other differentiated products such as Catalloy process resins and PB-1. Our O&P–EAI segment manages our worldwide PP compound business (including our facilities in North and South America), our worldwide PB-1 business, and our Catalloy process resins produced in Europe. PP compounds consist of specialty products produced from blends of polyolefins and additives and are sold mainly to the automotive and durable goods industries. PB-1, a family of butene-based polymers, is mainly used in pipe applications and for under-floor heating and thermo sanitary systems.

Sales & Marketing / Customers

Our ethylene production is primarily consumed internally as a raw material in the production of polymers and we purchase additional ethylene to meet our production needs. Our propylene production is used as a raw material in the production of propylene oxide (“PO”) and PP, and we purchase propylene where our internal needs exceed our internal production. European ethylene and propylene production is generally fully integrated with our downstream facilities in Europe.

We produce and sell butadiene to external customers under multi-year contracts and on a spot basis.

With respect to PP and PE, our production is typically sold through our sales organization to an extensive base of established customers under annual contracts or on a spot basis and is also sold through distribution. Our polyolefins primarily are transported in Europe by railcar or truck. We believe that, over a business cycle, average sales prices and profit margins for specialty polymers tend to be higher than average sales prices and profit margins for higher-volume commodity polyolefins or polymers.

Our regional sales offices are in various locations, including The Netherlands, Hong Kong, China, India, Australia and United Arab Emirates. We also operate through a worldwide network of local sales and representative offices in Europe, Asia and Africa. Our joint ventures typically manage their domestic sales and marketing efforts independently, and we typically operate as their agent/distributor for all or a portion of their exports.

Joint Venture Relationships

We participate in several manufacturing joint ventures in Saudi Arabia, Thailand, Poland, Australia, Japan and South Korea. We do not hold majority interests in any of the joint venture relationships, nor do we have operational control. These ventures provide us with additional production capacity of approximately 2,630 million pounds of PP, approximately 810 million pounds of propylene, approximately 550 million pounds of ethylene, approximately 570 million pounds of HDPE, approximately 340 million pounds of LDPE and approximately 160 million pounds of PP compounding. These capacities are based on our percentage ownership interest in the joint ventures’ total capacities. We realize profits or losses from these ventures as income from equity investments.

We generally license our polyolefin process technologies and supply catalysts to our joint ventures through our Technology segment. Some of our joint ventures source cost advantaged raw materials from their local shareholders.

Raw Materials

Raw material cost is the largest component of the total cost for the production of ethylene and its co-products. The primary raw materials used in our European olefin facilities are heavy liquids and, for our Saudi joint venture facilities, locally sourced and cost advantaged NGLs, including ethane, propane and butane. The

 

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principal raw materials used by our polyolefin and Catalloy process resin businesses are propylene and ethylene. In Europe, we have the capacity to produce approximately 50% of the propylene requirements of our European PP business and approximately 90% of the ethylene requirements of our European PE business. Propylene and ethylene requirements that are not produced internally are generally acquired via spot purchases or pursuant to long-term contracts with third-party suppliers.

Our PP compounding facilities generally receive their PP and other polymers from one of our wholly owned or joint venture facilities. PB-1 raw materials are sourced solely from external supply. Some of our joint ventures receive propylene and ethylene from their local shareholders under long-term contracts.

Industry Dynamics / Competition

With respect to olefins and polyolefins, competition is based on price, product quality, product delivery, reliability of supply, product performance and customer service. We compete with regional and multinational chemical companies and divisions of large oil companies. The petrochemical market in the EU has been affected by the volatility of naphtha, the primary feedstock for olefins in the region, as well as fluctuating demand as a result of uncertain economic conditions.

Based on published data and including our proportionate share of our joint ventures, we believe we were, as of December 31, 2013:

 

   

the fourth largest producer of ethylene in Europe with an ethylene rated capacity in Europe of approximately 4.3 billion pounds per year, or approximately 8% of total European ethylene capacity;

 

   

the largest producer of PP in Europe with 5.2 billion pounds per year of capacity, or approximately 22% of European PP capacity;

 

   

the largest producer of PE in Europe with 4.8 billion pounds per year of capacity, or approximately 21% of HDPE and 13% of LDPE European capacity; and

 

   

the largest PP compounds producer in the world with 2.4 billion pounds per year of capacity, with approximately 55% of that capacity in Europe, 20% in North America, and 25% in the rest of the world.

Intermediates and Derivatives Segment

Overview

Our I&D segment produces and markets PO and its co-products and derivatives, acetyls, including methanol, ethylene oxide and its derivatives, and oxyfuels (methyl tertiary butyl ether (“MTBE”) and ethyl tertiary butyl ether (“ETBE”)). PO co-products include styrene monomer (“SM”) and C4 chemicals (tertiary butyl alcohol (“TBA”), most of which is used to make oxyfuels, isobutylene and tertiary butyl hydro peroxide (“TBHP”)). PO derivatives include propylene glycol (“PG”), propylene glycol ethers (“PGE”) and butanediol (“BDO”). We believe that our proprietary PO and acetyls production process technologies provide us with a cost advantaged position for these products and their derivatives.

We produce PO through two distinct technologies, one of which yields TBA as the co-product and the other of which yields SM as the co-product. The two technologies are mutually exclusive, meaning that a manufacturing facility must be dedicated either to PO/TBA or to PO/SM. Based on published data regarding MTBE and ETBE capacity, we believe that we are the largest producer of MTBE/ETBE worldwide.

 

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The following table outlines the primary products, annual capacities, and primary uses for I&D’s products. Capacities, which are presented in pounds unless otherwise indicated, include 100% of the capacity of joint venture facilities.

 

Product

 

Annual Capacity(1)

  

Primary Uses

Propylene Oxide

  5.1 billion    PO is a key component of polyols, PG, PGE and BDO.

PO Co-Products:

    

Styrene Monomer

  5.6 billion    SM is used to produce plastics, such as expandable polystyrene for packaging, foam cups and containers, insulation products and durables and engineering resins.

Tertiary Butyl Alcohol

  5.8 billion    TBA is a precursor to Isobutylene, MTBE and ETBE. Isobutylene is used in the manufacture of synthetic rubber and lubricant additives as well as a gasoline blending component. MTBE is a high octane gasoline blending component; ETBE is an alternative gasoline blending component based on agriculturally produced ethanol.

PO Derivatives:

    

Propylene Glycol

  1.0 billion    PG is used to produce unsaturated polyester resins for bathroom fixtures and boat hulls; antifreeze, coolants and aircraft deicers; and cosmetics and cleaners.

Propylene Glycol Ethers

  560 million    PGE are used as solvents for paints, coatings, cleaners and a variety of electronics applications.

Butanediol

  390 million    BDO is used in the manufacture of engineering resins, films, personal care products, pharmaceuticals, coatings, solvents and adhesives.

Acetyls:

    

Methanol (in gallons)

  440 million(2)    Methanol is a raw material used to produce acetic acid, MTBE, formaldehyde and several other products, including adhesives, foams, plywood subfloors, solvents and windshield washer fluid.

Acetic Acid

  1.2 billion    Acetic acid is a raw material used to produce VAM, terephthalic acid (used to produce polyester for textiles and plastic bottles), industrial solvents and a variety of other chemicals.

Vinyl Acetate Monomer (“VAM”)

  700 million    VAM is used to produce a variety of polymers, products used in adhesives, water-based paint, textile coatings and paper coatings.

Ethylene Derivatives:

    

Ethylene Oxide (“EO”)

 

800 million EO equivalents; 400

million as pure EO

   EO is used to produce surfactants, industrial cleaners, cosmetics, emulsifiers, paint, heat transfer fluids and ethylene glycol.

Ethylene Glycol (“EG”)

  650 million    EG is used to produce polyester fibers and film, polyethylene terephthalate resin, heat transfer fluids and automobile antifreeze.

 

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Product

 

Annual Capacity(1)

  

Primary Uses

Ethylene Glycol Ethers

  220 million    Ethylene glycol ethers are used to produce paint and coatings, polishes, solvents and chemical intermediates.

Ethanol (in gallons)

  50 million    Ethanol is used as a fuel and a fuel additive and in the production of solvents as well as household, medicinal and personal care products.

 

(1) The annual capacities include approximately 2,280 million pounds of PO; approximately 2,390 million pounds of SM; approximately 110 million pounds of PGE; and approximately 30 million gallons of methanol production owned by third parties through joint venture or other contractual relationships.
(2) The capacities above include an additional 250 million gallons of methanol as a result of our December 2013 restart of a methanol unit at our Channelview facility.

Sales & Marketing / Customers

We sell our PO and its co-products and derivatives through multi-year sales agreements and spot sales and have a number of multi-year processing (or tolling) agreements. We sell most of our SM production into the North American and European merchant markets and to Asian and South American export markets through long-term sales contracts and processing agreements. We purchase SM for resale, when necessary, to satisfy customer demand that exceeds our production levels. Volumes of SM purchases made for resale can vary significantly from period to period. However, purchased volumes have not historically had a significant impact on profits. PO and SM are transported by barge, ocean going vessel, pipeline, railcar and tank truck.

Our I&D segment converts most of its TBA, which is produced as a co-product of the PO process, to isobutylene. Over half of the isobutylene is reacted with methanol or ethanol to produce MTBE and ETBE. The remaining isobutylene is sold into the external market as high purity and purity grade isobutylene.

We sell our MTBE and ETBE production under market and cost-based sales agreements and in the spot market. MTBE and ETBE are transported by barge, ocean going vessel and tank truck. Substantially all refiners and blenders have discontinued the use of MTBE in the U.S., partly as a result of governmental initiatives to increase use of bio-ethanol in gasoline and to reduce or effectively ban the use of MTBE. However, MTBE/ETBE demand for gasoline blending remains strong within most of the remaining worldwide market. Accordingly, we market MTBE and ETBE produced in the U.S. for use outside of the U.S. Japan has opted to use ETBE as a means of meeting its carbon dioxide reduction commitments under the Kyoto Protocol, and we source a significant portion of Japan’s bio-fuels needs. Some of our plants have the flexibility to produce either MTBE or ETBE to accommodate market needs.

Sales of MTBE, ETBE, acetyls, PO and PO co-products and derivatives are made by our marketing and sales personnel, and also through distributors and independent agents in the Americas, Europe, the Middle East, Africa and the Asia Pacific region.

Acetyls, including acetic acid and VAM, are consumed internally and sold worldwide under multi-year contracts and on a spot basis. Acetic Acid and VAM are shipped by barge, ocean going vessel, pipeline, railcar and tank truck. Sales are made through a direct sales force, agents and distributors. Our acetyls business uses methanol, which we produce internally, as a raw material for our production of acetic acid, solvents and MTBE, and we also sell the methanol under annual contracts and on a spot basis to large U.S. customers. In December, we restarted our 250 million gallon per year methanol plant in Channelview, Texas in order to take advantage of low-cost natural gas from shale formations. The methanol unit had been out of service since 2004 due to the rising cost of natural gas, the key feedstock for methanol production. Methanol is shipped by barge and pipeline.

EO and EG typically are sold under multi-year contracts and on a spot basis, with market and cost-based pricing. Glycol ethers are sold primarily into the solvent and distributor markets at market prices. The vast

 

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majority of the ethylene derivative products are sold in North America and Asia, primarily through our sales organizations. EO is shipped by railcar and its derivatives are shipped by railcar, truck, isotank and ocean going vessel.

Joint Venture Relationships

We have two PO joint ventures with Bayer Corporation. We operate four of our U.S. operating units for the U.S PO joint venture. Bayer’s interest represents ownership of an in-kind portion of the PO production of 1.5 billion pounds per year. We take, in-kind, the remaining PO production and all co-product (SM and TBA) production. We do not share marketing or product sales with Bayer under the U.S. PO joint venture. The parties’ rights in the joint venture are based on off take volumes as opposed to ownership percentages. Bayer also has the right to 50% of the PO and SM production of our European PO joint venture. Our proportional additional production capacity provided through this venture is approximately 340 million pounds of PO and approximately 740 million pounds of SM.

We also have joint venture manufacturing relationships in China. These ventures provide us with additional production capacity of approximately 115 million pounds of PO. This capacity is based on our operational share of the joint ventures’ total capacities.

In December 2013, we sold our 40% ownership interest in Nihon Oxirane Company, a joint venture in Japan that produces PO, PG and SM. For more information, see Note 9 to the Consolidated Financial Statements.

Raw Materials

The cost of raw materials generally is the largest component of total production cost for PO and its co-products and derivatives. The primary raw materials used for the production of PO and its co-products and derivatives are propylene, isobutane, mixed butane, ethylene and benzene. The market prices of these raw materials historically have been related to the price of crude oil, NGLs and natural gas, as well as supply and demand for the raw materials.

In the U.S., we obtain a large portion of our propylene, benzene and ethylene raw materials needed for the production of PO and its co-products and derivatives from our O&P–Americas segment. Raw materials for the non-U.S. production of PO and its co-products and derivatives are obtained from our O&P–EAI segment and from third parties. We consume a significant portion of our internally-produced PO in the production of PO derivatives.

The raw material requirements not sourced internally are purchased at market-based prices from numerous suppliers in the U.S. and Europe with which we have established contractual relationships, as well as in the spot market.

We purchase our ethanol requirements for the production of ETBE from third parties; the methanol for our MTBE production comes from internal production and third parties. The primary raw materials required for the production of acetic acid are carbon monoxide and methanol. We purchase carbon monoxide pursuant to a long-term contract under which pricing is based primarily on the cost of production. All methanol required for acetyls production is internally sourced. Natural gas is the primary raw material required for the production of methanol.

In addition to ethylene, acetic acid is a primary raw material for the production of VAM. For the production of VAM, we obtain our entire requirements for acetic acid and ethylene from our internal production. Historically we have used a large percentage of our acetic acid production to produce VAM.

Industry Dynamics / Competition

With respect to PO, its co-products and derivatives, competition is based on a variety of factors, including product quality and price, reliability of supply, technical support, customer service and potential substitute

 

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materials. Profitability is affected by the worldwide level of demand along with price competition, which may intensify due to, among other things, new industry capacity. PO demand growth could be impacted by further development of alternative bio-based PO derivatives. It is not possible to predict accurately the changes in raw material costs, market conditions and other factors that will affect industry profitability in the future. Our major worldwide competitors for sales of PO, it co-products and derivatives include other multinational chemical companies as well as some regional marketers and producers.

Based on published data regarding PO capacity, we believe that, excluding our partners’ shares of joint venture capacity, we are the second largest producer of PO worldwide, with approximately 13% of the total worldwide capacity for PO. Based on published data regarding MTBE and ETBE capacity, we believe we are the largest producer of MTBE/ETBE worldwide, with approximately 12% of the total worldwide capacity to produce these combined oxyfuels as of December 31, 2013. Based on published data regarding SM capacity, we believe that we are one of the largest producers of SM worldwide, with approximately 5% of the total worldwide capacity for SM as of December 31, 2013. We believe that we are the ninth and seventh largest producer of acetic acid and VAM, respectively, each with approximately 3% and 4% of the total worldwide capacity as of December 31, 2013.

Refining Segment

Overview

Our Houston refinery, which is located on the Houston Ship Channel in Houston, Texas, has a heavy, high-sulfur crude oil processing capacity of approximately 268,000 barrels per day on a calendar day basis (normal operating basis), or approximately 292,000 barrels per day on a stream day basis (maximum achievable over a 24 hour period). The Houston refinery has a Nelson Complexity Index of 12.5. The Houston refinery is a full conversion refinery designed to refine heavy, high-sulfur crude oil. This crude oil is more viscous and dense than traditional crude oil and contains higher concentrations of sulfur and heavy metals, making it more difficult to refine into gasoline and other high-value fuel products. However, this crude oil has historically been less costly to purchase than light, low-sulfur crude oil such as Brent. Recently, certain crudes such as West Texas Intermediate (WTI) and West Texas Sour (WTS) have been priced lower than normal trends due to transportation constraints.

On January 4, 2012, we ceased refinery operations at our Berre refinery in France. The cessation of operations was in accordance with an agreement executed in the fourth quarter of 2011 by certain of our French subsidiaries and union representatives. Additional information about the cessation of operations can be found in “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and Note 3, Discontinued Operations and Related Items, to the Consolidated Financial Statements.

The following table outlines the primary products of our Refining segment capacity as of December 31, 2013, unless otherwise noted, and the primary uses for those products.

 

Product

  

Capacity(1)

  

Primary Uses

Gasoline and components

   120,000 barrels per day    Automotive fuel

Ultra Low Sulfur Diesel

   95,000 barrels per day    Diesel fuel for cars and trucks

Jet Fuel

   25,000 barrels per day    Aviation fuel

Lube Oils

   4,000 barrels per day    Industrial lube oils, railroad engine additives and white oils for food-grade applications

Aromatics

   7,000 barrels per day    Intermediate chemicals

 

(1) Only key products for the Houston refinery are identified and therefore, the sum of capacities shown does not equal the facility’s total capacity.

 

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Sales & Marketing / Customers

Gasoline sales accounted for 9% of our total revenues in 2013, 10% in 2012 and 7% in 2011. The Houston refinery’s products primarily are sold in bulk to other refiners, marketers, distributors and wholesalers at market-related prices. Most of the Houston refinery’s products are sold under contracts with a term of one year or less or are sold in the spot market. The Houston refinery’s products generally are transported to customers via pipelines and terminals owned and operated by other parties.

Raw Materials

We purchase the crude oil used as a raw material for the Houston refinery on the open market on a spot basis and under a number of supply agreements with regional producers generally with terms varying from one to three years.

Industry Dynamics / Competition

Our refining competitors are major integrated oil companies, refineries owned or controlled by foreign governments and independent domestic refiners. Based on published data, as of January 2013, there were 143 operable crude oil refineries in the U.S., and total U.S. refinery capacity was approximately 17.8 million barrels per day. During 2013, the Houston refinery processed an average of approximately 232,000 barrels per day of crude oil, representing approximately 1.3% of all U.S. crude processing capacity.

Our refining operations compete for the purchases of crude oil based on price and quality. Supply disruptions could impact the availability and pricing. We compete in gasoline and distillate markets as a bulk supplier of fungible products satisfying industry and government specifications. Competition is based on price and location.

The markets for fuel products tend to be volatile as well as cyclical as a result of the changing global economy and changing crude oil and refined product prices. Crude oil prices are impacted by worldwide political events, the economics of exploration and production and refined products demand. Prices and demand for fuel products are influenced by seasonal and short-term factors such as weather and driving patterns, as well as by longer term issues such as the economy, energy conservation and alternative fuels. Industry fuel products supply is dependent on short-term industry operating capabilities and on long-term refining capacity.

A crack spread is a benchmark indication of refining margins based on the processing of a specific type of crude oil into an assumed selection of refined products. The Houston refinery generally tracks the Maya 2-1-1 crack spread, which represents the difference between the first month futures price of two barrels of Maya crude oil as set by Pemex and one barrel each of U.S. Gulf Coast 87 Octane Conventional Gasoline and U.S. Gulf Coast Ultralow-sulfur Diesel (“ULSD”). While these benchmark refining spreads are generally indicative of the level of profitability at the Houston refinery and similarly configured refineries, there are many other factors specific to each refinery and the industry in general, such as the cost of Renewable Identification Numbers (RINs) and the value of by-products, which influence operating results.

Technology Segment

Overview

Our Technology segment develops and licenses chemical, polyolefin and other process technologies and provides associated engineering and other services. Our Technology segment also develops, manufactures and sells polyolefin catalysts. We market our process technologies and our polyolefin catalysts to external customers and also use them in our own manufacturing operations.

 

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Our polyolefin process licenses are structured to provide a standard core technology, with individual customer needs met by adding customized modules that provide the required capabilities to produce the defined production grade slate and plant capacity. In addition to the basic license agreement, a range of services can also be provided, including project assistance; training; start-up assistance of the plant; and ongoing technical support after start-up. We may also offer marketing and sales services. In addition, licensees may continue to purchase polyolefin catalysts that are consumed in the production process, generally under long-term catalyst supply agreements with us.

Process Technology Licensing

We are a leading licensor of polyolefin process technologies. In addition, we license a selective portfolio of chemical process technologies in the fields of olefin recovery, olefin conversion, aromatics extraction and acetyls.

Polyolefin Catalysts

We are a leading manufacturer and supplier of polyolefin catalysts. Approximately 25% of our catalyst sales are intercompany as we are a large polyolefin producer.

Research and Development

Our research and development activities are designed to improve our existing products and processes, and discover and commercialize new materials, catalysts and processes. These activities focus on product and application development, process development, catalyst development and fundamental polyolefin focused research.

In 2013, 2012 and 2011, our research and development expenditures were $150 million, $172 million and $196 million, respectively. A portion of these expenses are related to technical support and customer service and are allocated to the other business segments.

GENERAL

Intellectual Property

We maintain an extensive patent portfolio and continue to file new patent applications in the U.S. and other countries. As of December 31, 2013, we owned approximately 5,000 patents and patent applications worldwide. Our patents and trade secrets cover our processes, products and catalysts and are significant to our competitive position, particularly with regard to PO, intermediate chemicals, petrochemicals, polymers and our process technologies. We own globally registered and unregistered trademarks including the “LyondellBasell,” “Lyondell” and “Equistar” trade names. While we believe that our intellectual property provides competitive advantages, we do not regard our businesses as being materially dependent upon any single patent, trade secret or trademark. Some of our heritage production capacity operates under licenses from third parties.

Environmental

Most of our operations are affected by national, state, regional and local environmental laws. Matters pertaining to the environment are discussed in Part I, Item 1A. Risk Factors; Part I, Item 3. Legal Proceedings; Part II, Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations; and Notes 2 and 19 to the Consolidated Financial Statements.

We have made, and intend to continue to make, the expenditures necessary for compliance with applicable laws and regulations relating to environmental, health and safety matters. We incurred capital expenditures in 2013 for health, safety and environmental compliance purposes and improvement programs of $121 million in 2013, and estimate such expenditures to be approximately $215 million in 2014 and $274 million in 2015.

 

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While capital expenditures or operating costs for environmental compliance, including compliance with potential legislation and potential regulation related to climate change, cannot be predicted with certainty, we do not believe they will have a material effect on our competitive position.

While there can be no assurance that physical risks to our facilities and supply chain due to climate change will not occur in the future, we have reviewed the potential for these risks and have concluded that, because of our facility locations and our existing distribution networks, we do not believe these risks are material in the near term.

Employee Relations

As of December 31, 2013, we employed approximately 13,300 full-time and part-time employees around the world. Of these, approximately 5,900 were in North America, approximately 6,300 were in Europe and approximately 1,100 were in other locations.

As of December 31, 2013, approximately 850 of our employees in North America were represented by labor unions. The vast majority of our employees in Europe and South America are subject to staff council or works council coverage or collective bargaining agreements.

In addition to our own employees, we use the services of contractors in the routine conduct of our businesses.

 

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EXECUTIVE OFFICERS

 

Name and Age*

  

Significant Experience

James L. Gallogly, 61

  

Chairman and Sole Member of the Management Board since April 2010 and Chief Executive Officer since May 2009.

 

Executive Vice President of Exploration and Production for ConocoPhillips from October 2008 to May 2009.

Karyn F. Ovelmen, 50

  

Executive Vice President and Chief Financial Officer since October 2011.

 

Executive Vice President and Chief Financial Officer of Petroplus Holdings AG from 2006 to 2010. (1)

Craig B. Glidden, 56

  

Executive Vice President and Chief Legal Officer since August 2009.

 

Senior Vice President, Legal and Public Affairs, General Counsel and Corporate Secretary of Chevron Phillips Chemical Company from April 2004 to August 2009.

Bhavesh V. (“Bob”) Patel, 47

  

Executive Vice President, Olefins and Polyolefins—EAI and Technology since October 2013.

 

Senior Vice President, Olefins and Polyolefins—EAI and Technology from November 2010 to October 2013.

 

Senior Vice President, Olefins and Polyolefins—Americas from March 2010 to June 2011.

 

General Manager, Olefins and NGLs of Chevron Phillips Chemical Company from 2009 to 2010.

Timothy D. Roberts, 52

  

Executive Vice President, Olefins and Polyolefins—Americas since October 2013.

 

Senior Vice President, Olefins and Polyolefins—Americas from June 2011 to October 2013.

 

Vice President of Planning and Development for Chevron Phillips Chemical from February 2011 to May 2011.

 

President and CEO of Americas Styrenics LLC, a joint venture between the Dow Chemical Company and Chevron Phillips Chemical, from May 2008 to January 2011.

Kevin W. Brown, 56

  

Senior Vice President, Refining since October 2009.

 

Director of Sinclair Oil from January 2006 to September 2009.

 

Executive Vice President, Operations of Sinclair Oil from June 2004 to September 2009.

Massimo Covezzi, 56

   Senior Vice President, Research and Development since January 2008.

 

(1) In January 2012, Petroplus Holdings AG filed an insolvency petition in Switzerland.

 

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Name and Age*

  

Significant Experience

Patrick D. Quarles, 46

  

Senior Vice President, Intermediates & Derivatives since September 2009.

 

Senior Vice President, Propylene Oxide & Derivatives from January 2009 to September 2009.

Karen M. Swindler, 48

  

Senior Vice President, Manufacturing—Americas since November 2009.

 

Director of Performance Improvement from July 2009 to November 2009.

 

Director of North America Polymers Manufacturing from January 2008 to November 2009.

Michael VanDerSnick, 49

  

Senior Vice President, Manufacturing—EAI since July 2012.

 

Site manager of the Company’s Channelview, Matagorda, Chocolate Bayou and Bayport, Texas plants from 2004 to 2012.

Sergey Vasnetsov, 50

  

Senior Vice President, Strategic Planning & Transactions since August 2010.

 

Managing Director of Equity Research at Barclay’s Capital from 1999 to 2010.

Jacquelyn H. Wolf, 52

  

Senior Vice President and Chief Human Resources Officer since September 2012.

 

Senior Vice President and Chief Human Resources Officer for Celanese, Inc. from December 2009 to July 2012.

 

Executive Vice President and Chief Human Resources Officer for Comerica Bank from January 2006 to December 2009.

William B. Allen, Jr., 49

  

Vice President, Finance since February 2013 and Principle Accounting Officer since April 2013.

 

Vice President, Corporate Controller and Chief Accounting Officer of Albemarle Corporation from 2009 to 2013.

 

Chief Financial Officer of Albemarle Corporation’s Catalysts Business Segment from 2007 to 2009 and Fine Chemistry Solutions Business Segment from 2006 to 2007.

Lawrence C. Somma, 47

  

Vice President, Treasurer since October 2013.

 

Senior Vice President Real Estate and Capital Strategy for Hyatt Hotels Corporation from October 2012 to September 2013.

 

Senior Vice President, Treasury for Hyatt Hotels Corporation from July 2008 to September 2012.

Samuel L. Smolik, 60

  

Vice President, Health, Safety, Environmental and Operational Excellence since November 2009.

 

Vice President, Downstream Health, Safety and Environmental of Royal Dutch Shell from 2004 to October 2009.

 

* As of February 17, 2014.

 

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Description of Properties

Our principal manufacturing facilities as of December 31, 2013 are set forth below, and are identified by the principal segment or segments using the facility. All of the facilities are wholly owned, except as otherwise noted.

 

Location

  

Segment

  

Principal Products

Americas

     

Bayport (Pasadena), Texas

   I&D    Ethylene Oxide, Ethylene Glycol and other Ethylene Oxide derivatives

Bayport (Pasadena), Texas(1)

   I&D    PO, PG, PGE, TBA and Isobutylene

Bayport (Pasadena), Texas

   O&P—Americas    PP and Catalloy process resins

Channelview, Texas(2)

   O&P—Americas    Ethylene, Propylene, Butadiene, Benzene and Toluene
   Refining    Alkylate

Channelview, Texas(1)(2)(3)

   I&D    Isopropyl Alcohol, PO, BDO, SM, Isobutylene, Methanol, ETBE and MTBE

Chocolate Bayou, Texas

   O&P—Americas    PE (HDPE)

Clinton, Iowa

   O&P—Americas    Ethylene and Propylene
      PE (LDPE and HDPE)

Corpus Christi, Texas

   O&P—Americas    Ethylene, Propylene, Butadiene and Benzene

Ensenada, Argentina

   O&P—Americas    PP

Ensenada, Argentina

   O&P—EAI    PP compounds

Houston, Texas

   Refining    Gasoline, Diesel, Jet Fuel and Lube Oils

La Porte, Texas(4)

   O&P—Americas    Ethylene and Propylene
PE (LDPE and LLDPE)

La Porte, Texas(4)(5)

   I&D    VAM, acetic acid and methanol

Lake Charles, Louisiana

   O&P—Americas    PP and Catalloy process resins

Matagorda, Texas

   O&P—Americas    PE (HDPE)

Morris, Illinois

   O&P—Americas    PE (LDPE and LLDPE)

Victoria, Texas†

   O&P—Americas    PE (HDPE)

Europe

     

Bayreuth, Germany

   O&P—EAI    PP compounds

Berre l’Etang, France

   O&P—EAI    Ethylene, Propylene, Butadiene, PP and PE (LDPE)

Botlek, Rotterdam, The Netherlands†

   I&D    PO, PG, PGE, TBA, Isobutylene, BDO, MTBE and ETBE

Brindisi, Italy

   O&P—EAI    PP

Ferrara, Italy

   O&P—EAI    PP and Catalloy process resins
   Technology    Polyolefin catalysts

Fos-sur-Mer, France†

   I&D    PO, PG, TBA, MTBE and ETBE

Frankfurt, Germany†

   O&P—EAI    PE (HDPE)
   Technology    Polyolefin catalysts

Knapsack, Germany†

   O&P—EAI    PP and PP compounds

 

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Location

  

Segment

  

Principal Products

Ludwigshafen, Germany†

   Technology    Polyolefin catalysts

Maasvlakte (near Rotterdam), The Netherlands(6)

   I&D    PO and SM

Moerdijk, The Netherlands†

   O&P—EAI    Catalloy process resins and PB-1

Münchsmünster, Germany†

   O&P—EAI    Ethylene, Propylene, PE (HDPE)

    Tarragona, Spain(7)

   O&P—EAI    PP and PP compounds

Wesseling, Germany

   O&P—EAI    Ethylene, Propylene and Butadiene
      PP and PE (HDPE and LDPE)

Asia Pacific

     

Geelong, Australia

   O&P—EAI    PP

 

The facility is located on leased land.
(1) The Bayport PO/TBA plants and the Channelview PO/SM I plant are held by the U.S. PO joint venture between Bayer and Lyondell Chemical. These plants are located on land leased by the U.S. PO joint venture.
(2) Equistar Chemicals, LP operates a styrene maleic anhydride unit and a polybutadiene unit, which are owned by an unrelated party and are located within the Channelview facility on property leased from Equistar Chemicals, LP.
(3) Unrelated equity investors hold a minority interest in the PO/SM II plant at the Channelview facility.
(4) The La Porte facilities are on contiguous property.
(5) The La Porte methanol facility is owned by La Porte Methanol Company, a partnership owned 85% by us.
(6) The Maasvlakte plant is owned by the European PO joint venture and is located on land leased by the European PO joint venture.
(7) The Tarragona PP facility is located on leased land; the compounds facility is located on co-owned land.

Other Locations and Properties

We maintain executive offices in London, The United Kingdom, Rotterdam, The Netherlands and Houston, Texas. We maintain research facilities in Lansing, Michigan; Channelview, Texas; Cincinnati, Ohio; Ferrara, Italy and Frankfurt, Germany. Our Asia Pacific headquarters are in Hong Kong. We also have technical support centers in Bayreuth, Germany; Geelong, Australia; and Tarragona, Spain. We have various sales facilities worldwide.

Website Access to SEC Reports

Our Internet website address is http://www.lyondellbasell.com. Information contained on our Internet website is not part of this report on Form 10-K.

Our Annual Reports on Form 10-K, Quarterly Reports on Form 10-Q, Current Reports on Form 8-K and any amendments to these reports filed or furnished pursuant to Section 13(a) or 15(d) of the Securities Exchange Act of 1934 are available on our website, free of charge, as soon as reasonably practicable after such reports are filed with, or furnished to, the U.S. Securities and Exchange Commission. Alternatively, you may access these reports at the SEC’s website at http://www.sec.gov.

 

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Disclosure pursuant to Section 219 of the Iran Threat Reduction & Syria Human Rights Act

Under the Iran Threat Reduction and Syria Human Rights Act of 2012 (the “Act”), which added Section 13(r) of the Securities Exchange Act of 1934, we are required to include certain disclosures in our periodic reports if we or any of our “affiliates” (as defined in Rule 12b-2 under the Exchange Act) knowingly engage in certain specified activities during the period covered by the report. Neither we nor any of our controlled affiliates or subsidiaries engaged in any of the specified activities during 2013. However, because the SEC defines the term “affiliate” broadly, it includes any entity controlled by us as well as any person or entity that controlled us or is under common control with us (“control” is also construed broadly by the SEC). Apollo Global Management, LLC (“Apollo”) was potentially an affiliate of ours during 2013, as a result of the share ownership of certain investment funds managed by affiliates of Apollo, which owned over 10% of our outstanding shares during 2013, and their right to designate two individuals to our eleven person Supervisory Board up until early August 2013. As of the date of this report, Apollo is not an affiliate of LyondellBasell as no investment funds managed by affiliates of Apollo owned any of our shares and their nomination rights terminated in November 2013.

Apollo informed us that, as of October 24, 2013, certain investment funds managed by Apollo beneficially owned approximately 22% of the limited liability company interests of CEVA Holdings, LLC (“CEVA”). Under the limited liability company agreement governing CEVA, certain investment funds managed by affiliates of Apollo hold a majority of the voting power of CEVA and have the right to elect a majority of the board of CEVA. CEVA may be deemed to be under common control with us, but this statement is not meant to be an admission that common control exists. We have no involvement in or connection with the activities of CEVA or any of its subsidiaries and receive no revenue from them, and have not independently verified or participated in the disclosure provided by Apollo pursuant to the Act. To comply with the Act, we are providing the following disclosure, as provided to us by Apollo:

“Through an internal review of its global operations, CEVA has identified the following transactions in an Initial Notice of Voluntary Self-Disclosure that CEVA filed with the U.S. Treasury Department Office of Foreign Assets Control (“OFAC”) on October 28, 2013. CEVA’s review is ongoing. CEVA will file a further report with OFAC after completing its review.

The internal review indicates that, in December 2012, CEVA Freight Italy Srl (“CEVA Italy”) provided customs brokerage and freight forwarding services for the export to Iran of two measurement instruments to the Iranian Offshore Engineering Construction Company, a joint venture between two entities that are identified on OFAC’s list of Specially Designated Nationals (“SDN”). The revenues and net profits for these services were approximately $1,260.64 USD and $151.30 USD, respectively. In February 2013, CEVA Freight Holdings (Malaysia) SDN BHD (“CEVA Malaysia”) provided customs brokerage for export and local haulage services for a shipment of polyethylene resin to Iran shipped on a vessel owned and/or operated by HDS Lines, also an SDN. The revenues and net profits for these services were approximately $779.54 USD and $311.13 USD, respectively. In September 2013, CEVA Malaysia provided customs brokerage services for the import into Malaysia of fruit juice from Alifard Co. in Iran via HDS Lines. The revenues and net profits for these services were approximately $227.41 USD and $89.29 USD, respectively.

These transactions violate the terms of internal CEVA compliance policies, which prohibit transactions involving Iran. Upon discovering these transactions, CEVA promptly launched an internal investigation, and is taking action to block and prevent such transactions in the future. CEVA intends to cooperate with OFAC in its review of this matter.”

 

Item 1A. Risk Factors.

You should carefully consider the following risk factors in addition to the other information included in this Annual Report on Form 10-K. Each of these risk factors could adversely affect our business, operating results and financial condition, as well as adversely affect the value of an investment in our common stock.

 

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Our business, including our results of operations and reputation, could be adversely affected by safety or product liability issues.

Failure to appropriately manage safety, human health, product liability and environmental risks associated with our products, product life cycles and production processes could adversely impact employees, communities, stakeholders, our reputation and our results of operations. Public perception of the risks associated with our products and production processes could impact product acceptance and influence the regulatory environment in which we operate. While we have procedures and controls to manage safety risks, issues could be created by events outside of our control including natural disasters, severe weather events and acts of sabotage.

Our operations are subject to risks inherent in chemical and refining businesses, and we could be subject to liabilities for which we are not fully insured or that are not otherwise mitigated.

We maintain property, business interruption, product, general liability, casualty and other types of insurance that we believe are in accordance with customary industry practices. However, we are not fully insured against all potential hazards incident to our business, including losses resulting from natural disasters, wars or terrorist acts. Changes in insurance market conditions have caused, and may in the future cause, premiums and deductibles for certain insurance policies to increase substantially and, in some instances, for certain insurance to become unavailable or available only for reduced amounts of coverage. If we were to incur a significant liability for which we were not fully insured, we might not be able to finance the amount of the uninsured liability on terms acceptable to us or at all, and might be obligated to divert a significant portion of our cash flow from normal business operations.

Further, because a part of our business involves licensing polyolefin process technology, our licensees are exposed to similar risks involved in the manufacture and marketing of polyolefins. Hazardous incidents involving our licensees, if they do result or are perceived to result from use of our technologies, may harm our reputation, threaten our relationships with other licensees and/or lead to customer attrition and financial losses. Our policy of covering these risks through contractual limitations of liability and indemnities and through insurance may not always be effective. As a result, our financial condition and results of operation would be adversely affected, and other companies with competing technologies may have the opportunity to secure a competitive advantage.

Our ability to source raw materials, including crude oil, may be adversely affected by political instability, civil disturbances or other governmental actions.

We obtain a substantial portion of our principal raw materials from sources in North Africa, the Middle East, Mexico and South America that may be less politically stable than other areas in which we conduct business, such as Europe or the U.S. Political instability, civil disturbances and actions by governments in these areas are likely to substantially increase the price and decrease the supply of raw materials necessary for our operations, which will have a material adverse effect on our results of operations.

Recently, increased incidents of civil unrest, including terrorist attacks and demonstrations which have been marked by violence, have occurred in some countries in North Africa and the Middle East. Some political regimes in these countries are threatened or have changed as a result of such unrest. Political instability and civil unrest could continue to spread in the region and involve other areas. Such unrest, if it continues to spread or grow in intensity, could lead to civil wars, regional conflict, or regime changes resulting in governments that are hostile to countries in which we conduct substantial business, such as Europe, the U.S., or their respective allies.

Costs and limitations on supply of raw materials and energy may result in increased operating expenses.

The costs of raw materials and energy represent a substantial portion of our operating expenses. Energy costs generally follow price trends of crude oil and natural gas. These price trends may be highly volatile and cyclical. In the past, raw material and energy costs have experienced significant fluctuations that adversely

 

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affected our business segments’ results of operations. For example, we continue to benefit from the favorable ratio of U.S. natural gas prices to crude oil prices. However, if the price of crude oil decreases relative to U.S. natural gas prices or if the demand for natural gas and NGLs increases, this may have a negative result on our results of operations. Additionally, the export of NGLs from the U.S.; greater restrictions on hydraulic fracturing or the lifting by the U.S. government of the ban on U.S. crude oil exports could restrict the availability of our raw materials thereby increasing our costs.

We are not always able to pass raw material and energy cost increases on to our customers. When we do have the ability to pass on the cost increases, we are not always able to do so quickly enough to avoid adverse impacts on our results of operations.

Cost increases for raw materials also may increase working capital needs, which could reduce our liquidity and cash flow. Even if we increase our sales prices to reflect rising raw material and energy costs, demand for products may decrease as customers reduce their consumption or use substitute products, which may have an adverse impact on our results of operations. In addition, producers in natural gas cost-advantaged regions, such as the Middle East and North America, benefit from the lower prices of natural gas and NGLs. Competition from producers in these regions may cause us to reduce exports from Europe and elsewhere. Any such reductions may increase competition for product sales within Europe and other markets, which can result in lower margins in those regions. Additionally, there are a limited number of suppliers for some of our raw materials and utilities and, in some cases, the supplies are specific to the particular geographic region in which a facility is located.

It is also common in the chemical and refining industries for a facility to have a sole, dedicated source for its utilities, such as steam, electricity and gas. Having a sole or limited number of suppliers may limit our negotiating power, particularly in the case of rising raw material costs. Any new supply agreements we enter into may not have terms as favorable as those contained in our current supply agreements.

Additionally, there is growing concern over the reliability of water sources, including around the Texas Gulf Coast where several of our facilities are located. The decreased availability or less favorable pricing for water as a result of population growth, drought or regulation could negatively impact our operations.

If our raw material or utility supplies were disrupted, our businesses may incur increased costs to procure alternative supplies or incur excessive downtime, which would have a direct negative impact on plant operations. Disruptions of supplies may occur as a result of transportation issues including, but not limited to, as a result of natural disasters and water levels that can affect the ability of vessels, barges, rails, trucks and pipeline traffic. These risks are particularly prevalent in the U.S. Gulf Coast area.

With increased volatility in raw material costs, our suppliers could impose more onerous terms on us, resulting in shorter payment cycles and increasing our working capital requirements.

Economic disruptions and downturns in general, and particularly continued economic uncertainty in Europe or economic turmoil in emerging markets, could have a material adverse effect on our business, prospects, operating results, financial condition and cash flows.

Our results of operations can be materially affected by adverse conditions in the financial markets and depressed economic conditions generally. Economic downturns in the businesses and geographic areas in which we sell our products substantially reduce demand for our products and result in decreased sales volumes and increased credit risk. Recessionary environments adversely affect our business because demand for our products is reduced, particularly from our customers in industrial markets generally and the automotive and housing industries specifically, and may result in higher costs of capital. The recent European economic crisis resulted in reduced consumer confidence and spending in many countries in Europe, particularly southern Europe. A significant portion of our revenues and earnings are derived from our business in Europe, including southern Europe. In addition, most of our European transactions and assets, including cash reserves and receivables, are denominated in euros.

 

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Europe’s recovery from the economic crisis has been uneven, slow and modest. If the crisis re-emerges or meaningful recovery does not materialize across Europe, there will likely be a continued negative effect on our European business, as well as the businesses of our European customers, suppliers and partners. In addition, if the crisis ultimately led to the break-up of the European economic and monetary union or a significant devaluation of the euro, the value of our financial assets that are denominated in euros would be significantly reduced when translated to U.S. dollars for financial reporting purposes. We also derive significant revenues from our business in emerging markets, particularly the emerging markets in Asia and Brazil. Any broad-based downturn in these emerging markets, or in a key market such as China, could require us to reduce export volumes into these markets and could also require us to divert product sales to less profitable markets. Any of these conditions could ultimately harm our overall business, prospects, operating results, financial condition and cash flows.

The cyclicality and volatility of the industries in which we participate may cause significant fluctuations in our operating results.

Our business operations are subject to the cyclical and volatile nature of the supply-demand balance in the chemical and refining industries. Our future operating results are expected to continue to be affected by this cyclicality and volatility. The chemical and refining industries historically have experienced alternating periods of capacity shortages, causing prices and profit margins to increase, followed by periods of excess capacity, resulting in oversupply, declining capacity utilization rates and declining prices and profit margins.

In addition to changes in the supply and demand for products, changes in energy prices and other worldwide economic conditions can cause volatility. These factors result in significant fluctuations in profits and cash flow from period to period and over business cycles.

New capacity additions in Asia, the Middle East and North America may lead to periods of oversupply and lower profitability. A sizable number of expansions have been announced in North America. The timing and extent of any changes to currently prevailing market conditions are uncertain and supply and demand may be unbalanced at any time. As a consequence, we are unable to accurately predict the extent or duration of future industry cycles or their effect on our business, financial condition or results of operations.

We sell products in highly competitive global markets and face significant price pressures.

We sell our products in highly competitive global markets. Due to the commodity nature of many of our products, competition in these markets is based primarily on price and, to a lesser extent, on product performance, product quality, product deliverability, reliability of supply and customer service. Generally, we are not able to protect our market position for these products by product differentiation and may not be able to pass on cost increases to our customers.

In addition, we face increased competition from companies that may have greater financial resources and different cost structures or strategic goals than us. These include large integrated oil companies (some of which also have chemical businesses), government-owned businesses, and companies that receive subsidies or other government incentives to produce certain products in a specified geographic region. Increased competition from these companies, especially in our olefin and refining businesses, could limit our ability to increase product sales prices in response to raw material and other cost increases, or could cause us to reduce product sales prices to compete effectively, which could reduce our profitability. Competitors that have greater financial resources than us may be able to invest significant capital into their businesses, including expenditures for research and development.

In addition, specialty products we produce may become commoditized over time. Increased competition could result in lower prices or lower sales volumes, which would have a negative impact on our results of operations.

 

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Interruptions of operations at our facilities may result in liabilities or lower operating results.

We own and operate large-scale facilities. Our operating results are dependent on the continued operation of our various production facilities and the ability to complete construction and maintenance projects on schedule. Interruptions at our facilities may materially reduce the productivity and profitability of a particular manufacturing facility, or our business as a whole, during and after the period of such operational difficulties. In the past, we had to shut down plants on the U.S. Gulf Coast, including the temporary shutdown of our Houston refinery, as a result of hurricanes striking the Texas coast.

In addition, because the Houston refinery is our only refining operation, an outage at the refinery could have a particularly negative impact on our operating results. Unlike our chemical and polymer production facilities, which may have sufficient excess capacity to mitigate the negative impact of lost production at other facilities, we do not have the ability to increase refining production elsewhere in the U.S.

Although we take precautions to enhance the safety of our operations and minimize the risk of disruptions, our operations are subject to hazards inherent in chemical manufacturing and refining and the related storage and transportation of raw materials, products and wastes. These potential hazards include:

 

   

pipeline leaks and ruptures;

 

   

explosions;

 

   

fires;

 

   

severe weather and natural disasters;

 

   

mechanical failure;

 

   

unscheduled downtimes;

 

   

supplier disruptions;

 

   

labor shortages or other labor difficulties;

 

   

transportation interruptions;

 

   

increased restrictions on, or the unavailability of, water for use at our manufacturing sites or for the transport of our products or raw materials;

 

   

remediation complications;

 

   

chemical and oil spills;

 

   

discharges or releases of toxic or hazardous substances or gases;

 

   

shipment of incorrect or off-specification product to customers;

 

   

storage tank leaks;

 

   

other environmental risks; and

 

   

terrorist acts.

Some of these hazards may cause severe damage to or destruction of property and equipment or personal injury and loss of life and may result in suspension of operations or the shutdown of affected facilities.

Increased IT security threats and more sophisticated and targeted computer crime could pose a risk to our systems, networks, products, facilities and services.

Increased global information security threats and more sophisticated, targeted computer crime pose a risk to the confidentiality, availability and integrity of our data, operations and infrastructure. While we attempt to mitigate these risks by employing a number of measures, including employee training, comprehensive

 

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monitoring of our networks and systems, and maintenance of backup and protective systems, our employees, systems, networks, products, facilities and services remain potentially vulnerable to sophisticated espionage or continual cyber-assault. Depending on their nature and scope, such threats could potentially lead to the compromise of confidential information, improper use of our systems and networks, manipulation and destruction of data, defective products, production downtimes and operational disruptions, which in turn could adversely affect our reputation, competitiveness and results of operations.

We operate internationally and are subject to exchange rate fluctuations, exchange controls, political risks and other risks relating to international operations.

We operate internationally and are subject to the risks of doing business on a global level. These risks include fluctuations in currency exchange rates, economic instability and disruptions, restrictions on the transfer of funds and the imposition of duties and tariffs. Additional risks from our multinational business include transportation delays and interruptions, war, terrorist activities, epidemics, pandemics, political instability, import and export controls, changes in governmental policies, labor unrest and current and changing regulatory environments.

We generate revenues from export sales and operations that may be denominated in currencies other than the relevant functional currency. Exchange rates between these currencies and functional currencies in recent years have fluctuated significantly and may do so in the future. We also could hedge certain revenues and costs using derivative instruments to minimize the impact of changes in the exchange rates of those currencies compared to the respective functional currencies. It is possible that fluctuations in exchange rates will result in reduced operating results. Additionally, we operate with the objective of having our worldwide cash available in the locations where it is needed, including The United Kingdom for our parent company’s significant cash obligations as a result of dividend and interest payments. It is possible that we may not always be able to provide cash to other jurisdictions when needed or that such transfers of cash could be subject to additional taxes, including withholding taxes.

Our operating results could be negatively affected by the global laws, rules and regulations, as well as political environments in the jurisdictions in which we operate. There could be reduced demand for our products, decreases in the prices at which we can sell our products and disruptions of production or other operations. Additionally, there may be substantial capital and other costs to comply with regulations and/or increased security costs or insurance premiums, any of which could reduce our operating results.

We obtain a substantial portion of our principal raw materials from international sources that are subject to these same risks. Our compliance with applicable customs, currency exchange control regulations, transfer pricing regulations or any other laws or regulations to which we may be subject could be challenged. Furthermore, these laws may be modified, the result of which may be to prevent or limit subsidiaries from transferring cash to us.

Furthermore, we are subject to certain existing, and may be subject to possible future, laws that limit or may limit our activities while some of our competitors may not be subject to such laws, which may adversely affect our competitiveness.

Many of our businesses depend on our intellectual property. Our future success will depend in part on our ability to protect our intellectual property rights, and our inability to do so could reduce our ability to maintain our competitiveness and margins.

We have a significant worldwide patent portfolio of issued and pending patents. These patents, together with proprietary technical know-how, are significant to our competitive position, particularly with regard to propylene oxide, performance chemicals, petrochemicals, and polymers, including process technologies such as Spheripol, Spherizone, Hostalen, Spherilene, Lupotech T and Avant catalyst family technology rights. We rely on the patent, copyright and trade secret laws of the countries in which we operate to protect our investment in research

 

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and development, manufacturing and marketing. However, we may be unable to prevent third parties from using our intellectual property without authorization. Proceedings to protect these rights could be costly, and we may not prevail.

The protection afforded by patents varies from country to country and depends upon the type of patent and its scope of coverage. While a presumption of validity exists with respect to patents issued to us, our patents may be challenged, invalidated, circumvented or rendered unenforceable. As patents expire, the products and processes described and claimed under those patents become generally available for use by competitors.

Our continued growth strategy may bring us to regions of the world where intellectual property protection may be limited and difficult to enforce. In addition, patent rights may not prevent our competitors from developing, using or selling products that are similar or functionally equivalent to our products. Moreover, our competitors or other third parties may obtain patents that restrict or preclude our ability to lawfully produce or sell our products in a competitive manner, which could result in significantly lower revenues, reduced profit margins or loss of market share.

We also rely upon unpatented proprietary know-how and continuing technological innovation and other trade secrets to develop and maintain our competitive position. While it is our policy to enter into confidentiality agreements with our employees and third parties to protect our intellectual property, these confidentiality agreements may be breached, may not always be executed, may not provide meaningful protection or adequate remedies may not be available. Additionally, others could obtain knowledge of our trade secrets through independent development or other access by legal or illegal means.

The failure of our patents or confidentiality agreements to protect our processes, apparatuses, technology, trade secrets or proprietary know-how could result in significantly lower revenues, reduced profit margins and cash flows and/or loss of market share. We also may be subject to claims that our technology, patents or other intellectual property infringes on a third party’s intellectual property rights. Unfavorable resolution of these claims could result in restrictions on our ability to deliver the related service or in a settlement that could be material to us.

Shared control or lack of control of joint ventures may delay decisions or actions regarding the joint ventures.

A portion of our operations are conducted through joint ventures, where control may be exercised by or shared with unaffiliated third parties. We cannot control the actions of our joint venture partners, including any nonperformance, default or bankruptcy of joint venture partners. The joint ventures that we do not control may also lack adequate internal controls systems or financial reporting systems to provide adequate and timely information for our reporting purposes.

In the event that any of our joint venture partners do not observe their obligations, it is possible that the affected joint venture would not be able to operate in accordance with our business plans. As a result, we could be required to increase our level of commitment in order to give effect to such plans. Differences in views among the joint venture participants also may result in delayed decisions or in failures to agree on major matters, potentially adversely affecting the business and operations of the joint ventures and in turn our business and operations.

We cannot predict with certainty the extent of future costs under environmental, health and safety and other laws and regulations, and cannot guarantee they will not be material.

We may face liability arising out of the normal course of business, including alleged personal injury or property damage due to exposure to chemicals or other hazardous substances at our current or former facilities or chemicals that we manufacture, handle or own. In addition, because our products are components of a variety of

 

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other end-use products, we, along with other members of the chemical industry, are subject to potential claims related to those end-use products. Any substantial increase in the success of these types of claims could negatively affect our operating results.

We (together with the industries in which we operate) are subject to extensive national, regional, state and local environmental laws, regulations, directives, rules and ordinances concerning

 

   

emissions to the air;

 

   

discharges onto land or surface waters or into groundwater; and

 

   

the generation, handling, storage, transportation, treatment, disposal and remediation of hazardous substances and waste materials.

Many of these laws and regulations provide for substantial fines and potential criminal sanctions for violations. Some of these laws and regulations are subject to varying and conflicting interpretations. In addition, some of these laws and regulations require us to meet specific financial responsibility requirements. Any substantial liability for environmental damage could have a material adverse effect on our financial condition, results of operations and cash flows.

Although we have compliance programs and other processes intended to ensure compliance with all such regulations, we are subject to the risk that our compliance with such regulations could be challenged. Non-compliance with certain of these regulations could result in the incurrence of additional costs, penalties or assessments that could be material.

Our industry is subject to extensive government regulation, and existing, or future regulations may restrict our operations, increase our costs of operations or require us to make additional capital expenditures.

Compliance with regulatory requirements could result in higher operating costs, such as regulatory requirements relating to emissions, the security of our facilities, and the transportation, export or registration of our products. We generally expect that regulatory controls worldwide will become increasingly more demanding, but cannot accurately predict future developments.

Increasingly strict environmental laws and inspection and enforcement policies, could affect the handling, manufacture, use, emission or disposal of products, other materials or hazardous and non-hazardous waste. Stricter environmental, safety and health laws, regulations and enforcement policies could result in increased operating costs or capital expenditures to comply with such laws and regulations. Additionally, we are required to have permits for our businesses and are subject to licensing regulations. These permits and licenses are subject to renewal, modification and in some circumstances, revocation. Further, the permits and licenses are often difficult, time consuming and costly to obtain and could contain conditions that limit our operations.

We have learned that the European Commission has opened an investigation into Germany’s Renewable Energy Law (as amended in 2012) to examine whether the reduction granted to energy-intensive companies on a surcharge for the financing of renewable energy sources in Germany is compatible with EU state aid rules. If and to the extent that the German government were to attempt to recover the reductions previously granted to our German subsidiaries or otherwise curtail the availability of such reductions in the future, the results of our O&P-EAI operations would be negatively impacted.

We may incur substantial costs to comply with climate change legislation and regulatory initiatives.

There has been a broad range of proposed or promulgated state, national and international laws focusing on greenhouse gas (“GHG”) reduction. These proposed or promulgated laws apply or could apply in countries where we have interests or may have interests in the future. Laws in this field continue to evolve and, while they are likely to be increasingly widespread and stringent, at this stage it is not possible to accurately estimate either

 

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a timetable for implementation or our future compliance costs relating to implementation. Within the framework of the EU emissions trading scheme (“ETS”) we were allocated certain allowances of carbon dioxide for the affected plants of our European sites for the period 2008 to 2012 (“ETS II period”). The ETS II period did not bring additional cost to us as the allowance allocation was sufficient to cover the actual emissions of the affected plants. We were able to build an allowance surplus during the ETS II period which has been banked to the scheme for the period 2013 to 2020 (“ETS III period”). We expect to incur additional costs for the ETS III period, despite the allowance surplus accrued over the ETS II period, as allowance allocations have been reduced for the ETS III period and more of our plants are affected by the scheme. We maintain an active hedging strategy to cover these additional costs. We expect to incur additional costs in relation to future carbon or greenhouse gas emission trading schemes.

In the U.S., the Environmental Protection Agency (the “EPA”) has promulgated federal GHG regulations under the Clean Air Act affecting certain sources. The EPA has issued mandatory GHG reporting requirements, requirements to obtain GHG permits for certain industrial plants and proposals for GHG performance standards for some facilities. The recent EPA action could be a precursor to further federal regulation of carbon dioxide emissions and other greenhouse gases, and may affect the outcome of other climate change lawsuits pending in U.S. courts in a manner unfavorable to our industry. In any event, additional regulation may be forthcoming at the U.S. federal or state level with respect to GHG emissions, and such regulation could result in the creation of additional costs in the form of taxes or required acquisition or trading of emission allowances.

Compliance with these or other changes in laws, regulations and obligations that create a GHG emissions trading scheme or GHG reduction policies generally could significantly increase our costs or reduce demand for products we produce. Additionally, compliance with these regulations may result in increased permitting necessary for the operation of our business or for any of our growth plans. Difficulties in obtaining such permits could have an adverse effect on our future growth. Therefore, any future potential regulations and legislation could result in increased compliance costs, additional operating restrictions or delays in implementing growth projects or other capital investments, and could have a material adverse effect on our business and results of operations.

We may be required to record material charges against our earnings due to any number of events that could cause impairments to our assets.

We may be required to reduce production at or idle facilities for extended periods of time or exit certain businesses as a result of the cyclical nature of our industry. Specifically, oversupplies of or lack of demand for particular products or high raw material prices may cause us to reduce production. We may choose to reduce production at certain facilities because we have off-take arrangements at other facilities, which make any reductions or idling unavailable at those facilities. Any decision to permanently close facilities or exit a business likely would result in impairment and other charges to earnings.

Temporary outages at our facilities can last for several quarters and sometimes longer. These outages could cause us to incur significant costs, including the expenses of maintaining and restarting these facilities. In addition, even though we may reduce production at facilities, we may be required to continue to purchase or pay for utilities or raw materials under take-or-pay supply agreements.

Our business is capital intensive and we rely on cash generated from operations and external financing to fund our growth and ongoing capital needs. Limitations on access to external financing could adversely affect our operating results.

We require significant capital to operate our current business and fund our growth strategy. Moreover, interest payments, dividends and the expansion of our business or other business opportunities may require significant amounts of capital. We believe that our cash from operations currently will be sufficient to meet these needs. However, if we need external financing, our access to credit markets and pricing of our capital is

 

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dependent upon maintaining sufficient credit ratings from credit rating agencies and the state of the capital markets generally. There can be no assurances that we would be able to incur indebtedness on terms we deem acceptable, and it is possible that the cost of any financings could increase significantly, thereby increasing our expenses and decreasing our net income. If we are unable to generate sufficient cash flow or raise adequate external financing, including as a result of significant disruptions in the global credit markets, we could be forced to restrict our operations and growth opportunities, which could adversely affect our operating results.

We may use our five-year, $2 billion revolving credit facility to meet our cash needs, to the extent available. As of December 31, 2013, we had no borrowings or letters of credit outstanding under the facility, leaving an unused and available credit capacity of $2,000 million. We may also meet our cash needs by selling receivables under our $1,000 million U.S. accounts receivable securitization facility or our €450 million European accounts receivable securitization facility. In the event of a default under our credit facility or any of our senior notes, we could be required to immediately repay all outstanding borrowings and make cash deposits as collateral for all obligations the facility supports, which we may not be able to do. Any default under any of our credit arrangements could cause a default under many of our other credit agreements and debt instruments. Without waivers from lenders party to those agreements, any such default could have a material adverse effect on our ability to continue to operate.

Legislation and regulatory initiatives could lead to a decrease in demand for our products.

New or revised governmental regulations and independent studies relating to the effect of our products on health, safety and the environment may affect demand for our products and the cost of producing our products. Initiatives by governments and private interest groups will potentially require increased toxicological testing and risk assessments of a wide variety of chemicals, including chemicals used or produced by us. For example, in the United States, the National Toxicology Program (“NTP”) is a federal interagency program that seeks to identify and select for study chemicals and other substances to evaluate potential human health hazards. In the European Union, the Regulation on Registration, Evaluation, Authorisation and Restriction of Chemicals (“REACH”) is regulation designed to identify the intrinsic properties of chemical substances, assess hazards and risks of the substances, and identify and implement the risk management measures to protect humans and the environment.

Assessments under NTP, REACH or similar programs or regulations in other jurisdictions may result in heightened concerns about the chemicals we use or produce and may result in additional requirements being placed on the production, handling, labeling or use of those chemicals. Such concerns and additional requirements could also increase the cost incurred by our customers to use our chemical products and otherwise limit the use of these products, which could lead to a decrease in demand for these products. Such a decrease in demand could have an adverse impact on our business and results of operations.

Our success depends upon our ability to attract and retain key employees and the identification and development of talent to succeed senior management.

Our success depends on our ability to attract and retain key personnel, and we rely heavily on our management team. The inability to recruit and retain key personnel or the unexpected loss of key personnel may adversely affect our operations. In addition, because of the reliance on our management team, our future success depends in part on our ability to identify and develop talent to succeed senior management. The retention of key personnel and appropriate senior management succession planning will continue to be critically important to the successful implementation of our strategies.

We may not be able to fully or successfully implement our ongoing plans to improve and globally integrate our business processes and functions.

We continue to seek ways to drive greater productivity, flexibility and cost savings. In particular, we are working towards the improvement and global integration of our business processes and functions. As part of these efforts, we have been centralizing certain functions, implementing new information technology, and integrating our existing information technology systems.

 

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Our ongoing implementation of organizational improvements is made more difficult by our need to coordinate geographically dispersed operations. Inabilities and delays in implementing improvements can negatively affect our ability to realize projected or expected cost savings. In addition, the process of organizational improvements may cause interruptions of, or loss of momentum in, the activities of our businesses. It may also result in the loss of personnel or other labor issues. These issues, as well as any information technology systems failures, also could impede our ability to timely collect and report financial results in accordance with applicable laws and regulations.

Additionally, from time to time certain aspects of our business processes may be outsourced to third parties. The processes, or the portions thereof, that are outsourced generally will tend to be labor intensive transactional activities. Although we make a diligent effort to ensure that all providers of outsourced services observe proper internal control practices and procedures, we cannot assure that failures will not occur. The failure of such third parties to provide adequate services could adversely affect our results of operations, liquidity, or our ability to provide adequate financial and management reporting.

Significant changes in pension fund investment performance or assumptions relating to pension costs may adversely affect the valuation of pension obligations, the funded status of pension plans, and our pension cost.

Our pension cost is materially affected by the discount rate used to measure pension obligations, the level of plan assets available to fund those obligations at the measurement date and the expected long-term rate of return on plan assets. Significant changes in investment performance or a change in the portfolio mix of invested assets may result in corresponding increases and decreases in the value of plan assets, particularly equity securities, or in a change of the expected rate of return on plan assets. Any change in key actuarial assumptions, such as the discount rate, would impact the valuation of pension obligations, affecting the reported funded status of our pension plans as well as the net periodic pension cost in the following fiscal years.

Certain of our current pension plans could have projected benefit obligations that exceed the fair value of the plan assets. As of December 31, 2013, the aggregate deficit was $668 million. Any declines in the fair values of the pension plans assets could require additional payments by us in order to maintain specified funding levels.

Our pension plans are subject to legislative and regulatory requirements of applicable jurisdictions, which could include, under certain circumstances, local governmental authority to terminate the plan.

Our operations could be adversely affected by labor relations.

The vast majority of our employees located in Europe and South America are represented by labor unions and works councils. Approximately 850 of our employees located in North America are represented by labor unions.

Our operations have been in the past, and may be in the future, significantly and adversely affected by strikes, work stoppages and other labor disputes.

 

Item 1B. Unresolved Staff Comments.

None.

 

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Item 3. Legal Proceedings.

Environmental Matters

From time to time we and our joint ventures receive notices or inquiries from federal, state or local governmental entities regarding alleged violations of environmental laws and regulations pertaining to, among other things, the disposal, emission and storage of chemical and petroleum substances, including hazardous wastes. Item 103 of the SEC’s Regulation S-K requires disclosure of certain environmental matters when a governmental authority is a party to the proceedings and the proceedings involve potential monetary sanctions that we reasonably believe could exceed $100,000. The matters below are disclosed solely pursuant to that requirement.

In September 2012, Harris County, Texas filed a lawsuit against our subsidiary, Equistar Chemicals, LP, in Harris County District Court in connection with four emissions events between September 2011 and March 2012 at our manufacturing plant in Channelview, Texas. The complaint alleges a maximum penalty of $200,000.

In September 2013, the Louisiana Department of Environmental Quality (the “LDEQ”) issued a Compliance Order and Notice of Potential Penalty to Equistar Chemicals, LP pertaining to self-reported deviations arising from our polyolefins plant and relating to certain Clean Air Act Title V permit conditions, limits and other requirements. The matter involves deviations reported by us to the LDEQ in semi-annual reports covering 2007 through June 2011. We reasonably believe that LDEQ may assert an administrative penalty demand in this matter in excess of $100,000.

In September 2013, EPA Region V issued a Notice and Finding of Violation alleging violations at our Morris, Illinois facility related to flaring activity. Specifically, the Notice generally alleges failures to monitor steam usage and improper flare operations. While a penalty demand is expected, the Notice did not contain any such demand, although we reasonably believe that EPA Region V may assert a penalty demand in excess of $100,000.

In September 2013, the EPA Region VII sent our Clinton, Iowa facility notice that it intended to proceed with the filing of an administrative complaint seeking penalties of approximately $191,000, related to alleged violations of the Resources Conservation and Recovery Act (“RCRA”) for inadequate secondary containment of hazardous waste container storage areas. In January 2014, we entered into a Consent Agreement and Final Order pursuant to which we agreed to pay a civil penalty of approximately $27,000.

Litigation and Other Matters

Information regarding our litigation and other legal proceedings can be found in Note 19, Commitments and Contingencies, to the Consolidated Financial Statements.

 

Item 4. Mine Safety Disclosures.

Not applicable.

 

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PART II

 

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

Market and Dividend Information

Our shares were listed on the NYSE on October 14, 2010 under the symbol “LYB.” The high and low sales prices for our ordinary shares and the cash dividends per share declared for the two most recent fiscal years are shown in the table below.

 

     High      Low      Cash Dividends
Declared
 

2013

        

First Quarter

   $ 65.69      $ 55.94      $ 0.40  

Second Quarter

     69.45        55.02        0.50  

Third Quarter

     75.67        64.74        0.50  

Fourth Quarter

     80.33        72.27        0.60  

2012

        

First Quarter

   $ 46.39      $ 33.11      $ 0.25  

Second Quarter

     46.13        35.97        0.40  

Third Quarter

     53.77        38.44        0.40  

Fourth Quarter

     57.16        44.87        3.15 (a)

 

(a) Includes a special dividend of $2.75 that was paid on December 11, 2012 to shareholders of record on November 19, 2012.

The payment of dividends or distributions in the future will be subject to the requirements of Dutch law and the discretion of our shareholders (in the case of annual dividends), our Management Board and Supervisory Board. The declaration of any future cash dividends and, if declared, the amount of any such dividends, will depend upon general business conditions, our financial condition, our earnings and cash flow, our capital requirements, financial covenants and other contractual restrictions on the payment of dividends or distributions.

There can be no assurance that any dividends or distributions will be declared or paid in the future.

Holders

As of February 18, 2014, there were approximately 5,200 record holders of our shares, including Cede & Co. as nominee of the Depository Trust Company.

United Kingdom Tax Considerations

In May 2013, we announced the planned migration of the tax domicile of LyondellBasell Industries N.V. from The Netherlands, where LyondellBasell Industries N.V. is incorporated, to the United Kingdom. On August 28, 2013, the Dutch and the United Kingdom competent authorities completed a mutual agreement procedure and issued a ruling that retroactively as of July 1, 2013 LyondellBasell Industries N.V. should be treated solely as a tax resident in the United Kingdom and is subject to the United Kingdom corporate income tax system.

As a result of its United Kingdom tax status, dividend distributions by LyondellBasell Industries N.V. to its shareholders are not subject to withholding tax, as the United Kingdom currently does not levy a withholding tax on dividend distributions.

 

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Performance Graph

The graph below shows the relative investment performance of LyondellBasell Industries N.V. shares, the S&P 500 Index and the S&P 500 Chemicals Index since April 30, 2010, the first date on which we had issued capital as a publicly traded company. The graph assumes that $100 was invested on April 30, 2010 and any dividends paid were reinvested at the date of payment. The graph is presented pursuant to SEC rules and is not meant to be an indication of our future performance.

 

LOGO

 

    4/30/2010   6/30/2010   12/31/2010   6/30/2011   12/31/2011   6/30/2012   12/31/2012   6/30/2013   12/31/2013

LyondellBasell Industries N.V.

  $100   $72.42   $154.26   $173.13   $168.22   $211.83   $321.94   $379.02   $465.95

S&P 500 Index

  $100   $87.20   $107.49   $113.96   $109.76   $120.17   $127.32   $144.92   $168.56

S&P 500 Chemicals Index

  $100   $83.42   $117.58   $128.20   $116.10   $132.96   $143.51   $155.27   $189.15

 

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Issuer Purchases of Equity Securities

 

Period

   Total Number
of Shares
Purchased(1)
     Average Price
Paid per Share
     Total Number of
Shares Purchased
as Part of Publicly
Announced Plans
or Programs
     Maximum Number (or
Approximate Dollar Value)
of Shares That May Yet

Be Purchased Under the
Plans or Programs
 

October 1 – October 31

     4,938,458      $ 75.75        4,938,458        33,749,679  

November 1 – November 30

     3,531,961      $ 77.19        3,524,443        30,225,236  

December 1 – December 31

     —          —          —          30,225,236  

Total

     8,470,419      $ 76.35        8,462,901        30,225,236  

 

(1) In addition to shares purchased pursuant to our publicly announced program described below, the total number of shares purchased includes 7,518 shares withheld to satisfy withholding tax obligations upon the vesting of employee restricted stock. The average price for the shares withheld in satisfaction of employee withholding taxes was $75.17. The average price for the shares repurchased pursuant to the publicly announced program includes commissions.
(2) On May 22, 2013, we announced a share repurchase program of up to 57,584,238 of our ordinary shares through May 21, 2014. The maximum number of shares that may yet be purchased is not necessarily an indication of the number of shares that will ultimately be purchased.

 

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Item 6. Selected Financial Data.

See Management’s Discussion and Analysis of Financial Condition and Results of Operations for a discussion of factors that will enhance an understanding of this data.

The following selected financial data of the Company and its predecessor, LyondellBasell Industries AF S.C.A. (“LyondellBasell AF”), should be read in conjunction with the Consolidated Financial Statements and related notes thereto and “Management’s Discussion and Analysis of Financial Condition and Results of Operations,” below. The selected financial data of the Company and the Predecessor were derived from their consolidated financial statements. Those financial statements were prepared from the books and records of LyondellBasell AF for periods through April 30, 2010 and of the Company upon emergence from bankruptcy after that date. As discussed elsewhere in this annual report on Form 10-K, we became the successor parent holding company of the subsidiaries of LyondellBasell AF and the reporting entity upon completion of the bankruptcy proceedings. Financial information is reported for the Company as the successor on a basis different from financial information of the predecessor, LyondellBasell AF. As a result of the application of fresh-start accounting and restructuring activities pursuant to the Plan of Reorganization, the Successor period is not comparable to the Predecessor period.

 

    Successor          Predecessor  
    Year Ended
December 31,
    May 1
through
December 31,
         January 1
through
April 30,
    Year Ended
December 31,
 
In millions of dollars, except per share data   2013     2012     2011     2010          2010     2009  

Results of operations data:

               

Sales and other operating revenues

  $ 44,062     $ 45,352     $ 48,183     $ 26,132         $ 12,807     $ 29,008  

Operating income

    5,102       4,676       4,337       2,292           704       487  

Interest expense(a)

    (309     (655     (1,044     (539         (711     (1,794

Income (loss) from equity investments(b)

    203       143       216       86           84       (181

Income (loss) from continuing operations(c)

    3,860       2,858       2,472       1,561           8,262       (2,685

Earnings per share from continuing operations:

               

Basic

    6.81       5.01       4.34       2.76          

Diluted

    6.76       4.96       4.32       2.75          

Income (loss) from discontinued operations, net of tax

    (7     (24     (332     19           242       (186

Earnings (loss) per share from discontinued operations:

               

Basic

    (0.01     (0.04     (0.58     0.03          

Diluted

    (0.01     (0.04     (0.58     0.03          

Balance sheet data:

               

Total assets

    27,298       24,220       22,839       25,302             27,761  

Short-term debt

    58       95       48       42             6,182  

Long-term debt(d)

    5,777       4,305       3,984       6,040             802  

Cash and cash equivalents

    4,450       2,732       1,065       4,222             558  

Accounts receivable

    4,030       3,904       3,778       3,747             3,287  

Inventories

    5,279       5,075       5,499       4,824             3,277  

Working capital

    5,737       5,694       5,863       5,810             4,436  

Liabilities subject to compromise

    —         —         —         —               22,494  

Cash flow data:

               

Cash provided by (used in):

               

Operating activities

    4,835       4,787       2,860       2,968           (925     (787

Investing activities

    (1,602     (1,013     (1,021     (323         (224     (611

Expenditures for property, plant and equipment

    (1,561     (1,060     (1,050     (466         (226     (779

Financing activities

    (1,589     (2,145     (4,955     (1,194         3,315       1,101  

Dividends declared per share

    2.00       4.20       5.05            

 

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(a) Interest expense in 2012 includes charges of $294 million for premiums related to the refinancing of notes bearing interest rates of 8% and 11% per annum with lower coupon notes. Interest expense in 2011 included $443 million of prepayment premiums and unamortized debt issuance cost write-offs.
(b) Loss from equity investments for the year ended December 31, 2009 includes pre-tax charges of $228 million for impairment of the carrying value of our investments in certain joint ventures.
(c) Income from continuing operations for the year ended December 31, 2013 includes a $353 million benefit related to the release of valuation allowances primarily associated with tax losses in our French group. For the years ended December 31, 2012 and 2011, income from continuing operations included after-tax charges of $210 million and $279 million, respectively, for premiums and charges on the early repayment of debt. Income from continuing operations for the four months ended April 30, 2010 included after-tax income of $8,376 million related to reorganization items. Loss from continuing operations for the year ended December 31, 2009 included after-tax charges of $1,925 million related to reorganization items.
(d) Includes current maturities of long-term debt.

 

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

GENERAL

This discussion should be read in conjunction with the information contained in our Consolidated Financial Statements, and the accompanying notes elsewhere in this report. When we use the terms “we,” “us,” “our” or similar words in this discussion, unless the context otherwise requires, we are referring to LyondellBasell Industries N.V. and its consolidated subsidiaries.

References to industry benchmark prices or costs, including the weighted average cost of ethylene production, are generally to industry prices and costs from third-party consulting data. References to industry benchmarks for refining and oxyfuels market margins are to industry prices reported by Platts, a reporting service of The McGraw-Hill Companies. References to industry benchmark prices for crude oil and natural gas are to Bloomberg.

OVERVIEW

Our performance is driven by, among other things, global economic conditions generally and their impact on demand for our products, raw material and energy prices, as well as industry-specific issues, such as production capacity. Our businesses are generally subject to the cyclicality and volatility seen in the chemicals and refining industries.

Our performance during 2013 highlights the pattern of solid financial results built using our back-to-basics strategy, supplemented with high return growth projects. We continue progress by maintaining our focus on these back to basic principles, cost containment and capital discipline. Our high return, growth projects include projects that are focused on capturing additional advantages from U.S. shale gas.

Significant items that affected 2013 results include:

 

   

The continued benefit to our U.S. operations from the availability of low cost natural gas and natural gas liquids;

 

   

Increased liquefied petroleum gas (“LPG”) cracking in our European facilities;

 

   

Low refining margins, a decline in crude processing rates relative to 2012 primarily due to turnaround activities, the increased cost of renewable identification numbers (“RINs”) and low values for refining by-products; and

 

   

The benefit from the tax impact of a release of a valuation allowance related primarily to French tax carryforwards.

Other noteworthy items during 2013 include the following:

 

   

We increased our interim dividends in 2013 from $0.40 to $0.60;

 

   

We repurchased approximately 27.4 million of our ordinary shares during 2013;

 

   

Our credit rating was raised to investment grade by both Moody’s Investor Service and Standard & Poors;

 

   

Our wholly owned subsidiary, LYB International Finance B.V., issued $1.5 billion of unsecured notes;

 

   

We migrated our tax residency to the United Kingdom, providing flexibility for structuring subsidiary operations and for global cash management and repatriation strategies;

 

   

We began construction of ethylene expansions at our La Porte and Channelview facilities in Texas; and

 

   

We completed a methanol plant restart in Channelview, Texas, and a butadiene expansion project in Wesseling, Germany.

 

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Results of operations for the periods discussed in these “Results of Operations” are presented in the table below.

 

     Year Ended December 31,  

Millions of dollars

   2013     2012     2011  

Sales and other operating revenues

   $ 44,062     $ 45,352     $ 48,183  

Cost of sales

     37,940       39,595       42,732  

Selling, general and administrative expenses

     870       909       918  

Research and development expenses

     150       172       196  
  

 

 

   

 

 

   

 

 

 

Operating income

     5,102       4,676       4,337  

Interest expense

     (309     (655     (1,044

Interest income

     15       15       37  

Other income (expense), net

     (14     2       30  

Income from equity investments

     203       143       216  

Reorganization items

     (1     4       (45

Provision for income taxes

     1,136       1,327       1,059  
  

 

 

   

 

 

   

 

 

 

Income from continuing operations

     3,860       2,858       2,472  

Loss from discontinued operations, net of tax

     (7     (24     (332
  

 

 

   

 

 

   

 

 

 

Net income

   $ 3,853     $ 2,834     $ 2,140  
  

 

 

   

 

 

   

 

 

 

RESULTS OF OPERATIONS

Revenues—We had revenues of $44,062 million in 2013, $45,352 million in 2012 and $48,183 million in 2011.

2013 versus 2012—Revenues decreased $1,290 million, or 3%, in 2013 compared to 2012. Lower sales volumes in 2013 contributed 4% to the decrease in revenues over 2012. This decline in sales volumes primarily reflects the negative impact of lower crude processing rates at the Houston refinery on refining product volumes, which was offset in part by higher olefins sales volumes in our Olefins and Polyolefins–Americas (“O&P–Americas”) segment. The impact of lower sales volumes was slightly mitigated by the effect of favorable exchange rates, which increased revenues by 1% in 2013 over 2012. Average sales prices were relatively unchanged in 2013 compared to 2012.

2012 versus 2011—Lower sales volumes were responsible for a 2% decrease in revenues in 2012 compared to 2011, while lower average product prices contributed 4% to the revenue decrease. Lower natural gas liquids (“NGL”) feedstock prices contributed to the lower average sales prices for olefins and polyolefins in the O&P–Americas segment. Sales volumes in 2012 were lower than in 2011, primarily in European olefins and polyethylene and in refining. Weak economic conditions in Europe, turnaround activity at our cracker in Wesseling, Germany, and the resale of crude oil in 2011 to take advantage of favorable crude purchases were the main factors in the reduced level of sales volumes in 2012.

Cost of Sales—Cost of sales were $37,940 million in 2013, $39,595 million in 2012 and $42,732 million in 2011.

2013 versus 2012—Cost of sales declined in 2013 primarily due to a 4% decrease in volumes and a 2% decline in average unit cost of sales, which we define as total Cost of sales divided by total sales volumes. These impacts were partially offset by the unfavorable effect of changes in foreign exchange rates in 2013 relative to 2012, which resulted in a 1% increase in cost of sales. These factors, combined with the effect of the one-time items specific to 2012 discussed below, led to the $1,655 million decrease in 2013 cost of sales. A shift to cracking more NGLs in our O&P–Americas segment, increased benefits from LPG cracking and the lower cost

 

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of naphtha in our Olefins and Polyolefins–EAI (“O&P–EAI”) segment, and lower crude oil costs in our Refining segment were the most significant contributors to our lower feedstock costs in 2013. These benefits were offset in part by the higher costs of RINs and natural gas in our Refining segment and the higher costs of propylene, benzene and natural gas feedstocks in our Intermediates and Derivatives (“I&D”) segments.

2012 versus 2011—The $3,137 million decrease in cost of sales in 2012 compared to 2011 was driven by decreases of 5% in our average unit cost of sales and 2% in volumes. The primary factor behind the decrease in our average unit cost of sales was a decline in the cost of feedstocks, driven mainly by the lower prices of NGL-based raw materials, particularly ethane, used in North American olefins. Falling raw material costs, including butane, methanol and ethanol, used in oxyfuels also benefited the average unit costs of sales in the I&D segment. These lower costs were partially offset by slightly higher average naphtha feedstock costs in the O&P–EAI segment and small increases in average crude oil prices in the Refining segment.

Apart from the factors described above, cost of sales in 2012 included benefits totaling $152 million related to insurance proceeds from a 2008 hurricane, a recovery related to a former employee who pled guilty to fraud and the reversal of a reserve for an unfavorable monomer contract. These 2012 benefits were offset in part by charges totaling $97 million related to reorganization activities in Europe, facility closure costs in Australia and Italy, and the impairment of a low density polyethylene (“LDPE”) plant in Europe. In 2011, cost of sales included $35 million of charges associated with reorganization activities and increased environmental liabilities. The impact of these charges was offset by a $34 million insurance recovery related to the fraud matter mentioned above.

Operating Income—Our operating income was $5,102 million, $4,676 million and $4,337 million in 2013, 2012 and 2011, respectively.

2013 versus 2012—The increase in 2013 operating income reflects higher margins, offset in part by the decline in volumes and the items specific to 2012 discussed above. The lower average cost of feedstocks led to the improvement in margins in 2013, as average sales prices were relatively unchanged compared to 2012.

The higher margins in 2013 were related to olefins and polyethylene in our O&P–Americas and O&P–EAI segments and styrene, ethylene oxide/ethylene glycol (“EO/EG”) and acetyls in our I&D segment. These improvements were partially offset by lower refining margins in our Refining segment and lower margins for oxyfuels, butanediol (“BDO”) and solvents in our I&D segment.

2012 versus 2011—The increase in operating income in 2012 compared to 2011 reflects higher margins, offset in part by the decline in volumes. Margins improved in 2012 as the decrease in average unit cost of sales during 2012 exceeded the decrease in average sales prices during that period relative to 2011. The improvement in margins reflects strong ethylene performance in our O&P–Americas segment and higher oxyfuels margins.

Operating results for each of our business segments are reviewed further in the “Segment Analysis” section below.

Interest Expense—Interest expense was $309 million in 2013, $655 million in 2012 and $1,044 million in 2011. In 2012, we refinanced most of our long-term debt to lower coupon notes. In connection with the refinancing, we paid $294 million of premiums and wrote off $18 million of unamortized debt issuance costs. The benefit of lower interest expense from the refinancing was partially offset in 2013 by interest on our 4% Notes due 2023 and 5.25% Notes due 2043, which were issued in July 2013. In 2012, the benefit of the lower interest expense was offset in part by the premium payments and write off of unamortized debt issuance costs made in connection with the refinancing as well as the $17 million write off of capitalized debt issuance costs in connection with the termination of our U.S. asset-based credit facility in May 2012.

Other Income (Expense), net—We had other expense, net, of $14 million in 2013, and other income, net, of $2 million and $30 million in 2012 and 2011, respectively. Other expense, net, in 2013 included a $16 million loss related to the sale of our 40% interest in Nihon Oxirane Company in December 2013. See Note 9 to the

 

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Consolidated Financial Statements for additional information on the sale of this investment. Other income, net, in 2011 included gains of $41 million related to the sale of excess precious metals, $15 million related to the sale of scrap at one of our plants and $15 million related to a settlement associated with the July 2008 crane incident at our Houston refinery. These gains were partially offset by the negative effect of a $37 million fair value adjustment of the warrants to purchase our shares and $17 million of foreign exchange losses.

Income from Equity Investments—Our income from equity investments was $203 million in 2013, $143 million in 2012 and $216 million in 2011.

2013 versus 2012—The $60 million increase in income from equity investments in 2013 reflected higher margins and improved operations from our joint ventures in the Middle East and Asia. These benefits were offset in part by a $10 million impairment of our NOC Asia Ltd. joint venture. For additional information related to this impairment, see Note 9 to the Consolidated Financial Statements. Operations improved in 2013 at our Al Waha joint venture as a result of turnaround activities there in 2012. Results for 2012 were also negatively affected by planned maintenance activities at our HMC joint venture and unplanned outages at our Al Waha joint venture.

2012 versus 2011—The $73 million decrease in 2012 compared to 2011 was due to the lower operating results of our joint ventures in the Middle East and Asia, which were driven by lower average sales prices, higher raw material costs and the planned maintenance activities and unplanned outages discussed above.

Income Taxes—Our effective income tax rates of 22.7% in 2013, 31.7% in 2012 and 30.0% in 2011 resulted in tax provisions of $1,136 million, $1,327 million and $1,059 million, respectively.

2013 versus 2012—The 2013 effective income tax rate, which was lower than the U.S. statutory tax rate of 35%, reflected the release of certain valuation allowances coupled with favorable permanent deductions related to non-taxable income and the U.S. domestic production activity deduction, partially offset by the effect of local taxes and foreign exchange gains. In 2013, we released valuation allowances primarily associated with tax losses in our French tax group resulting in an overall benefit of $353 million. We continue to maintain valuation allowances in various jurisdictions totaling $167 million which could impact our effective tax rate in the future.

2012 versus 2011—The 2012 effective income tax rate, which was lower than the U.S. statutory tax rate of 35%, reflected the release of certain valuation allowances coupled with favorable permanent deductions related to non-taxable income and the U.S. domestic production activity deduction, partially offset by the effect of local taxes. The 2011 effective income tax rate, which was lower than the U.S. statutory tax rate of 35%, reflected favorable permanent deductions related to non-taxable income and the U.S. domestic production activity deduction partially offset by the effect of local taxes.

For further information related to our income taxes, see Note 18 to the Consolidated Financial Statements.

Loss from Discontinued Operations, Net of Tax—We had losses from discontinued operations, net of tax, of $7 million in 2013, $24 million in 2012 and $332 million in 2011.

The $308 million improvement in the results of our discontinued operations in 2012 compared to 2011 reflects a benefit from the suspension of operations at the Berre refinery in early January 2012 as well as pretax benefits totaling $73 million related to the liquidation of product inventory during 2012. Results for 2011 also included charges related to the Berre refinery of $130 million and $29 million, respectively, associated with the estimated cost of the social plan for affected employees and asset impairments.

Comprehensive Income—We had comprehensive income of $4,364 million in 2013, $2,864 million in 2012 and $1,639 million in 2011. The increases in comprehensive income in 2013 and 2012 over the respective prior year periods mainly reflected increases in net income and to a lesser extent, foreign currency translation adjustments and actuarial gains and losses related to our defined benefit pension plans and our other post-retirement benefit plans.

 

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The predominant local currency of our operations outside the United States is the euro, which has increased relative to the value of the U.S. dollar during 2013 and 2012 but decreased during 2011, resulting in gains and losses as reflected on the Consolidated Statements of Comprehensive Income.

In 2013, $411 million of net actuarial gains reflects $254 million of discount rate assumption changes and other immaterial liability experience gains and losses and $157 million resulting from an actual asset return in excess of the expected return. In 2012, $198 million of actuarial losses primarily reflect $261 million of discount rate assumption changes and other immaterial liability experience gains and losses, partially offset by $63 million of gains resulting from an actual asset return in excess of the expected return. In 2011, $388 million of actuarial losses primarily reflect $247 million due to discount rate assumption changes and other immaterial liability experience gains and losses and $141 million of losses resulting from an actual asset return less than the expected return. See “Critical Accounting Policies” below and Note 16 to the Consolidated Financial Statements for additional information on the key assumptions included in calculating the discount rate and expected return on plan assets.

Segment Analysis

Our continuing operations are divided into five reportable segments: O&P–Americas; O&P–EAI; I&D; Refining; and Technology. The following tables reflect selected financial information for our reportable segments.

 

     Year Ended December 31,  

Millions of dollars

   2013     2012     2011  

Sales and other operating revenues:

      

O&P—Americas segment

   $ 13,089     $ 12,934     $ 14,880  

O&P—EAI segment

     14,685       14,521       15,591  

I&D segment

     9,472       9,658       9,500  

Refining segment

     11,698       13,291       13,706  

Technology segment

     532       498       506  

Other, including intersegment eliminations

     (5,414     (5,550     (6,000
  

 

 

   

 

 

   

 

 

 

Total

   $ 44,062     $ 45,352     $ 48,183  
  

 

 

   

 

 

   

 

 

 

Operating income (loss):

      

O&P—Americas segment

   $ 3,253     $ 2,650     $ 1,855  

O&P—EAI segment

     377       127       435  

I&D segment

     1,300       1,430       1,156  

Refining segment

     22       334       809  

Technology segment

     157       122       107  

Other, including intersegment eliminations

     (7     13       (25
  

 

 

   

 

 

   

 

 

 

Total

   $ 5,102     $ 4,676     $ 4,337  
  

 

 

   

 

 

   

 

 

 

Income (loss) from equity investments:

      

O&P—Americas segment

   $ 25     $ 25     $ 21  

O&P—EAI segment

     174       121       168  

I&D segment

     4       (3     27  
  

 

 

   

 

 

   

 

 

 

Total

   $ 203     $ 143     $ 216  
  

 

 

   

 

 

   

 

 

 

Olefins and Polyolefins—Americas Segment

Overview—Ethylene produced from NGLs in North America has been much lower in cost than that produced from crude oil-based liquids. Naphtha and other crude oil-based liquids are the predominant feedstocks in the rest of the world. Margins in our olefins and polyethylene businesses in 2013, 2012 and 2011 have benefited from this advantage.

 

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Stronger segment earnings in 2013 primarily reflect improved olefins and polyethylene results over 2012. Olefins results in 2013 benefited from a decrease in our cost to produce ethylene and from higher sales volumes. Polyethylene results also improved on higher margins while polypropylene results declined on modestly lower margins.

Higher operating results for 2012 compared to 2011 were driven by continued strong ethylene performance. Ethylene margins improved in 2012 despite a decrease in the average price of ethylene as prices for ethane and propane remained advantaged. Higher sales volumes in 2012 for ethylene reflect stronger domestic demand. Polypropylene and polyethylene results also contributed to higher segment results on higher margins and moderately higher sales volumes.

Ethylene Raw Materials—Benchmark crude oil and natural gas prices generally have been indicators of the level and direction of the movement of raw material and energy costs for ethylene and its co-products in the O&P–Americas segment. Ethylene and its co-products are produced from two major raw material groups:

 

   

NGLs, principally ethane and propane, the prices of which are generally affected by natural gas prices; and

 

   

crude oil-based liquids (“liquids” or “heavy liquids”), including naphtha, condensates, and gas oils, the prices of which are generally related to crude oil prices.

Although prices of these raw materials are generally related to crude oil and natural gas prices, during specific periods the relationships among these materials and benchmarks may vary significantly. In the U.S., we have significant capability to change the mix of raw materials used in the production of ethylene and its co-products to take advantage of the relative costs of heavy liquids and NGLs.

Production economics for the industry have favored NGLs during 2013, 2012 and 2011. As a result, we have increased our use of NGLs and reduced liquids consumption at our U.S. plants in each year since 2011. During 2013, 2012 and 2011, approximately 90%, 85% and 75%, respectively, of our U.S. ethylene production was produced from NGLs.

The following table shows the average U.S. benchmark prices for crude oil and natural gas for the applicable periods, as well as benchmark U.S. sales prices for ethylene and propylene, which we produce and sell or consume internally. The table also shows the discounted U.S. benchmark prices for certain polyethylene and polypropylene products. These industry benchmark prices are third party estimates that are indicative of contract sales for some key product grades, but do not necessarily describe price trends for our full olefins or polymers product mixes. The benchmark weighted average cost of ethylene production, which reflects credits for co-product sales, is based on a third-party consultant’s estimated ratio of heavy liquid raw materials and NGLs used in U.S. ethylene production.

 

     Average Benchmark Price and Percent Change
Versus Prior Year Period Average
 
     Year Ended
December 31,
           Year Ended
December 31,
        
     2013      2012      Change     2012      2011      Change  

Crude oil, dollars per barrel:

                

West Texas Intermediate (“WTI”)

     98.06        94.15        4     94.15        95.11        (1 )% 

Light Louisiana Sweet (“LLS”)

     107.31        111.70        (4 )%      111.70        112.40        (1 )% 

Natural gas (Henry Hub), dollars per million BTUs

     3.78        2.90        31     2.90        4.14        (29 )% 

United States, cents per pound:

                

Weighted average cost of ethylene production

     16.2        21.2        (24 )%      21.2        35.6        (40 )% 

Ethylene

     46.7        48.3        (3 )%      48.3        54.3        (11 )% 

Polyethylene (high density)

     70.5        62.3        13     62.3        63.3        (2 )% 

Propylene—polymer grade

     68.7        60.4        14     60.4        75.5        (20 )% 

Polypropylene

     82.2        72.5        13     72.5        87.5        (17 )% 

 

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The following table sets forth selected financial information for the O&P–Americas segment.

 

     Year Ended December 31,  

Millions of dollars

   2013      2012      2011  

Sales and other operating revenues

   $ 13,089      $ 12,934      $ 14,880  

Operating income

     3,253        2,650        1,855  

Income from equity investments

     25        25        21  

Revenues—Revenues increased by $155 million, or 1%, in 2013 compared to 2012, and decreased by $1,946 million, or 13%, in 2012 compared to 2011.

2013 versus 2012—In 2013, a 2% increase in revenues attributable to higher olefins sales volumes, particularly propylene and butadiene, was partly offset by a 1% revenue decrease stemming from lower average sales prices. The decrease in 2013 revenues attributable to lower average sales prices primarily reflects lower average sales prices for ethylene and butadiene partly offset by higher average sales prices for polyolefins. Polyethylene sales prices were higher in 2013, largely reflecting supply constraints due to competitor outages, while increases in the cost of propylene feedstock led to higher average sales prices for polypropylene.

2012 versus 2011—In 2012, lower average sales prices across most products were responsible for an 8% decrease in revenue and lower sales volumes were responsible for an additional decrease of 5%. Average sales prices for ethylene and polyethylene were lower in 2012 mainly reflecting the significantly lower costs of NGL feedstocks. Lower average sales prices for polypropylene in 2012 reflected lower propylene prices compared to a strong propylene market in 2011. The overall decrease in sales volumes reflects the increased amount of NGLs in our olefins feed slate in 2012, as NGLs produce significantly less co-products than liquids feedstock. Sales volumes of the main products in the segment (ethylene, polyethylene and polypropylene) actually increased in 2012 over 2011 levels. The increase in ethylene sales volumes was driven by improved demand and higher spot sales opportunities in 2012. The higher polyethylene sales volumes in 2012 reflect an increase in market share.

Cost of Sales—Cost of sales decreased by $446 million in 2013 compared to 2012, and by $2,774 million in 2012 compared to 2011.

2013 versus 2012—The lower cost of sales in 2013 compared to 2012 resulted mainly from a shift in our feedstock slate in 2013 to a higher percentage of lower priced NGL feedstocks in the feed mix. This shift in our feedstock slate was largely responsible for a 7% decrease in average unit cost of sales. These lower feedstock costs in 2013 were offset in part by the effect of the 2% volume increase mentioned above. Also, cost of sales in 2012 included a $29 million benefit from an insurance settlement related to damages from a hurricane in 2008.

2012 versus 2011—Feedstock costs were lower in 2012 compared to 2011 due to the significantly lower prices for NGLs, particularly ethane and propane, and propylene. These lower prices resulted in an 17% decline in average unit cost of sales. The lower costs described above, a 5% decrease in volumes and the $29 million benefit from the insurance settlement discussed above led to the $2,774 million decrease in 2012 segment cost of sales.

Operating Income—Operating income increased by $603 million in 2013 compared to 2012, and by $795 million in 2012 compared to 2011.

2013 versus 2012—In 2013, the increase in operating income reflects higher olefins and polyethylene margins, and an increase in volumes compared to 2012. The decrease in feedstock costs, which more than offset the effect of the lower average sales prices discussed above, resulted in the higher margins.

Olefins margins benefited from the lower costs of NGL and heavy liquids feedstock, which more than offset the impact of lower sales prices. This benefit, coupled with the higher propylene and butadiene volumes

 

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discussed above led to higher olefins results in 2013 compared to 2012. Higher polyethylene margins reflected higher sales prices and to a lesser extent, lower feedstock costs. Although average sales prices were significantly higher for polypropylene in 2013, this benefit was outpaced by the rising cost of its feedstock, propylene, resulting in modestly lower margins over 2012. In addition, operating income in 2012 included the benefit related to the insurance settlement discussed above.

2012 versus 2011—The increase in 2012 operating income primarily reflects higher margins offset in part by the decrease in volumes, compared to 2011. The margin improvement in 2012 reflected the benefit of our lower cost of ethylene production in 2012, which surpassed the offsetting impact of lower average sales prices during the period.

Although the increase in 2012 operating income was largely attributable to strong ethylene performance, better performance in polyethylene and polypropylene yielded higher product margins and sales volumes in 2012. Decreases in the prices for ethylene and propylene outpaced declines in average polymer sales prices and led to higher polyethylene and polypropylene margins. Operating income in 2012 also reflected the benefit related to the hurricane insurance settlement discussed above.

Olefins and Polyolefins—Europe, Asia and International Segment

Overview—Although operating results have improved in 2013 compared to 2012, market conditions in Europe remain weak. Operating results in 2013 primarily reflect higher results for European olefins and also reflect improved margins in most businesses relative to 2012. Results during 2012 were impacted by a scheduled maintenance turnaround at our Wesseling, Germany plant. Weak market conditions in 2012 amid economic uncertainty resulted in a decline for European demand for ethylene and polyolefins compared to 2011. The volatility of naphtha feedstock prices throughout 2012 resulted in substantial swings in olefins margins over this period.

Operating results in 2012 primarily reflected weak margins and lower sales volumes across most products. The decrease in sales volumes reflects weak European demand and the negative impact of reduced production during the last half of 2012 from a turnaround at our Wesseling, Germany cracker. The volatility in naphtha feedstock price noted above resulted in compressed olefins cracker margins for most of the year, and considerably lower demand reduced butadiene prices and margins relative to 2011. Polypropylene and polyethylene results in 2012 reflect lower product margins and polyethylene sales volumes driven by lower demand. Results for our polypropylene (“PP”) compounding and polybutene-1 businesses were slightly higher in 2012 compared to 2011.

Ethylene Raw Materials—In Europe, heavy liquids are the primary raw materials for our ethylene production.

 

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The following table shows the average Western Europe benchmark prices for Brent crude oil for the applicable periods, as well as benchmark Western Europe prices for ethylene and propylene, which we produce and consume internally or purchase from unrelated suppliers, and discounted prices for certain polyethylene and polypropylene products. These industry benchmark prices are third party estimates that are indicative of contract sales for some key product grades, but do not necessarily describe price trends for our full olefins or polymers product mixes.

 

     Average Benchmark Price and Percent Change
Versus Prior Year Period Average
 
     Year Ended
December 31,
           Year Ended
December 31,
        
     2013      2012      Change     2012      2011      Change  

Brent crude oil, dollars per barrel

     108.7        111.7        (3 )%      111.7        110.7        1

Western Europe benchmark prices, €0.01 per pound:

                

Weighted average cost of ethylene production

     34.7        38.9        (11 )%      38.9        36.5        7

Ethylene

     55.8        56.2        (1 )%      56.2        51.7        9

Polyethylene (high density)

     58.2        59.4        (2 )%      59.4        55.4        7

Propylene

     49.5        50.7        (2 )%      50.7        50.7        0

Polypropylene (homopolymer)

     57.9        58.3        (1 )%      58.3        58.8        (1 )% 

Average exchange rate, $US per €

     1.3280        1.2858        3     1.2858        1.3921        (8 )% 

The following table sets forth selected financial information for the O&P–EAI segment.

 

     Year Ended December 31,  

Millions of dollars

   2013      2012      2011  

Sales and other operating revenues

   $ 14,685      $ 14,521      $ 15,591  

Operating income

     377        127        435  

Income from equity investments

     174        121        168  

Revenues—Revenues in 2013 increased by $164 million, or 1%, compared to 2012, and decreased in 2012 by $1,070 million, or 7%, compared to 2011.

2013 versus 2012—In 2013, a 2% increase in revenues driven by the favorable impact of changes in foreign exchange was partially offset by a 1% decrease stemming from lower average sales prices. The decrease in average sales prices was largely attributable to lower sales prices for olefins. These prices are generally correlated with the cost of naphtha, which decreased during 2013 compared to 2012. Sales volumes in 2013 decreased less than 1% from 2012, as a small decrease in olefins volumes was substantially offset by a similar increase in polypropylene sales volumes.

2012 versus 2011—Lower average sales prices in 2012 contributed 4% to the revenue decrease and lower sales volumes were responsible for the remaining revenue decrease of 3%, compared to 2011. The lower average sales prices and sales volumes reflect weak economic conditions in Europe. In addition, polyethylene sales volumes were affected by an explosion in a reactor bay at our LDPE plant in Wesseling, Germany that occurred during the first quarter 2012.

Cost of Sales—Cost of sales decreased by $48 million in 2013 compared to 2012, and by $754 million in 2012 compared to 2011.

2013 versus 2012—Cost of sales in 2013 decreased slightly as the combined benefit of the small change in volumes and a 2% decrease in average unit cost of sales was not quite offset by a 2% unfavorable impact from changes in foreign exchange rates. The decline in the 2013 average unit cost of sales was mainly due to lower naphtha feedstock costs and increased benefits from LPG cracking relative to 2012. In addition to the factors

 

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above, cost of sales in 2013 included a $25 million benefit from an insurance settlement related to the damage to our LDPE plant described above. Cost of sales was also negatively impacted in 2012 by the one-time items mentioned below.

2012 versus 2011—The decline in 2012 cost of sales was mainly due to decreases of 3% in volumes and 2% in average unit cost of sales compared to 2011. Decreases in feedstock costs, primarily propylene and naphtha, were the primary factor in the 2012 decline in unit cost of sales. The one-time items discussed below negatively impacted cost of sales in 2012 and 2011 by an equal amount.

In 2012, cost of sales included charges of $35 million for restructuring activities in Europe, $22 million for closure costs in Australia and Italy and $22 million for impairment of assets related to the damage of our LDPE plant in Wesseling, Germany described above. These charges were partially offset by a $28 million benefit in 2012 related to the reversal of a reserve for an unfavorable monomer contract. Cost of sales in 2011 also included charges totaling $30 million associated with activities to reorganize certain functional organizations and for increased environmental liabilities at our Wesseling, Germany site.

Operating Income—Operating results increased by $250 million in 2013 compared to 2012 and decreased by $308 million in 2012 compared to 2011.

2013 versus 2012—In 2013, the combined benefit of lower feedstock costs and increased LPG cracking, which more than offset the impact of lower average sales prices, led to an improvement in margins. This improvement in margins, the slight decrease in 2013 volumes and the impact of the one-time items in 2013 and 2012 mentioned above resulted in the $250 million increase in 2013 operating income.

The increase in 2013 segment results was driven mainly by higher olefins results. The higher olefins results reflect higher margins as lower naphtha feedstock costs and the benefit of processing advantaged feedstock during the summer months more than offset lower average sales prices during the period. In addition, olefins sales price increases in 2012 lagged steep naphtha feedstock cost increases for several months.

Excluding the impact of the one-time items discussed above, underlying results for polyolefins reflected higher polyethylene margins and an increase in polypropylene volumes. PP compounding margins, which reflected higher sales prices coupled with decreases in the costs of its raw materials, propylene, also improved in 2013 relative to 2012. Higher margins due to higher average sale prices contributed to the better polybutene-1 results in 2013 compared to 2012.

2012 versus 2011—In 2012, the decrease in average sales prices, which was offset in part by the decrease in feedstock costs, led to lower margins compared to 2011. These lower margins, the impact of lower volumes and $58 million of charges to SG&A related to the restructuring activities discussed above were largely responsible for the decline in operating income from the level seen in 2011.

Excluding the impact of the items occurring in 2012 and 2011 included in the discussion of Cost of sales above, operating results for 2012 reflect lower cracker and butadiene margins and a 6% decline in olefins production volumes. Lower butadiene margins were principally the result of lower average sales prices in the second half of 2012 compared to the very strong levels in 2011 as supplies outpaced weaker global demand. The turnaround at our Wesseling, Germany cracker and the subsequent delay in the start-up of activities during the last half of 2012 contributed to the decline in production volumes.

Polyethylene results were lower in 2012 as a result of lower sales volumes and margins. Margins also declined for polypropylene in Europe. The lower polyethylene and polypropylene margins reflected decreases in average sales prices that exceeded average decreases in raw material prices. The lower polyethylene sales volumes in 2012 reflected lower operating rates which were largely attributable to the Wesseling turnaround. Slightly improved results for our PP compounding and polybutene-1 (“PB-1”) businesses reflected margins that were higher in 2012 compared to 2011. Sales volumes for PP compounding and PB-1 were relatively unchanged over the two periods.

 

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Intermediates and Derivatives Segment

Overview—Our I&D operating results for 2013 were lower relative to 2012, mainly due to a decline in oxyfuels results from the exceptionally strong results reported in 2012. Additions to BDO industry capacity and raw material increases during 2013 contributed to a decline in our propylene oxide (“PO”) derivative results. Improved results for styrene, acetyls and EO/EG in 2013 were driven by higher margins as compared to 2012. Results were also negatively impacted during the 2013 period by scheduled maintenance at our facilities in the U.S. and Europe.

Operating results for 2012 reflected the exceptional performance of our oxyfuels business. Global gasoline prices and oxygenated blend premiums remained high relative to butane feedstock costs compared to 2011 and our oxyfuels sales volumes increased as we expanded to new regional markets. Higher margins for tertiary butyl alcohol (“TBA”) and derivatives, which reflected higher average sales prices and lower raw material costs, also contributed to the higher operating results for the I&D segment for 2012. These benefits were partially offset by lower results for our PO derivatives and lower ethylene glycol margins.

The following table sets forth selected financial information for the I&D segment. In addition, the table shows MTBE margins in Northwest Europe (“NWE”).

 

     Year Ended December 31,  

Millions of dollars

   2013      2012     2011  

Sales and other operating revenues

   $ 9,472      $ 9,658     $ 9,500  

Operating income

     1,300        1,430       1,156  

Income (loss) from equity investments

     4        (3     27  

Market margins, cents per gallon

       

MTBE–NWE

     79.1        118.2       83.1  

Revenues—Revenues for 2013 decreased by $186 million, or 2%, compared to 2012 and increased $158 million, or 2%, for 2012 compared to 2011.

2013 versus 2012—A 4% decrease in revenues in 2013 stemming from lower sales volumes was offset in part by increases in revenue of 1% due to higher average sales prices and 1% from favorable foreign exchange impacts. In 2013, lower sales volumes for PO and derivatives and styrene were partially offset by higher oxyfuels and methanol sales volumes, compared to 2012. An oversupplied market, which more than offset the benefit from nominal demand growth, contributed to lower BDO sales volumes in 2013 compared to 2012. Turnaround activities in 2013 led to lower styrene volumes during that period. Improved South American demand resulted in higher oxyfuels sales volumes relative to 2012. The increase in methanol sales volumes was attributable to the restart in December 2013 of our Channelview, Texas, methanol plant, which had been idled since 2004.

Higher average sales prices in 2013 increased revenues by 1% compared to 2012. Average sales prices for PO increased in 2013 largely due to increases in the price of propylene. Supply constraints due to industry outages resulted in higher average sales prices for styrene in 2013 compared to 2012. Higher demand for methanol due to supply constraints in the Middle East and Asia coupled with supply constraints for VAM in Europe, led to increases in acetyls sales prices in 2013 over those seen in 2012. These increases were substantially offset by declines in oxyfuels and BDO sales prices. Oxyfuels sales prices decreased in 2013, reflecting reduced spreads over gasoline relative to a supply-constrained market in 2012, as well as lower gasoline prices and reduced gasoline spread over butane. BDO sales prices also declined due to weak economic conditions and an oversupplied Asian market.

2012 versus 2011—The increase in 2012 revenues reflected a 2% increase due to higher sales volumes, primarily oxyfuels and acetyls, and a decrease of less than 1% from lower average sales prices. Higher sales

 

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volumes for oxyfuels in 2012 reflected strong market demand and expansion into new geographic markets, primarily Eastern Europe, relative to 2011. Oxyfuels volumes in 2011 were negatively impacted by turnaround activities in Europe. Increased production from better catalyst yields early in 2012, combined with strong acetyls demand in our European and South American markets contributed to the higher sales volumes for acetyls.

Cost of Sales—Cost of sales decreased by $60 million in 2013 compared to 2012, and by $97 million in 2012 compared to 2011.

2013 versus 2012—Cost of sales declined in 2013 relative to 2012 due to the impact of a 4% decrease in volumes discussed above, which was partly offset by a 2% increase in average unit cost of sales and a 1% unfavorable impact of changes in foreign exchange rates on cost of sales. Higher feedstock costs, particularly propylene, benzene and natural gas, contributed to the increase in the 2013 average unit cost of sales. Cost of sales in 2012 also included an $18 million benefit related to a hurricane insurance settlement.

2012 versus 2011—The $97 million decrease in segment cost of sales in 2012 reflects a 3% decrease in our average unit cost of sales offset in part by the 2% increase in volumes. Lower feedstock costs, primarily propylene, ethylene and butane, and to a lesser extent, utilities, were the primary factors in the decline in unit cost of sales. Cost of sales was also affected by an $18 million benefit related to an insurance settlement in 2012.

Operating Income—Operating income decreased by $130 million in 2013 compared to 2012 and increased by $274 million in 2012, compared to 2011.

2013 versus 2012—Lower margins, the decrease in volumes and the absence of the insurance settlement discussed above led to the decline in operating income in 2013. Margins were lower in 2013 as the increase in our average unit cost of sales more than offset the increase in average sales prices during the period.

Lower results for oxyfuels and PO derivatives were offset in part by higher styrene, acetyls and EO/EG margins. Oxyfuels results in 2013 reflect lower margins relative to the exceptionally strong margins in 2012. Reduced spreads over gasoline relative to a supply-constrained market in 2012, as well as lower gasoline prices and a reduced gasoline spread over butane contributed to the decrease in oxyfuels margins in 2013. Results for PO derivatives declined in 2013 primarily due to lower BDO and solvents results. An oversupplied Asian market which more than offset nominal demand growth, resulted in lower sales volumes and weaker margins for BDO in 2013 compared to 2012.

These decreases were partially offset by improved styrene margins due to industry outages which constrained global supply and led to increases in average sales prices in 2013, which outpaced the higher costs of benzene feedstock. The improvement in acetyls results reflects the benefit of the restart of our Channelview, Texas methanol plant. Higher average sales prices and the lower cost of ethylene feedstock, the benefits of which were partly offset by higher natural gas costs, also contributed to the increase in acetyls results. Higher margins for EO/EG in 2013 reflected a modest increase in average sales prices and lower ethylene feedstock costs.

2012 versus 2011—The decrease in average feedstock costs exceeded the decrease in average sales prices during the period, which led to improved product margins in 2012 compared to those seen in 2011. These higher margins coupled with the benefit stemming from higher volumes were the primary drivers leading to the $274 million increase in operating income. Operating results for 2012 also included the benefit related to the insurance settlement discussed above.

The improvement in oxyfuels margins and volumes were the primary factors for the increase in 2012 operating income. The higher oxyfuels margins reflect an increase in the spread between gasoline and raw materials, butane, methanol and ethanol as well as a higher market blend premium for oxyfuels products over gasoline. Higher TBA and derivatives margins in 2012 which benefited from lower butane feedstock prices due to lower natural gas prices and higher average sales prices also contributed to the increase in operating income.

 

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These higher results were offset in part by lower results for PO and derivatives, and ethylene glycol which saw average sales prices decrease more than the cost of their respective raw materials. Lower demand for propylene glycol used in deicers due to the unseasonably warm start to winter also contributed to the decrease in 2012 PO and derivatives results. Results for acetyls reflected lower natural gas and ethylene feedstock costs and higher volumes, which largely offset lower product sales prices.

Refining Segment

Overview—The Refining segment comprises the operations of our full conversion refinery located on the Houston Ship Channel in Houston, Texas. The Berre refinery, which was previously included in the Refining segment through the first quarter of 2012, was classified as discontinued operations in the second quarter of 2012. Accordingly, results of operations for the Berre refinery are not included in the segment discussion.

Lower refining margins in 2013 reflect decreases in the average differential between light and heavy crude oils, lower by-product values and higher costs for RINs, a U.S. government established credit used to show compliance in meeting the Environmental Protection Agency’s Renewable Fuel Standard. Operating results were unfavorably impacted by lower crude processing rates, largely due to turnaround activities.

Although the benchmark Maya 2-1-1 margin increased in 2012, our refinery’s operating results decreased largely as a result of a reduced benefit from favorable crude purchasing opportunities compared to 2011 and lower by-product spreads for petroleum coke and other natural gas-based products. Operating results also reflected lower crude processing rates compared to 2011 as a result of planned and unplanned plant outages.

The following table sets forth selected financial information and heavy crude processing rates for the Refining segment and the U.S. refining market margins for the applicable periods. “LLS” is a light crude oil, while “Maya” is a heavy crude oil.

 

     Year Ended December 31,  

Millions of dollars

   2013      2012      2011  

Sales and other operating revenues

   $ 11,698      $ 13,291      $ 13,706  

Operating income

     22        334        809  

Heavy crude processing rates, thousands of barrels per day

     232        255        263  
  

 

 

    

 

 

    

 

 

 

Market margins, dollars per barrel

        

Light crude oil—2-1-1

   $ 12.89      $ 12.86      $ 8.95  

Light crude oil—Maya differential

     10.05        12.05        14.10  
  

 

 

    

 

 

    

 

 

 

Total Maya 2-1-1

   $ 22.94      $ 24.91      $ 23.05  
  

 

 

    

 

 

    

 

 

 

Revenues—Revenues decreased by $1,593 million, or 12%, in 2013 compared to 2012 and by $415 million, or 3%, from 2011 to 2012.

2013 versus 2012—Lower sales volumes in 2013 contributed 9% to the revenue decrease over 2012. This decrease in sales volumes corresponds to a 9% decrease in 2013 crude processing rates, mainly due to a scheduled turnaround during the first quarter of 2013 and unplanned maintenance during the year. In 2013, the increased supply of refined products relative to demand is reflected in a 3% decrease in revenues attributable to lower average refined product sales prices.

2012 versus 2011—Lower sales volumes in 2012 were responsible for a revenue decrease of 6% compared to 2011. The lower sales volumes reflected less resale of crude oil versus 2011. In addition, crude processing

 

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rates were lower in 2012 compared to 2011 as a result of planned and unplanned outages in 2012. A 3% revenue increase from sales prices in 2012 compared to 2011 was driven by the impact of higher gasoline and distillate prices, partly offset by lower values for refinery by-products.

Cost of Sales—Cost of sales decreased by $1,276 million in 2013 compared to 2012, and increased by $40 million in 2012 compared to 2011.

2013 versus 2012—Cost of sales in 2013 primarily reflects the 9% decline in volumes discussed above and a 1% decrease in average unit cost of sales relative to 2012. The benefit of lower crude oil feedstock costs in 2013, which was offset in part by $87 million of higher RINs costs and increased natural gas costs, resulted in the decrease in average unit cost of sales compared to 2012.

Additionally, cost of sales in 2013 included benefits of $14 million related to recoveries and a settlement associated with a former employee who pled guilty to fraud and $10 million related to the resolution of property tax assessments for the three-year period beginning 2011. In 2012, cost of sales benefited from $53 million of insurance settlement proceeds associated with a hurricane in 2008 and a recovery of $24 million related to the employee fraud matter discussed above.

2012 versus 2011—In 2012, a 7% increase in our average unit cost of sales relative to 2011 was driven by higher feedstock costs, which reflected a reduced benefit from favorable crude purchasing opportunities and higher heavy crude prices relative to 2011. This increase was somewhat offset by the 6% decline in volumes discussed above. In 2012, cost of sales also included $77 million of one-time benefits described above while 2011 reflected a $34 million benefit from an insurance recovery related to the fraud mentioned above.

Operating Income—Operating income decreased by $312 million in 2013 compared to 2012 and by $475 million in 2012 compared to 2011.

2013 versus 2012—Lower margins, the effect of the lower volumes and the specific one-time items impacting each period that are discussed above led to the decrease in 2013 operating income compared to 2012. Margins were lower in 2013 as our average unit cost of sales declined less than our average sales prices. Our refining margins in 2013, which were lower relative to 2012, were impacted by decreases in the average differential between light and heavy crude oils. Lower by-product values and higher natural gas and RINs costs also negatively impacted our margins in 2013.

Crude oil costs at the refinery in 2013 relative to 2012 reflected increased purchases priced in relation to WTI and Brent crude oils and a lesser amount priced relative to Maya, which has reduced the comparability of our refined product spreads with the Maya benchmark product spread.

2012 versus 2011—The $475 million decrease in 2012 operating income relative to 2011 reflected lower margins, the effect of lower volumes and the impact on each period of the specific one-time items discussed above. The increase in our average unit cost of sales in 2012, which more than offset the benefit of higher average sales prices, resulted in margins that were lower than those seen in 2011.

Our refining margins decreased in 2012 despite an increase in the Maya 2-1-1 benchmark margin. Our refining margins in 2012, which were lower relative to the Maya 2-1-1, reflected a reduced benefit from favorable crude purchasing opportunities compared to 2011 and lower by-product spreads for petroleum coke and other natural gas-based products.

Technology Segment

Overview—Improved operating results in 2013 compared to 2012 reflect higher licensing and services revenues and lower research and development (“R&D”) expenses.

 

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Restructuring activities in Europe in 2012 and 2011 and the impairment of a research and development project in 2011 contributed to the decline in 2012 Technology segment results over 2011. Underlying operations of the Technology segment in 2012 were relatively unchanged from 2011.

The following table sets forth selected financial information for the Technology segment.

 

     Year Ended December 31,  

Millions of dollars

   2013      2012      2011  

Sales and other operating revenues

   $ 532      $ 498      $ 506  

Operating income

     157        122        107  

Revenues—Revenues increased by $34 million, or 7%, in 2013 compared to 2012 and decreased by $8 million, or 2%, in 2012 compared to 2011.

2013 versus 2012—Higher licensing and services revenues primarily due to a one-time, lump-sum settlement in 2013 associated with a process license agreement entered into in a prior year contributed 7% to the increase in 2013 revenues over 2012. Lower catalyst sales volumes decreased revenues by 2%, while average catalyst sales prices in 2013 remained relatively unchanged from 2012. Favorable foreign exchange rates contributed the remaining 2% increase in 2013 revenues.

2012 versus 2011—The decrease in 2012 revenues reflects lower catalyst sales volumes, which were responsible for a revenue decrease of 1% in 2012 compared to 2011. Price changes in 2012 accounted for a revenue decrease of 4% compared to 2011. In addition, the recognition of higher revenues on process licenses issued in prior years in 2012 resulted in an increase of 3% in revenues compared to 2011.

Operating Income—Operating income increased by $35 million in 2013 compared to 2012 and by $15 million in 2012 compared to 2011.

2013 versus 2012—The improvement in operating income in 2013 reflects higher licensing and services revenues discussed above and lower R&D costs compared to 2012. In 2012, segment results included an $18 million charge related to R&D restructuring activities in Europe.

2012 versus 2011—The underlying operations of the Technology segment’s businesses in 2012 were relatively unchanged compared to 2011. Lower catalyst results which stemmed from lower margins and sales volumes were substantially offset by higher revenue recognized from process licenses issued in prior years.

Apart from the factors discussed above, operating results for 2012 included the $18 million charge related to the restructuring activities discussed above. In addition, charges of $16 million related to restructuring activities and asset retirement obligations associated with a relocated R&D facility and $19 million for the impairment of an R&D project in Europe were included in our 2011 operating results.

FINANCIAL CONDITION

Operating, investing and financing activities of continuing operations, which are discussed below, are presented in the following table:

 

     Year Ended December 31,  

Millions of dollars

   2013     2012     2011  

Source (use) of cash:

      

Operating activities

   $ 4,835     $ 4,787     $ 2,860  

Investing activities

     (1,602     (1,013     (1,021

Financing activities

     (1,589     (2,145     (4,955

 

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Operating Activities—Cash of $4,835 million provided in 2013 primarily reflected earnings, adjusted for non-cash items, proceeds received from Italian tax authorities for refunds of VAT from prior periods, distributions from our joint ventures, insurance settlements and cash provided by the main components of working capital – accounts receivable, inventories and accounts payable. These increases were offset in part by company contributions to our pension plans.

The main components of working capital provided cash of $60 million in 2013. This reflects increases of $64 million, $151 million and $275 million in accounts receivable, inventories and accounts payable, respectively. The increase in inventory is attributable to a build in our O&P—Americas polyethylene inventory at the end of 2013 in preparation for a turnaround scheduled during the first half of 2014 at our La Porte, Texas facility, and an increase in crude oil inventory over 2012 levels. These increases were only partially offset by decreases in our I&D segment inventories. The increase in accounts receivable reflects higher 2013 sales volumes compared to the same period in 2012 within the O&P—Americas and I&D segments. A temporary increase in the purchase of intermediate feedstocks due to operating issues at the Houston refinery at the end of 2013 and an increase in payment terms for crude oil purchases in our Refining segment were the primary drivers for the increase in accounts payable.

Cash of $4,787 million provided in 2012 primarily reflected earnings, adjusted for non-cash items, proceeds received from income tax refunds, distributions from our joint ventures, insurance settlements and cash provided by the main components of working capital. These increases were offset in part by company contributions to our pension plans and premiums and other fees related to prepayment of debt.

The main components of working capital provided cash of $151 million in 2012. This reflects a decrease in inventories of $441 million, partially offset by a $101 million increase in accounts receivable and a $189 decrease in accounts payable. A reduction in the high level of our O&P—Americas olefins inventories that were built at the end of 2011 in preparation for a turnaround scheduled for early 2012 at our Channelview, Texas facility, and the liquidation of refined products and crude oil inventories following the January 2012 shutdown of our Berre refinery were the primary contributors to the $441 million decrease in inventories. The increase in accounts receivable reflects higher sales volumes at the end of 2012 compared to the same period in 2011, while the lower accounts payable balance at December 31, 2012 reflects lower outstanding crude oil invoices compared to December 31, 2011.

Cash of $2,860 million provided in 2011 primarily reflected earnings, adjusted for non-cash items, and higher distributions from our joint ventures, partially offset by an increase in cash used by the main components of working capital and payments totaling $1,699 million related to company contributions to our pension plans, tax payments, premiums and other fees related to prepayments of debt and a litigation settlement.

The main components of working capital used cash of $118 million in 2011. The increase in these working capital components during 2011 reflects increases of $89 million and $732 million in accounts receivable and inventories, respectively, partially offset by a $703 million increase in accounts payable. The increases in both accounts receivable and accounts payable reflect increasing prices over the period. The increase in inventories reflects higher prices and increased volumes, especially in the O&P—Americas business segment as we built inventory in preparation for a major first quarter 2012 turnaround.

Investing Activities—Cash used in investing activities in 2013, 2012, and 2011 primarily reflects capital expenditures of $1,561 million, $1,060 million and $1,050 million, respectively. The increased level of capital spending in 2013 funded turnaround activities at several sites, construction of our methanol plant restart at our Channelview, Texas site, debottlenecks of certain assets to enhance production, railcar purchases and other plant improvement projects. In 2011, we purchased a pipeline for $73 million and received proceeds of $71 million from the sale of assets, which included $57 million related to the sale of surplus precious metals.

 

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The following table summarizes our capital expenditures plan for 2014 and actual capital expenditures for our continuing operations for the periods from 2011 through 2013:

 

      Plan
2014
     Year Ended December 31,  

Millions of dollars

      2013      2012      2011  

Capital expenditures by segment:

           

O&P—Americas

   $ 933      $ 645      $ 468      $ 425  

O&P—EAI

     194        229        254        235  

I&D

     271        443        159        101  

Refining

     154        209        136        224  

Technology

     25        30        43        26  

Other

     15        5        —          10  
  

 

 

    

 

 

    

 

 

    

 

 

 

Consolidated capital expenditures of continuing operations

   $ 1,592      $ 1,561      $ 1,060      $ 1,021  
  

 

 

    

 

 

    

 

 

    

 

 

 

In 2011, our discontinued operations had capital expenditures of $29 million.

Capital spending projected for 2014 reflects a small increase over 2013 levels. In 2014, capital spending for our O&P—Americas segment is projected to increase relative to 2013 due to the expected completion of an ethylene expansion and associated turnaround at our LaPorte, Texas facility, a planned debottleneck at our Corpus Christi, Texas facility and the installation of new furnaces at our Channelview, Texas facility. This increase will be offset in part by reduced capital spending planned for the I&D and Refining segments. Capital spending planned for the I&D segment is lower in 2014 due to the completion in 2013 of the restart of our methanol plant in Channelview, Texas.

The higher levels of capital spending for our I&D and O&P—Americas segments in 2013 relative to 2012 were primarily related to the methanol plant restart in Channelview, Texas, and the ethylene expansion project at our LaPorte, Texas, facility, respectively.

Financing Activities—Financing activities used cash of $1,589 million during 2013. We made payments totaling $1,949 million to repurchase ordinary shares and paid dividends of $1,127 million to our shareholders.

In July 2013, we received net proceeds totaling $1,468 million from the issuance of $750 million of 4% guaranteed notes due 2023 and $750 million of 5.25% guaranteed notes due 2043, and paid fees totaling $23 million.

Financing activities used cash of $2,145 million during 2012. Financing activities in 2012 reflect proceeds of $3,000 million from the issuance of $2,000 million of 5% senior notes due 2019 and $1,000 million of 5.75% senior notes due 2024. Net proceeds from the notes, together with cash on hand, were used to finance the repayment in full of the remaining $2,676 million of previously outstanding notes and to pay $294 million for associated premiums and fees, which are reflected in operating cash flows.

In May 2012, we entered into a five-year revolving credit facility, and terminated our asset-based credit facility. The revolving credit facility may be used for dollar and euro denominated borrowings and includes a sublimit for up to $700 million of dollar and euro denominated letters of credit. The balance of outstanding borrowings and letters of credit under the facility may not exceed $2,000 million at any given time.

In September 2012, we entered into a three-year, $1,000 million U.S. accounts receivable securitization facility that permits the sale of certain eligible trade receivables to participating financial institutions. The facility also provides for the issuance of letters of credit up to $200 million.

In the aggregate, we paid fees related to these 2012 financing activities totaling $53 million.

 

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Cash dividends of $2,415 million were paid during 2012, which include a special dividend of $2.75 per share paid on December 11, 2012 to shareholders of record on November 19, 2012.

Financing activities used cash of $4,955 million during 2011. In 2011, we redeemed an aggregate of $3,050 million of previously existing notes. We paid premiums totaling $404 million and bank fees of $7 million in conjunction with these redemptions.

Also in 2011, we issued $1,000 million of 6% senior notes due 2021 and used the proceeds to pay a portion of a special dividend of $4.50 per share, totaling $2,580 million. In addition to the special dividend, we paid a final 2010 dividend and interim dividends totaling $313 million. In June 2011, we paid $15 million of fees related to the amendment of our asset-based credit facility.

For additional information related to these financing activities, see Note 12 to the Consolidated Financial Statements.

Liquidity and Capital Resources—As of December 31, 2013, we had unrestricted cash and cash equivalents of $4,450 million, of which $1,528 million was held outside the U.S., principally in the United Kingdom. Less than 1% of our outstanding cash balance is held in a country that has established government imposed currency restrictions that could impede the ability of our subsidiary to transfer funds to us. There are currently no other legal or economic restrictions that would impede such transfers of cash. We also had total unused availability under our credit facilities of $3,469 million at December 31, 2013, which included the following:

 

   

$2,000 million under our $2,000 million revolving credit facility.

 

   

$892 million under our $1,000 million U.S. accounts receivable securitization facility. Availability under this facility is subject to a borrowing base of eligible receivables, which is reduced by outstanding borrowings and letters of credit, if any. This facility had no outstanding borrowings or letters of credit at December 31, 2013.

 

   

€405 million and $22 million (totaling approximately $577 million) under our €450 million European receivables securitization facility. Availability under this facility is subject to a borrowing base, net of outstanding borrowings. There were no outstanding borrowings under this facility at December 31, 2013.

See Note 12 to the Consolidated Financial Statements for additional information related to our credit facilities.

We also have outstanding letters of credit and bank guarantees totaling $424 million at December 31, 2013 issued under uncommitted credit facilities.

At December 31, 2013, we had total debt, including current maturities, of $5,835 million.

On July 16, 2013, our direct, 100% owned subsidiary, LYB International Finance B.V., issued $750 million of 4% Notes due 2023 and $750 million of 5.25% Notes due 2043 at discounted prices of 98.678% and 97.004%, respectively. Proceeds from these notes are being used for general corporate purposes, including repurchases of our ordinary shares. Interest payments under these notes commenced on January 15, 2014. These unsecured notes, which are fully and unconditionally guaranteed by LyondellBasell Industries N.V., rank equally in right of payment to all of LYB International Finance B.V.’s existing and future unsecured indebtedness and to all of LyondellBasell’s existing and future unsubordinated indebtedness. These notes may be redeemed or repaid at any time and from time to time prior to maturity at an amount equal to the greater of 100% of the principal amount of the notes redeemed and repaid, and the sum of the present values of the remaining scheduled payments of principal and interest on the notes to be redeemed (exclusive of interest accrued to the date of redemption)

 

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discounted to the date of redemption on a semi-annual basis at the applicable treasury yield plus 25 basis points in the case of the 4% Notes due 2023 and plus 30 basis points in the case of the 5.25% Notes due 2043.

In May 2013, we amended our $2,000 million revolving credit facility to extend its maturity date by one year to May 2018 and in April 2013, we amended and restated our €450 million European receivables securitization facility to obtain more favorable terms and conditions, including reduced pricing, and to extend the maturity date of the facility to April 2016.

In May 2013, our Supervisory Board announced a share repurchase program under which we may repurchase up to 10% of our shares outstanding through May 21, 2014, for a total of approximately 57.6 million shares. Our share repurchase program does not have a stated dollar amount, and purchases may be made through open market purchases, private market transactions or other structured transactions. Repurchased shares may be retired or used for general corporate purposes, including various employee benefit and compensation plans. As of December 31, 2013, we have purchased 27,359,002 shares under this program for approximately $1,949 million. As of February 18, 2014, we had approximately 26.7 million shares remaining under the current authorization. The timing and amount of additional shares repurchased will continue to be determined by our Management Board based on its evaluation of market conditions and other factors.

As a result of ceasing operations at our Berre refinery in France in January 2012, we expect to make future payments to severed employees and for exit and disposal activities. See Note 3 to the Consolidated Financial Statements for additional information related to this matter.

We may repay or redeem our debt, including purchases of our outstanding bonds in the open market, using cash on hand, cash from operating activities or proceeds from asset divestitures. We plan to finance our ongoing working capital, capital expenditures, debt service and other funding requirements with cash from operations. We also may, depending on market conditions, access the debt markets to finance our funding requirements. Our cash from operations and ability to access debt markets could be affected by general economic, financial, competitive, legislative, regulatory, business and other factors, many of which are beyond our control.

We intend to continue to declare and pay quarterly dividends, with the goal of increasing the dividend over time, after giving consideration to our cash balances and expected results from operations. We believe that our cash on hand, cash from operating activities and proceeds from our credit facilities provide us with sufficient financial resources to meet our anticipated capital requirements and obligations as they come due.

Contractual and Other Obligations—The following table summarizes, as of December 31, 2013, our minimum payments for long-term debt, including current maturities, short-term debt, and contractual and other obligations for the next five years and thereafter.

 

          Payments Due By Period  

Millions of dollars

  Total     2014     2015     2016     2017     2018     Thereafter  

Total debt

  $ 5,867     $ 59     $ 1     $ 5     $ 2     $ —       $ 5,800  

Interest on total debt

    3,408       311       311       311       311       311       1,853  

Advances from customers

    183       107       19       12       12       6       27  

Other

    1,888       1,166       151       127       121       32       291  

Deferred income taxes

    1,659       141       165       193       149       147       864  

Other obligations:

             

Purchase obligations:

             

Take-or-pay contracts

    15,183       2,355       2,213       1,746       1,753       1,659       5,457   

Other contracts

    26,313       6,356       5,021       3,829       3,739       2,835       4,533    

Operating leases

    1,827       305       267       228       187       163       677   
 

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Total

  $ 56,328     $ 10,800     $ 8,148     $ 6,451     $ 6,274     $ 5,153     $ 19,502   
 

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

 

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Total Debt—Total debt includes our 5% senior notes due 2019, our 6% senior notes due 2021, our 4% guaranteed notes due 2023, our 5.75% senior notes due 2024, our 8.1% guaranteed notes due 2027, our 5.25% guaranteed notes due 2043 and various other U.S. and non-U.S. loans. See Note 12 for a discussion of covenant requirements under the credit facilities and indentures and additional information regarding our debt facilities.

Interest on Total Debt—Our debt and related party debt agreements contain provisions for the payment of monthly, quarterly or semi-annual interest at a stated rate of interest over the term of the debt.

Pension and other Postretirement Benefits—We maintain several defined benefit pension plans, as described in Note 16 to the Consolidated Financial Statements. Many of our U.S. and non-U.S. plans are subject to minimum funding requirements; however, the amounts of required future contributions for all our plans are not fixed and can vary significantly due to changes in economic assumptions, liability experience and investment return on plan assets. As a result, we have excluded pension and other postretirement benefit obligations from the Contractual and Other Obligations table above. Our annual contributions may include amounts in excess of minimum required funding levels. Contributions to our non-U.S. plans in years beyond 2014 are not expected to be materially different than the expected 2014 contributions disclosed in Note 16 to the Consolidated Financial Statements. At December 31, 2013, the projected benefit obligation for our pension plans exceeded the fair value of plan assets by $668 million. Subject to future actuarial gains and losses, as well as actual asset earnings, we, together with our consolidated subsidiaries, will be required to fund the $668 million, with interest, in future years. We contributed $172 million, $180 million and $526 million to our pension plans in 2013, 2012 and 2011, respectively. We provide other postretirement benefits, primarily medical benefits to eligible participants, as described in Note 16 to the Consolidated Financial Statements. We pay other unfunded postretirement benefits as incurred.

Advances from Customers—We are obligated to deliver products in connection with long-term sales agreements under which advances from customers were received in prior years. These advances are treated as deferred revenue and will be amortized to earnings as product is delivered over the remaining terms of the respective contracts, which primarily range from 4 to 8 years. The unamortized long-term portion of such advances totaled $76 million as of December 31, 2013.

Other—Other primarily consists of accruals for environmental remediation costs, obligations under deferred compensation arrangements, and anticipated asset retirement obligations. See “Critical Accounting Policies” below for a discussion of obligations for environmental remediation costs.

Deferred Income Taxes—The scheduled settlement of the deferred tax liabilities shown in the table is based on the scheduled reversal of the underlying temporary differences. Actual cash tax payments will vary depending upon future taxable income.

Purchase Obligations—We are party to various obligations to purchase products and services, principally for raw materials, utilities and industrial gases. These commitments are designed to assure sources of supply and are not expected to be in excess of normal requirements. The commitments are segregated into take-or-pay contracts and other contracts. Under the take-or-pay contracts, we are obligated to make minimum payments whether or not we take the product or service. Other contracts include contracts that specify minimum quantities; however, in the event that we do not take the contractual minimum, we are only obligated for any resulting economic loss suffered by the vendor. The payments shown for the other contracts assume that minimum quantities are purchased. For contracts with variable pricing terms, the minimum payments reflect the contract price at December 31, 2013.

Operating Leases—We lease various facilities and equipment under noncancelable lease arrangements for various periods. See Note 13 to the Consolidated Financial Statements for related lease disclosures.

 

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CURRENT BUSINESS OUTLOOK

We believe the fundamentals underlying our businesses remain the same. The U.S. natural gas liquids advantage continues to evolve in a very positive way, and we are executing our growth projects to take advantage of these market opportunities. We believe olefins in North America will continue to benefit from strong margins derived from cost-advantaged NGLs. Weather-related increases in natural gas and NGL prices are being seen in the first quarter of 2014, which we believe are temporary. We will commence an olefins turnaround at our LaPorte, Texas facility late in the first quarter which will extend into the second quarter. We expect European olefin and polyolefin demand to improve in the first quarter 2014 from the seasonally-low levels seen in the fourth quarter of 2013.

Our I&D segment continues to realize solid, steady performance and will additionally benefit from the start up of our methanol plant in Channelview, Texas. The global refining market has been volatile, but improving of late. We expect our refining position to strengthen in 2014 as North American crude production grows and the delivery infrastructure expands.

RELATED PARTY TRANSACTIONS

We have related party transactions with certain of our major shareholders and their affiliates and our joint venture partners. We believe that such transactions are effected on terms substantially no more or less favorable than those that would have been agreed upon by unrelated parties on an arm’s length basis. See Note 4 to the Consolidated Financial Statements for additional related party disclosures.

CRITICAL ACCOUNTING POLICIES

Management applies those accounting policies that it believes best reflect the underlying business and economic events, consistent with accounting principles generally accepted in the U.S. (see Note 2 to the Consolidated Financial Statements). Our more critical accounting policies include those related to the valuation of inventory, long-lived assets, the valuation of goodwill, accruals for long-term employee benefit costs such as pension and other postretirement costs, and accruals for taxes based on income. Inherent in such policies are certain key assumptions and estimates made by management. Management periodically updates its estimates used in the preparation of the financial statements based on its latest assessment of the current and projected business and general economic environment.

Inventory—We account for our inventory using the last-in, first-out (“LIFO”) method of accounting.

The cost of raw materials, which represents a substantial portion of our operating expenses, and energy costs generally follow price trends for crude oil and/or natural gas. Crude oil and natural gas prices are subject to many factors, including changes in economic conditions. Fluctuation in the prices of crude oil and natural gas from period to period may result in the recognition of charges to adjust the value of inventory to the lower of cost or market in periods of falling prices and the reversal of those charges in subsequent interim periods as market prices recover. Accordingly, our cost of sales and results of operations may be affected by such fluctuations.

A $71 million charge to adjust the value of inventory to the lower of cost or market at June 30, 2012 was reversed in the third quarter of 2012 reflecting the recovery of market price as of September 30, 2012. No lower of cost or market charges were required in 2011.

Long-Lived Assets—With respect to long-lived assets, which primarily include property, plant and equipment and intangible assets, key assumptions included estimates of useful lives and the recoverability of carrying values of fixed assets and other intangible assets, as well as the existence of any obligations associated with the retirement of fixed assets. Such estimates could be significantly modified and/or the carrying values of the assets could be impaired by such factors as new technological developments, new chemical industry entrants with significant raw material or other cost advantages, uncertainties associated with the European, U.S. and other world economies, the cyclical nature of the chemical and refining industries, and uncertainties associated with regulatory governmental actions.

 

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When events or changes in circumstances indicate that the carrying value of an asset may not be recoverable, we evaluate definite lived intangible assets for impairment. Long-lived assets are grouped at the lowest level for which there are identifiable cash flows that are largely independent of the cash flows of other groups of assets, which for us is generally at the plant group level (or, at times individual plants in certain circumstances where we have isolated production units with separately identifiable cash flows). When it is probable that the undiscounted cash flows of a tangible asset or asset group will not be sufficient to recover the carrying amount, the asset is written down to its estimated fair value. In-process research and development projects are impaired when abandoned.

During the years ended December 31, 2012 and 2011, we recognized impairments of $22 million and $19 million, respectively, related to damage sustained by our LDPE plant in Wesseling, Germany and an abandoned in-process research and development project.

The estimated useful lives of long-lived assets range from 3 to 30 years. Depreciation and amortization of these assets, including amortization of capitalized turnaround costs, under the straight-line method over their estimated useful lives totaled $1,021 million in 2013. If the useful lives of assets are found to be shorter than originally estimated, depreciation and amortization charges would be accelerated over the revised useful life.

Goodwill—Goodwill of $605 million at December 31, 2013 represents the tax effect of the differences between the tax and book bases of the our assets and liabilities resulting from the revaluation of those assets and liabilities to fair value in connection with the Company’s emergence from bankruptcy and adoption of fresh-start accounting. We evaluate the recoverability of the carrying value of goodwill annually or more frequently if events or changes in circumstances indicate that the carrying amount of the goodwill of a reporting unit may not be fully recoverable.

We first assess qualitative factors to determine whether it is more likely than not that the fair value of a reporting unit is less than its carrying value. Qualitative factors assessed for each of the reporting units include, but are not limited to, changes in long-term commodity prices, discount rates, competitive environments, planned capacity, cost factors such as raw material prices, and financial performance of the reporting units. If the qualitative assessment indicates that it is more likely than not that the carrying value of a reporting unit exceeds its estimated fair value, a two-step quantitative test is required.

For 2013, 2012 and 2011, our qualitative assessment indicated that the fair value of our reporting units was greater than their carrying value. Accordingly, a quantitative two-step goodwill impairment test was not required.

Long-Term Employee Benefit Costs—Our costs for long-term employee benefits, particularly pension and other postretirement medical and life insurance benefits, are incurred over long periods of time, and involve many uncertainties over those periods. The net periodic benefit cost attributable to current periods is based on several assumptions about such future uncertainties, and is sensitive to changes in those assumptions. It is management’s responsibility, often with the assistance of independent experts, to select assumptions that in its judgment represent its best estimates of the future effects of those uncertainties. It also is management’s responsibility to review those assumptions periodically to reflect changes in economic or other factors that affect those assumptions.

The current benefit service costs, as well as the existing liabilities, for pensions and other postretirement benefits are measured on a discounted present value basis. The discount rate is a current rate, related to the rate at which the liabilities could be settled. Our assumed discount rate is based on yield information for high-quality corporate bonds with durations comparable to the expected cash settlement of our obligations. For the purpose of measuring the benefit obligations at December 31, 2013, we used a weighted average discount rate of 4.73% for the U.S. plans which reflects the different terms of the related benefit obligations. The weighted average discount rate used to measure obligations for non-U.S. plans at December 31, 2013 was 3.78%, reflecting market interest rates. The discount rates in effect at December 31, 2013 will be used to measure net periodic benefit cost during 2014.

 

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The benefit obligation and the periodic cost of other postretirement medical benefits are also measured based on assumed rates of future increase in the per capita cost of covered health care benefits. As of December 31, 2013, the assumed rate of increase for our U.S. plans was 7.6%, decreasing to 4.5% in 2027 and thereafter. A one percentage point change in the health care cost trend rate assumption would have no significant effect on either the benefit liability or the net periodic cost, due to limits on our maximum contribution level under the medical plan.

The net periodic cost of pension benefits included in expense also is affected by the expected long-term rate of return on plan assets assumption. Investment returns that are recognized currently in net income represent the expected long-term rate of return on plan assets applied to a market-related value of plan assets which, for us, is defined as the market value of assets. The expected rate of return on plan assets is a longer term rate, and is expected to change less frequently than the current assumed discount rate, reflecting long-term market expectations, rather than current fluctuations in market conditions.

The weighted average expected long-term rate of return on assets in our U.S. plans of 8.00% is based on the average level of earnings that our independent pension investment advisor had advised could be expected to be earned over time and 3.73%, for our non-U.S. plan assets is based on an expectation and asset allocation that varies by region. The asset allocations are summarized in Note 16 to the Consolidated Financial Statements. The actual returns in 2013 were a gain of 16.45% for U.S. plan assets and a gain of 1.39% for non- U.S. plan assets.

The actual rate of return on plan assets may differ from the expected rate due to the volatility normally experienced in capital markets. Management’s goal is to manage the investments over the long term to achieve optimal returns with an acceptable level of risk and volatility.

Net periodic pension cost recognized each year includes the expected asset earnings, rather than the actual earnings or loss. Along with other gains and losses, this unrecognized amount, to the extent it cumulatively exceeds 10% of the projected benefit obligation for the respective plan, is recognized as additional net periodic benefit cost over the average remaining service period of the participants in each plan.

The following table reflects the sensitivity of the benefit obligations and the net periodic benefit costs of our pension plans to changes in the actuarial assumptions:

 

     Effects on
benefit obligations
in 2013
    Effects on net
periodic pension costs
in 2014
 

Millions of dollars

   U.S.     Non-U.S.     U.S.     Non-U.S.  

Projected benefit obligations at December 31, 2013

   $ 1,932     $ 1,362     $ —       $ —    

Projected net periodic pension costs in 2014

         (24     62  

Discount rate increases by 100 basis points

     (179     (154     2       (5

Discount rate decreases by 100 basis points

     217       199       —         13  

The sensitivity of our postretirement benefit plans obligations and net periodic benefit costs to changes in actuarial assumptions are reflected in the following table:

     Effects on
benefit obligations
in 2013
     Effects on net
periodic benefit costs
in 2014
 

Millions of dollars

   U.S.     Non-U.S.      U.S.      Non-U.S.  

Projected benefit obligations at December 31, 2013

   $ 310     $ 41      $ —        $ —    

Projected net periodic benefit costs in 2014

          18        3  

Discount rate increases by 100 basis points

     (28     —          1        —    

Discount rate decreases by 100 basis points

     33       —          1        —    

 

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Additional information on the key assumptions underlying these benefit costs appears in Note 16 to the Consolidated Financial Statements.

Accruals for Taxes Based on Income—The determination of our provision for income taxes and the calculation of our tax benefits and liabilities is subject to management’s estimates and judgments due to the complexity of the tax laws and regulations in the tax jurisdictions in which we operate. Uncertainties exist with respect to interpretation of these complex laws and regulations.

Deferred tax assets and liabilities are determined based on temporary differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases, and are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to reverse.

We recognize future tax benefits to the extent that the realization of these benefits is more likely than not. Our current provision for income taxes is impacted by the recognition and release of valuation allowances related to net deferred assets in certain non-U.S. jurisdictions. Further changes to these valuation allowances may impact our future provision for income taxes, which will include no tax benefit with respect to losses incurred and no tax expense with respect to income generated in these countries until the respective valuation allowance is eliminated.

We recognize the financial statement benefits with respect to an uncertain income tax position that we have taken or may take on an income tax return when it is more likely than not that the position will be sustained with the tax authorities. For a position that is likely to be sustained, the benefit recognized in the financial statements is measured at the largest amount that is greater than 50 percent likely of being realized.

For further information related to our income taxes, see Note 18 to the Consolidated Financial Statements of LyondellBasell N.V. for the year ended December 31, 2013.

ACCOUNTING AND REPORTING CHANGES

For a discussion of the potential impact of new accounting pronouncements on our consolidated financial statements, see Note 2 to the Consolidated Financial Statements.

Item 7A. Quantitative and Qualitative Disclosures About Market Risk.

See Note 14 to the Consolidated Financial Statements for discussion of LyondellBasell Industries N.V.’s management of commodity price risk, foreign currency exposure and interest rate risk through its use of derivative instruments and hedging activities.

Commodity Price Risk

A substantial portion of our products and raw materials are commodities whose prices fluctuate as market supply and demand fundamentals change. Accordingly, product margins and the level of our profitability tend to fluctuate with changes in the business cycle. We try to protect against such instability through various business strategies. These include provisions in sales contracts allowing us to pass on higher raw material costs through timely price increases, formula price contracts to transfer or share commodity price risk, and increasing the depth and breadth of our product portfolio.

In addition, we selectively use commodity swap, option, and futures contracts with various terms to manage the volatility related to purchases of natural gas and raw materials, as well as product sales. Such contracts are generally limited to durations of one year or less. Hedge accounting has not been elected for any of our commodity contracts in any of the periods presented. Market risks created by these derivative instruments and the mark-to-market valuations of open positions are monitored by management.

 

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The estimated fair value and notional amounts of our open commodity futures contracts are shown in the table below:

 

     Open Commodity Contracts
     December 31, 2013
           Notional Amounts            
Millions of dollars    Fair Value     Value      Volumes     

Volume Unit

  

Maturity Dates

Futures:

             

Gasoline

   $ (4   $ 257        92      million gallons   

February 2014 -

March 2014

Heating oil

     —         11        4      million gallons    February 2014

Crude oil

     —         378        158      million gallons   

February 2014 -

May 2014

  

 

 

   

 

 

          
   $ (4   $ 646           
  

 

 

   

 

 

          
     December 31, 2012
           Notional Amounts            

Millions of dollars

   Fair Value     Value      Volumes     

Volume Unit

  

Maturity Dates

Futures:

             

Gasoline

   $ (7   $ 56        20      million gallons   

January 2013 -

February 2013

Heating oil

     —         38        13      million gallons    January 2013

Butane

     5       25        14      million gallons   

January 2013 -

February 2013

Crude oil

     1       110        47      million gallons   

February 2013 -

March 2013

  

 

 

   

 

 

          
   $ (1   $ 229           
  

 

 

   

 

 

          

The increased level in open futures positions in 2013 is related to our strategies to manage the impact of future movements in the price of gasoline and crude oil on our product margins and the price differential between varying grades of crude oil.

We use value at risk (“VAR”), stress testing and scenario analysis for risk measurement and control purposes.

VAR estimates the maximum potential loss in fair market values, given a certain move in prices over a certain period of time, using specified confidence levels.

Using sensitivity analysis and hypothetical changes in market prices ranging from 6% to 14%, which represents a three month volatility range of the underlying products, the effect on our pretax income would be $9 million. The quantitative information about market risk is necessarily limited because it does not take into account the effects of the underlying operating transactions.

Foreign Exchange Risk

We manufacture and market our products in a number of countries throughout the world and, as a result, are exposed to changes in foreign currency exchange rates. We enter into transactions in currencies other than the applicable functional currency.

A significant portion of our reporting entities use the euro as their functional currency. Our reporting currency is the U.S. dollar. The translation gains or losses that result from the process of translating the euro

 

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denominated financial statements to U.S. dollars are deferred in accumulated other comprehensive income (“AOCI”) until such time as those entities may be liquidated or sold. Changes in the value of the U.S. dollar relative to the euro can therefore have a significant impact on comprehensive income. We generally do not attempt to minimize or mitigate the foreign currency risks resulting from the translation of assets and liabilities of non-U.S. operations into our reporting currency.

Some of our operations enter into transactions denominated in other than their functional currency. This results in exposure to foreign currency risk for financial instruments, including, but not limited to third party and intercompany receivables and payables and intercompany loans.

We maintain risk management control practices to monitor the foreign currency risk attributable to our inter-company and third party outstanding foreign currency balances. These practices involve the centralization of our exposure to underlying currencies that are not subject to central bank and/or country specific restrictions. By centralizing most of our foreign currency exposure into one subsidiary, we are able to take advantage of any natural offsets thereby reducing the overall impact of changes in foreign currency rates on our earnings.

Our policy is to maintain an approximately balanced position in foreign currencies to minimize exchange gains and losses arising from changes in exchange rates. To minimize the effects of our net currency exchange exposures, we enter into foreign currency spot and forward contracts. Our net position in foreign currencies is monitored daily.

At December 31, 2013 and 2012, a 10% fluctuation compared to the U.S. dollar in the underlying currencies that have no central bank or other currency restrictions would result in an additional impact to earnings of no more than approximately $2 million and $3 million, respectively.

We also engage in short-term foreign exchange swaps in order to roll certain hedge positions and to make funds available for intercompany financing.

For 2013, 2012, and 2011, Other income (expense), net in the Consolidated Statements of Income reflected losses of $4 million, $21 million and $17 million, respectively, in net exchange rate gains and losses. For forward contracts, including swap transactions, that economically hedge recognized monetary assets and liabilities in foreign currencies, no hedge accounting is applied. Changes in the fair value of foreign currency forward contracts are reported in the Consolidated Statements of Income and offset the currency exchange results recognized on the assets and liabilities.

Interest Rate Risk

We are exposed to interest rate risk with respect to variable rate debt. Our variable rate debt consists of our $2,000 million Senior Revolving Credit Facility, our $1,000 million U.S. Receivables Securitization Facility and our €450 million European Receivables Securitization Facility. At December 31, 2013, there were no outstanding borrowings under these facilities.

 

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Item 8. Financial Statements and Supplementary Data.

Index to the Consolidated Financial Statements

 

                          
     Page  

LYONDELLBASELL INDUSTRIES N.V.

  

Management’s Report On Internal Control Over Financial Reporting

     66   

Reports of Independent Registered Public Accounting Firm

     67   

Consolidated Financial Statements:

  

Consolidated Statements of Income

     68   

Consolidated Statements of Comprehensive Income

     69   

Consolidated Balance Sheets

     70   

Consolidated Statements of Cash Flows

     72   

Consolidated Statements of Stockholders’ Equity

     74   

Notes to the Consolidated Financial Statements

     75   

 

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MANAGEMENT’S REPORT ON INTERNAL CONTROL

OVER FINANCIAL REPORTING

Management of the Company, including the Chief Executive Officer and the Chief Financial Officer, is responsible for establishing and maintaining adequate internal control over financial reporting, as defined in Rules 13a-15(f) and 15d-15(f) of the Securities Exchange Act of 1934, as amended. Internal control over financial reporting is a process designed by, or under the supervision of, our Chief Executive Officer and Chief Financial Officer, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. Our internal control over financial reporting includes those policies and procedures that (i) pertain to the maintenance of records that in reasonable detail accurately and fairly reflect the transactions and dispositions of our assets; (ii) provide reasonable assurance that transactions are recorded as necessary to permit the preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures are being made only in accordance with authorizations of our management and directors; and (iii) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use or disposition of our assets that could have a material effect on the financial statements.

We conducted an evaluation of the effectiveness of our internal control over financial reporting as of December 31, 2013 based on the Internal Control—Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission in 1992. Based on our evaluation, management has concluded that our internal control over financial reporting was effective as of December 31, 2013.

The effectiveness of our internal control over financial reporting as of December 31, 2013 has been audited by PricewaterhouseCoopers LLP, an independent registered public accounting firm, as stated in their report which is included herein.

 

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REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Stockholders of LyondellBasell Industries N.V.

In our opinion, the accompanying consolidated balance sheets and the related consolidated statements of income, of comprehensive income, of stockholders’ equity and of cash flows present fairly, in all material respects, the financial position of LyondellBasell Industries N.V. and its subsidiaries at December 31, 2013 and December 31, 2012 and the results of their operations and their cash flows for each of the three years in the period ended December 31, 2013 in conformity with accounting principles generally accepted in the United States of America. Also in our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2013, based on criteria established in Internal Control—Integrated Framework (1992) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). The Company’s management is responsible for these financial statements, 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 opinions on these financial statements and on the Company’s internal control over financial reporting based on our integrated 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 audits to obtain reasonable assurance about whether the financial statements are free of material misstatement and whether effective internal control over financial reporting was maintained in all material respects. Our audits of the financial statements included examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, and evaluating the overall financial statement presentation. Our audit of internal control over financial reporting included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and operating effectiveness of internal control based on the assessed risk. Our audits also included performing such other procedures as we considered necessary in the circumstances. We believe that our audits provide a reasonable basis for our opinions.

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 (i) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (ii) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (iii) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’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.

/s/ PricewaterhouseCoopers LLP

Houston, Texas

February 20, 2014

 

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LYONDELLBASELL INDUSTRIES N.V.

CONSOLIDATED STATEMENTS OF INCOME

 

     Year Ended December 31,  

Millions of dollars, except earnings per share

   2013     2012     2011  

Sales and other operating revenues:

      

Trade

   $ 43,052     $ 44,315     $ 47,067  

Related parties

     1,010       1,037       1,116  
  

 

 

   

 

 

   

 

 

 
     44,062       45,352       48,183  

Operating costs and expenses:

      

Cost of sales

     37,940       39,595       42,732  

Selling, general and administrative expenses

     870       909       918  

Research and development expenses

     150       172       196  
  

 

 

   

 

 

   

 

 

 
     38,960       40,676       43,846  

Operating income

     5,102       4,676        4,337   

Interest expense

     (309     (655     (1,044

Interest income

     15       15        37   

Other income (expense), net

     (14     2        30   
  

 

 

   

 

 

   

 

 

 

Income from continuing operations before equity investments, reorganization items and income taxes

     4,794        4,038        3,360   

Income from equity investments

     203        143        216   

Reorganization items

     (1     4        (45
  

 

 

   

 

 

   

 

 

 

Income from continuing operations before income taxes

     4,996        4,185        3,531   

Provision for income taxes

     1,136        1,327        1,059   
  

 

 

   

 

 

   

 

 

 

Income from continuing operations

     3,860        2,858        2,472   

Loss from discontinued operations, net of tax

     (7     (24     (332
  

 

 

   

 

 

   

 

 

 

Net income

     3,853        2,834        2,140   

Net loss attributable to non-controlling interests

     4        14        7   
  

 

 

   

 

 

   

 

 

 

Net income attributable to the Company shareholders

   $ 3,857      $ 2,848      $ 2,147   
  

 

 

   

 

 

   

 

 

 

Earnings (loss) per share:

      

Net income (loss) attributable to the Company shareholders —

      

Basic:

      

Continuing operations

   $ 6.81      $ 5.01      $ 4.34   

Discontinued operations

     (0.01     (0.04     (0.58
  

 

 

   

 

 

   

 

 

 
   $ 6.80      $ 4.97      $ 3.76   
  

 

 

   

 

 

   

 

 

 

Diluted:

      

Continuing operations

   $ 6.76      $ 4.96      $ 4.32   

Discontinued operations

     (0.01     (0.04     (0.58
  

 

 

   

 

 

   

 

 

 
   $ 6.75      $ 4.92      $ 3.74   
  

 

 

   

 

 

   

 

 

 

See Notes to the Consolidated Financial Statements.

 

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LYONDELLBASELL INDUSTRIES N.V.

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

 

     Year Ended December 31,  

Millions of dollars

   2013     2012     2011  

Net income

   $ 3,853     $ 2,834     $ 2,140  

Other comprehensive income, net of tax –

      

Defined pension and other postretirement benefit plans:

      

Prior service cost arising during the period

     (21     12       (16

Reclassification adjustment for amortization of prior service cost included in net income

     14       3       —    

Net actuarial gain (loss) arising during the period

     411       (198     (388

Reclassification adjustment for net actuarial loss included in net income

     30       24       —    

Reclassification adjustment for settlement (gain) loss included in net income

     (3     —         6  
  

 

 

   

 

 

   

 

 

 

Defined pension and other postretirement benefit plans, before tax

     431       (159     (398

Income tax expense (benefit)

     149       (38     (128
  

 

 

   

 

 

   

 

 

 

Defined pension and other postretirement benefit plans, net of tax

     282       (121     (270
  

 

 

   

 

 

   

 

 

 

Foreign currency translations adjustments:

      

Unrealized net change arising during the period

     217       136       (237

Reclassification adjustment included in net income

     4       —         —    
  

 

 

   

 

 

   

 

 

 

Foreign currency translations adjustments, before tax

     221        136        (237

Income tax expense (benefit)

     (4     (1     1   
  

 

 

   

 

 

   

 

 

 

Foreign currency translations, net of tax

     225        137        (238
  

 

 

   

 

 

   

 

 

 

Total other comprehensive income (loss)

     507        16        (508
  

 

 

   

 

 

   

 

 

 

Comprehensive income

     4,360        2,850        1,632   

Comprehensive loss attributable to non-controlling interests

     4        14        7   
  

 

 

   

 

 

   

 

 

 

Comprehensive income attributable to the Company shareholders

   $ 4,364      $ 2,864      $ 1,639   
  

 

 

   

 

 

   

 

 

 

See Notes to the Consolidated Financial Statements.

 

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LYONDELLBASELL INDUSTRIES N.V.

CONSOLIDATED BALANCE SHEETS

 

     December 31,  

Millions of dollars

   2013      2012  

ASSETS

     

Current assets:

     

Cash and cash equivalents

   $ 4,450       $ 2,732   

Restricted cash

     10         5   

Accounts receivable:

     

Trade, net

     3,828         3,720   

Related parties

     202         184   

Inventories

     5,279         5,075   

Prepaid expenses and other current assets

     830         570   
  

 

 

    

 

 

 

Total current assets

     14,599         12,286   

Property, plant and equipment, net

     8,457         7,696   

Investments and long-term receivables:

     

Investment in PO joint ventures

     421         397   

Equity investments

     1,629         1,583   

Other investments and long-term receivables

     64         383   

Goodwill

     605         591   

Intangible assets, net

     904         1,038   

Other assets

     619         246   
  

 

 

    

 

 

 

Total assets

   $ 27,298       $ 24,220   
  

 

 

    

 

 

 

See Notes to the Consolidated Financial Statements.

 

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LYONDELLBASELL INDUSTRIES N.V.

CONSOLIDATED BALANCE SHEETS

 

      December 31,  

Millions of dollars, except shares and par value data

   2013     2012  

LIABILITIES AND EQUITY

    

Current liabilities:

    

Current maturities of long-term debt

   $ 1      $ 1   

Short-term debt

     58        95   

Accounts payable:

    

Trade

     2,822        2,440   

Related parties

     750        845   

Accrued liabilities

     1,299        1,157   

Deferred income taxes

     580        558   
  

 

 

   

 

 

 

Total current liabilities

     5,510        5,096   

Long-term debt

     5,776        4,304   

Other liabilities

     1,839        2,327   

Deferred income taxes

     1,659        1,314   

Commitments and contingencies

    

Stockholders’ equity:

    

Ordinary shares, €0.04 par value, 1,275 million shares authorized, 548,824,138 and 575,216,709 shares outstanding, respectively

     31        31   

Additional paid-in capital

     10,382        10,351   

Retained earnings

     4,004        1,274   

Accumulated other comprehensive income (loss)

     96        (411

Treasury stock, at cost, 29,607,877 and 3,206,033 ordinary shares, respectively

     (2,035     (106
  

 

 

   

 

 

 

Total Company share of stockholders’ equity

     12,478        11,139   

Non-controlling interests

     36        40   
  

 

 

   

 

 

 

Total equity

     12,514        11,179   
  

 

 

   

 

 

 

Total liabilities and equity

   $ 27,298      $ 24,220   
  

 

 

   

 

 

 

See Notes to the Consolidated Financial Statements.

 

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LYONDELLBASELL INDUSTRIES N.V.

CONSOLIDATED STATEMENTS OF CASH FLOWS

 

     Year Ended December 31,  

Millions of dollars

   2013     2012     2011  

Cash flows from operating activities:

      

Net income

   $ 3,853      $ 2,834      $ 2,140   

Adjustments to reconcile net income to net cash provided by operating activities:

      

Depreciation and amortization

     1,021        983        931   

Asset impairments

     —          22        52   

Amortization of debt-related costs

     21        58        61   

Equity investments –

      

Equity income

     (203     (143     (216

Distribution of earnings, net of tax

     186        147        206   

Deferred income taxes

     (46     715        452   

Reorganization items

     1        (4     45   

Reorganization-related payments, net

     —          —          (112

(Gain) loss on sale of assets

     16        (12     (42

Changes in assets and liabilities that provided (used) cash:

      

Accounts receivable

     (64     (101     (89

Inventories

     (151     441        (732

Accounts payable

     275        (189     703  

Contributions to pension plans

     (172     (180     (526

Income tax refunds

     10        306        7   

Prepaid expenses and other current assets

     (165     (98     (23

Other, net

     253        8        3   
  

 

 

   

 

 

   

 

 

 

Net cash provided by operating activities

     4,835        4,787        2,860   
  

 

 

   

 

 

   

 

 

 

Cash flows from investing activities:

      

Expenditures for property, plant and equipment

     (1,561     (1,060     (1,050

Proceeds from disposal of assets

     5        12        71   

Restricted cash

     (5     48        (42

Other

     (41     (13     —     
  

 

 

   

 

 

   

 

 

 

Net cash used in investing activities

     (1,602     (1,013     (1,021
  

 

 

   

 

 

   

 

 

 

See Notes to the Consolidated Financial Statements.

 

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LYONDELLBASELL INDUSTRIES N.V.

CONSOLIDATED STATEMENTS OF CASH FLOWS—Continued

 

     Year Ended December 31,  

Millions of dollars

   2013     2012     2011  

Cash flows from financing activities:

      

Repurchases of Company ordinary shares

     (1,949     —          —     

Dividends paid

     (1,127     (2,415     (2,893

Issuance of long-term debt

     1,472        3,000        1,000   

Repayments of long-term debt

     —          (2,679     (3,063

Payments of debt issuance costs

     (23     (53     (35

Other, net

     38        2        36   
  

 

 

   

 

 

   

 

 

 

Net cash used in financing activities

     (1,589     (2,145     (4,955
  

 

 

   

 

 

   

 

 

 

Effect of exchange rate changes on cash

     74        38        (41
  

 

 

   

 

 

   

 

 

 

Increase (decrease) in cash and cash equivalents

     1,718        1,667        (3,157

Cash and cash equivalents at beginning of period

     2,732        1,065        4,222   
  

 

 

   

 

 

   

 

 

 

Cash and cash equivalents at end of period

   $ 4,450      $ 2,732      $ 1,065   
  

 

 

   

 

 

   

 

 

 

Supplemental Cash Flow Information:

      

Interest paid

   $ 266      $ 665      $ 1,066   
  

 

 

   

 

 

   

 

 

 

Net income taxes paid

   $ 1,213      $ 261      $ 662   
  

 

 

   

 

 

   

 

 

 

See Notes to the Consolidated Financial Statements.

 

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Table of Contents

LYONDELLBASELL INDUSTRIES N.V.

CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY

 

                            Accumulated              
                Additional           Other     Total     Non-  
    Ordinary Shares     Paid-in     Retained     Comprehensive     Stockholders’     Controlling  

Millions of dollars

  Issued     Treasury     Capital     Earnings     Income (Loss)     Equity     Interests  

Balance, December 31, 2010

  $ 30      $ —       $ 9,837      $ 1,587      $ 81      $ 11,535      $ 61   

Net income (loss)

    —         —          —          2,147        —          2,147        (7)   

Other comprehensive loss

    —          —          —          —          (508)        (508)        —     

Warrants exercised

    1        —          402        —          —          403        —     

Share-based compensation

    —          9        33        —          —          42        —     

Special dividend ($4.50 per share)

    —          —          —          (2,580)        —          (2,580)        —     

Dividends ($0.55 per share)

    —          —          —          (313)        —          (313)        —     

Repurchases of Company ordinary shares

    —          (133)        —          —          —          (133)        —     
 

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Balance, December 31, 2011

  $ 31      $ (124)      $ 10,272      $ 841      $ (427)      $ 10,593      $ 54   

Net income (loss)

    —          —          —          2,848        —          2,848        (14)   

Other comprehensive income

    —          —          —          —          16        16        —     

Warrants exercised

    —          —          43        —          —          43        —     

Share-based compensation

    —          31        36        —          —          67        —     

Special dividend ($2.75 per share)

    —          —          —          (1,582)        —          (1,582)        —     

Dividends ($1.45 per share)

    —          —          —          (833)        —          (833)        —     

Repurchases of Company ordinary shares

    —          (13)        —          —          —          (13)        —     
 

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Balance, December 31, 2012

  $ 31      $ (106)      $ 10,351      $ 1,274      $ (411)      $ 11,139      $ 40   

Net income (loss)

    —          —          —          3,857        —          3,857        (4)   

Other comprehensive income

    —          —          —          —          507        507        —     

Share-based compensation

    —          20        31        —          —          51        —     

Dividends ($2.00 per share)

    —          —          —          (1,127)        —          (1,127)        —     

Repurchases of Company ordinary shares

    —          (1,949)        —          —          —          (1,949)        —     
 

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Balance, December 31, 2013

  $ 31      $ (2,035)      $ 10,382      $ 4,004      $ 96      $ 12,478      $ 36   
 

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

See Notes to the Consolidated Financial Statements.

 

74


Table of Contents

LYONDELLBASELL INDUSTRIES N.V.

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

TABLE OF CONTENTS

 

         Page  
1.  

Description of Company and Operations

     76   
2.  

Summary of Significant Accounting Policies

     76   
3.  

Discontinued Operations and Related Items

     82   
4.  

Related Party Transactions

     84   
5.  

Accounts Receivable

     85   
6.  

Inventories

     85   
7.  

Property, Plant and Equipment, Goodwill and Intangible Assets

     86   
8.  

Investment in PO Joint Ventures

     87   
9.  

Equity Investments

     88   
10.  

Prepaid Expenses and Other Current Assets and Other Assets

     90   
11.  

Accrued Liabilities

     91   
12.  

Debt

     91   
13.  

Lease Commitments

     94   
14.  

Financial Instruments

     94   
15.  

Fair Value Measurement

     97   
16.  

Pension and Other Post-retirement Benefits

     99