10-K

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-K

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

For the fiscal year ended December 31, 2011

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 001-34028

AMERICAN WATER WORKS COMPANY, INC.

(Exact name of registrant as specified in its charter)

Delaware	51-0063696
(State or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification No.)
1025 Laurel Oak Road, Voorhees, NJ	08043
(Address of principal executive offices)	(Zip Code)

(856) 346-8200

(Registrant’s telephone number, including area code)

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

Title of each class	Name of each exchange on which registered
Common stock, par value $0.01 per share	New York Stock Exchange, Inc.

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

None.

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

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

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

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

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 “small reporting company” in Rule 12(b)-2 of the Exchange Act.:

Large accelerated filer	þ	Accelerated filer	¨
Non-accelerated filer	¨	Small reporting company	¨

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

State the aggregate market value of the voting and non-voting common equity held by non-affiliates computed by reference to the price at which the common equity was last sold, or the average bid and asked price of such common equity, as of the last business day of the registrant’s most recently completed second fiscal quarter.

Common Stock, $0.01 par value—$5,166,650,955 as of June 30, 2011.

Indicate the number of shares outstanding of each of the registrant’s classes of common stock as of the latest practicable date.

Common Stock, $0.01 par value per share—175,717,124 shares, as of February 21, 2012.

DOCUMENTS INCORPORATED BY REFERENCE

(1) Portions of the Company’s Proxy Statement for the Company’s 2012 Annual Meeting of Stockholders are incorporated by reference into Part III of this report.

TABLE OF CONTENTS

		Page
Forward-Looking Statements			1
Part I
Item 1.	Business		3
Item 1A.	Risk Factors		21
Item 1B.	Unresolved Staff Comments		35
Item 2.	Properties		35
Item 3.	Legal Proceedings		35
Item 4.	Mine Safety Disclosures		39
Part II
Item 5.	Market For Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities		40
Item 6.	Selected Financial Data		41
Item 7.	Management’s Discussion and Analysis of Financial Condition and Results of Operations		42
Item 7A.	Quantitative and Qualitative Disclosures About Market Risk		84
Item 8.	Financial Statements and Supplementary Data		86
Item 9.	Changes in and Disagreements with Accountants on Accounting and Financial Disclosure		136
Item 9A.	Controls and Procedures		136
Item 9B.	Other Information		137
Part III
Item 10.	Directors, Executive Officers and Corporate Governance		138
Item 11.	Executive Compensation		142
Item 12.	Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters		142
Item 13.	Certain Relationships and Related Transactions and Director Independence		142
Item 14.	Principal Accountant Fees and Services		142
Part IV
Item 15.	Exhibits and Financial Statement Schedules		142
Signatures			143
Exhibit Index			144

FORWARD-LOOKING STATEMENTS

We have made statements under the captions “Business,” “Risk Factors,” “Management’s Discussion and Analysis of Financial Condition and Results of Operations,” and in other sections of this Annual Report on Form 10-K (“Form 10-K”), or incorporated certain statements by reference into this Form 10-K, that are forward-looking statements within the meaning of Section 27A of the Securities Act of 1933 and the Private Securities Litigation Reform Act of 1995. In some cases, these forward-looking statements can be identified by words with prospective meanings such as “intend,” “plan,” “estimate,” “believe,” “anticipate,” “expect,” “predict,” “project,” “forecast,” “outlook,” “future,” “potential,” “continue,” “may,” “can,” “should” and “could” and similar expressions. Forward-looking statements may relate to, among other things, our future financial performance, including our operations and maintenance (“O&M”) efficiency ratio, our growth and portfolio optimization strategies, our projected capital expenditures and related funding requirements, our ability to repay debt, our ability to finance current operations and growth initiatives, the impact of legal proceedings and potential fines and penalties, business process and technology improvement initiatives, trends in our industry, regulatory or legal developments or rate adjustments, including rate case filings, filings for infrastructure surcharges and filings to address regulatory lag.

Forward-looking statements are predictions based on our current expectations and assumptions regarding future events. They are not guarantees of any outcomes, financial results or levels of performance and you are cautioned not to place undue reliance upon them. These forward-looking statements are subject to a number of risks and uncertainties, and new risks and uncertainties of which we are not currently aware or which we do not currently perceive may arise in the future from time to time. Should any of these risks or uncertainties materialize, or should any of our expectations or assumptions prove incorrect, then our results may vary materially from those discussed in the forward-looking statements herein. Factors that could cause actual results to differ from those discussed in forward-looking statements include, but are not limited to, the factors discussed under the caption “Risk Factors” and the following factors:

• the decisions of governmental and regulatory bodies, including decisions to raise or lower rates;

• the timeliness of regulatory commissions’ actions concerning rates;

• changes in customer demand for, and patterns of use of, water, such as may result from conservation efforts;

• changes in laws, governmental regulations and policies, including environmental, health and water quality and public utility regulations and policies;

• weather conditions, patterns or events, including drought or abnormally high rainfall;

• our ability to affect significant changes to our business processes and corresponding technology;

• our ability to appropriately maintain current infrastructure and manage expansion of our business;

• our ability to obtain permits and other approvals for projects;

• changes in our capital requirements;

• our ability to control operating expenses and to achieve efficiencies in our operations;

• our ability to obtain adequate and cost-effective supplies of chemicals, electricity, fuel, water and other raw materials that are needed for our operations;

• our ability to successfully acquire and integrate water and wastewater systems that are complementary to our operations and the growth of our business or dispose of assets or lines of business that are not complementary to our operations and the growth of our business;

• cost overruns relating to improvements or the expansion of our operations;

• changes in general economic, business and financial market conditions;

• access to sufficient capital on satisfactory terms;

• fluctuations in interest rates;

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• restrictive covenants in or changes to the credit ratings on our current or future debt that could increase our financing costs or affect our ability to borrow, make payments on debt or pay dividends;

• fluctuations in the value of benefit plan assets and liabilities that could increase our cost and funding requirements;

• our ability to utilize our U.S. and state net operating loss carryforwards;

• migration of customers into or out of our service territories;

• difficulty in obtaining insurance at acceptable rates and on acceptable terms and conditions;

• the incurrence of impairment charges;

• labor actions, including work stoppages;

• ability to retain and attract qualified employees; and

• civil disturbance, or terrorist threats or acts or public apprehension about future disturbances or terrorist threats or acts.

Any forward-looking statements we make, speak only as of the date of this Form 10-K. Except as required by law, we do not have any obligation, and we specifically disclaim any undertaking or intention, to publicly update or revise any forward-looking statements, whether as a result of new information, future events, changed circumstances or otherwise.

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PART I

ITEM 1. BUSINESS

Our Company

American Water Works Company, Inc., (the “Company”), a Delaware corporation, is the most geographically diversified, as well as the largest publicly-traded, United States water and wastewater utility company, as measured by both operating revenue and population served. As a holding company, we conduct substantially all of our business operations through our subsidiaries. Our approximately 7,000 employees provide an estimated 15 million people with drinking water, wastewater and other water-related services in over 30 states and two Canadian provinces.

In 2011, our on-going operations generated $2,666.2 million in total operating revenue and $803.1 million in operating income. In 2010, our on-going operations generated $2,555.0 million in total operating revenue and $728.1 million in operating income.

We have two operating segments that are also the Company’s two reportable segments: the Regulated Businesses and the Market-Based Operations. For further details on our segments, see Note 21 of the Consolidated Financial Statements.

For 2011, our Regulated Businesses segment generated $2,368.9 million in operating revenue, which accounted for 88.8% of our total consolidated operating revenue. For the same period, our Market-Based Operations segment generated $327.8 million in operating revenue, which accounted for 12.3% of total consolidated operating revenue.

For additional financial information, please see the financial statements and related notes thereto appearing elsewhere in this Form 10-K.

Our History as a Public Company

The Company was founded in 1886 as the American Water Works & Guarantee Company for the purposes of building and purchasing water systems in McKeesport, Pennsylvania. In 1935, the Company was reorganized under its current name, and in 1947 the common stock of the Company became publicly traded on the New York Stock Exchange (“NYSE”). In 2003, we were acquired by RWE Aktiengesellschaft, which we refer to as RWE, a stock corporation incorporated in the Federal Republic of Germany. On April 28, 2008, RWE Aqua Holdings GmbH, a German limited liability company and a direct wholly-owned subsidiary of RWE, which then was the sole owner of the Company’s common stock, completed a partial divestiture of its investment through an initial public offering (“IPO”). Subsequently, RWE continued to divest of its investment in our common stock through public offerings and on November 24, 2009, RWE completed the divestiture. As a result of the IPO, we again became listed on the NYSE under the symbol “AWK” and resumed our position as the largest publicly traded water utility company in the United States.

During 2011, we either sold or announced the sale of assets or stock of certain of our regulated and market based subsidiaries as outlined in “Our Regulated Businesses” and “Our Market-Based Operation” discussions below. As such, these subsidiaries have been presented as discontinued operations for all periods presented, and are not included in the discussions below unless otherwise noted. See Note 3 to Consolidated Financial Statements for further details on our discontinued operations.

Regulated Businesses Overview

Our primary business involves the ownership of subsidiaries that provide water and wastewater utility services to residential, commercial, industrial and other customers, including sale for resale and public authority customers. Our subsidiaries that provide these services are generally subject to economic regulation by certain

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state commissions or other entities engaged in economic regulation, hereafter referred to as “PUCs”, in the states in which they operate. The federal government and the states also regulate environmental, health and safety, and water quality matters. We report the results of our primary business in the Regulated Businesses segment.

As noted above, for 2011, operating revenue for our Regulated Businesses segment was $2,368.9 million, accounting for 88.8% of total consolidated operating revenue for the same period. Regulated Businesses segment operating revenues were $2,285.7 million for 2010 and $2,076.6 million for 2009, accounting for 89.5% and 90.7%, respectively, of total operating revenues for the same periods.

The following charts set forth operating revenue for 2011 and customers as of December 31, 2011, for the states in which our Regulated Businesses provide services:

Market-Based Operations Overview

We also provide services that are not subject to economic regulation by state PUCs through our Market-Based Operations. Our Market-Based Operations include three lines of business:

• Contract Operations Group, which enters into contracts to operate and maintain water and wastewater facilities mainly for the United States military, municipalities, and the food and beverage industry;

• Homeowner Services Group, which provides services to domestic homeowners and smaller commercial establishments to protect against the cost of repairing broken or leaking water pipes and clogged or blocked sewer pipes inside and outside their accommodations; and

• Terratec Environmental Ltd., which we refer to as Terratec, which primarily provides biosolids management, transport and disposal services to municipal and industrial customers.

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For 2011, operating revenue for our Market-Based Operations was $327.8 million, accounting for 12.3% of total operating revenue for the same period. The Market-Based Operations’ operating revenue was $294.7 million for 2010 and $238.2 million for 2009, accounting for 11.5% and 10.4%, respectively, of total operating revenues for the same periods.

Our Industry

Overview

The United States water and wastewater industry has two main sectors (i) utility ownership, which involves supplying water and wastewater services to consumers; and (ii) general services, which involves providing water and wastewater related services to water and wastewater utilities and other customers on a contract basis.

The utility sector includes investor-owned as well as municipal systems that are owned and operated by local governments or governmental subdivisions. The Environmental Protection Agency (“EPA”) estimates that government-owned systems make up the vast majority of the United States water and wastewater utility segment, accounting for approximately 84% of all United States community water systems and approximately 98% of all United States community wastewater systems. Investor-owned water and wastewater systems account for the remainder of the United States water and wastewater community water systems. Growth of service providers in the investor-owned regulated utility sector is achieved through organic growth within a franchise area, the provision of bulk water service to other community water systems and/or acquisitions, including small water and wastewater systems, typically serving fewer than 10,000 customers that are in close geographic proximity to already established regulated operations, which we herein refer to as “tuck-ins.”

The utility sector is characterized by high barriers to entry, given the capital intensive nature of the industry. The aging water and wastewater infrastructure in the United States is in constant need of modernization and facilities replacement. Increased regulations to improve water quality and the management of water and wastewater residuals’ discharges, which began with passage of the Clean Water Act in 1972 and the Safe Drinking Water Act in 1974, have been among the primary drivers of the need for modernization. The EPA estimated that approximately $335 billion of capital spending would be necessary between 2007 and 2026 to replace aging infrastructure and to comply with standards to ensure quality water systems across the United States. Also, in 2007 the EPA estimated that approximately $390 billion of capital spending would be necessary over the next 20 years to replace aging infrastructure and ensure quality wastewater systems across the United States. In addition, the 2011 American Society of Civil Engineers’ report, Failure to Act: The Economic Impact of Current Investment Trends in Water and Wastewater Treatment Infrastructure estimates that as investment needs continue to escalate and current funding trends continue to fall short of the needs, it will likely result in unreliable water service and wastewater treatment. According to the report, this can result in water disruptions, impediments to emergency response, and damage to other types of infrastructure, as well as water shortages (from failing infrastructure and drought) that may result in unsanitary conditions and increase the likelihood of public health issues.

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The following chart sets forth estimated capital expenditure needs from 2007 through 2026 for United States water systems:

Over the next several years, we estimate that Company-funded capital investment for our operations will range between $800 million and $1 billion per year. Our capital investment includes both infrastructure renewal programs, where we replace existing infrastructure, as needed, and construction of facilities to meet environmental requirements and new customer growth. The charts below set forth our estimated percentage of projected capital expenditures by asset type and purpose of investment, respectively:

Investor-owned water and wastewater utilities generally require regulatory approval processes in order to do business, which may involve obtaining relevant operating approvals, including certificates of public convenience and necessity (or similar authorizations) from state PUCs. Investor-owned water and wastewater systems are generally subject to economic regulation by the state PUCs in the states in which they operate. The federal government and the states also regulate environmental, health and safety and water quality matters for both investor-owned and government-owned water and wastewater utilities.

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The general services sector includes engineering and consulting companies and numerous other fee-for-service businesses. These include building and operating water and wastewater utility systems, system repair services, lab services, sale of water infrastructure and distribution products (such as pipes) and other specialized services. The general services segment is characterized by aggressive competition and market-driven growth and profit margins.

According to the EPA, the utility segment of the United States water and wastewater industry is highly fragmented, with approximately 52,000 community water systems and approximately 16,000 community wastewater facilities. Fifty-six percent of the approximately 52,000 community water systems are very small, serving a population of 500 or less.

This large number of relatively small, fragmented water systems as well as fragmented wastewater facilities may result in inefficiencies in the marketplace, since such utilities may not have the operating expertise, financial and technological capability or economies of scale to provide services or raise capital as efficiently as larger utilities. Larger utilities that have greater access to capital are generally more capable of making mandated and other necessary infrastructure upgrades to both water and wastewater systems. In addition, water and wastewater utilities with large customer bases, spread across broad geographic regions, may more easily absorb the impact of significant variations in precipitation and temperatures, such as droughts, excessive rain and cool temperatures in specific areas. Larger utilities generally are able to spread overhead expenses over a larger customer base, thereby reducing the costs to serve each customer. Since many administrative and support activities can be efficiently centralized to gain economies of scale, companies that participate in industry consolidation have the potential to improve operating efficiencies, lower costs per unit and improve service at the same time.

Water and Wastewater Rates

Investor-owned water and wastewater utilities generate operating revenue from customers based on rates that are generally established by state PUCs through a rate-setting process that may include public hearings, evidentiary hearings and the submission by the utility of evidence and testimony in support of the requested level of rates. In evaluating a rate case, state PUCs typically focus on six areas: (i) the amount and prudence of investment in facilities considered “used and useful” in providing public service; (ii) the operating and maintenance costs and taxes associated with providing the service (typically by making reference to a representative 12-month period of time, known as a test year); (iii) the appropriate rate of return; (iv) revenue at existing rates; (v) the tariff or rate design that allocates operating revenue requirements across the customer base; and (vi) the quality of service the utility provides, including issues raised by customers.

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Water and wastewater rates in the United States are among the lowest rates in developed countries; and for most U.S. consumers, water and wastewater bills make up a relatively small percentage of household expenditures compared to other utility services. The following chart sets forth the relative cost of water and other public services, including trash and garbage collection and sewer maintenance, in the United States as a percentage of total household utility expenditures:

Our Regulated Businesses

Our core Regulated Businesses, which consist of locally managed utility subsidiaries that generally are economically regulated by the states in which they operate, accounted for $2,368.9 million or 88.8% of our consolidated operating revenue in 2011. Our Regulated Businesses provide a high degree of financial stability because (i) high barriers to entry provide certain protections from competitive pressures; (ii) economic regulation promotes predictability in financial planning and long-term performance through the rate-setting process; and (iii) our customer base.

As a result of our portfolio optimization initiative, we announced certain acquisitions to and dispositions from our Regulated Businesses. In May, 2011, we completed the acquisition of 11 regulated water systems and 48 wastewater systems in Missouri for a purchase price of $3.3 million, Additionally in June 2011, we completed the sale of the assets of our Texas regulated subsidiary for proceeds of $6.2 million. The Missouri acquisition added approximately 1,700 water customers and nearly 2,000 wastewater customers. The Texas assets served approximately 4,200 water and 1,100 wastewater customers in the greater Houston metropolitan area.

In January 2011, we announced that we had entered into an agreement with EPCOR Water (USA) Inc. (“EPCOR USA”) to sell all the stock of our regulated water and wastewater operating companies located in Arizona and New Mexico. The sale of these operating companies was completed on January 31, 2012.

On July 8, 2011 we entered into an agreement to purchase seven regulated water systems in New York for approximately $71 million, adding approximately 50,000 customers to our New York regulated operations. In a separate agreement, we will sell eight regulated water systems and one wastewater system in Ohio for approximately $89 million, plus assumed liabilities of approximately $31 million for an estimated enterprise value of approximately $120 million. Ohio American Water currently serves approximately 58,000 customers. The completion of both transactions is subject to customary closing conditions including regulatory approval by the PUCs in both New York and Ohio. In February 2012, the Ohio PUC approved the sale of our Ohio subsidiary, however both approvals are required to close the transactions. The closing on these transactions is expected to occur in the first half of 2012.

As noted above, as a result of these sales or pending sales, these regulated subsidiaries are presented as discontinued operations. Therefore, the amounts, statistics and tables presented in this section refer only to on-going operations, unless otherwise noted.

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The following table sets forth operating revenue for 2011 and number of customers from continuing operations as well as an estimate of population served as of December 31, 2011 in the states where our Regulated Businesses operate:

	Operating Revenues (in millions)		% of Total			Number of Customers		% of Total			Estimated Population Served (in millions)		% of Total
New Jersey	$	612.1		25.8	%		647,083		20.9	%		2.5		21.9	%
Pennsylvania		515.5		21.8	%		655,291		21.1	%		2.2		19.3	%
Illinois(a)		242.6		10.2	%		307,076		9.9	%		1.2		10.5	%
Missouri		243.1		10.3	%		454,094		14.7	%		1.5		13.2	%
Indiana		193.7		8.2	%		285,120		9.2	%		1.2		10.5	%
California		163.0		6.9	%		173,529		5.6	%		0.6		5.3	%
West Virginia(b)		124.2		5.2	%		171,898		5.5	%		0.6		5.3	%
Subtotal (Top Seven States)		2,094.2		88.4	%		2,694,091		86.9	%		9.8		86.0	%
Other(c)		274.7		11.6	%		407,214		13.1	%		1.6		14.0	%
Total Regulated Businesses	$	2,368.9		100.0	%		3,101,305		100.0	%		11.4		100.0	%

(a) Includes Illinois-American Water Company, which we refer to as ILAWC and American Lake Water Company, also a regulated subsidiary in Illinois.

(b) West Virginia-American Water Company, which we refer to as WVAWC, and its subsidiary Bluefield Valley Water Works Company.

(c) Includes data from our operating subsidiaries in the following states: Georgia, Hawaii, Iowa, Kentucky, Maryland, Michigan, New York, Tennessee, and Virginia.

Approximately 88.4% of operating revenue from our Regulated Businesses in 2011 was generated from approximately 2.7 million customers in our seven largest states, as measured by operating revenues. In fiscal year 2011, no single customer accounted for more than 10% of our annual operating revenue.

Overview of Networks, Facilities and Water Supply

Our Regulated Businesses operate in approximately 1,100 communities in 16 states in the United States. Our primary operating assets include approximately 80 surface water treatment plants, 500 groundwater treatment plants, 1,000 groundwater wells, 100 wastewater treatment facilities, 1,100 treated water storage facilities, 1,200 pumping stations and 90 dams and 46,000 miles of mains and collection pipes. We own substantially all of the assets used by our Regulated Businesses. We generally own the land and physical assets used to store, extract and treat source water. Typically, we do not own the water itself, which is held in public trust and is allocated to us through contracts and allocation rights granted by federal and state agencies or through the ownership of water rights pursuant to local law. Maintaining the reliability of our networks is a key activity of our Regulated Businesses. We have ongoing infrastructure renewal programs in all states in which our Regulated Businesses operate. These programs consist of both rehabilitation of existing mains and replacement of mains that have reached the end of their useful service lives.

Our ability to meet the existing and future water demands of our customers depends on an adequate supply of water. Drought, governmental restrictions, overuse of sources of water, the protection of threatened species or habitats or other factors may limit the availability of ground and surface water. We employ a variety of measures to ensure that we have adequate sources of water supply, both in the short-term and over the long-term. The geographic diversity of our service areas tends to mitigate some of the economic effect of weather extremes for the Company as a whole. In any given summer, some areas are likely to experience drier than average weather while other areas will experience wetter than average weather.

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Our Regulated Businesses are dependent upon a defined source of water supply. Our Regulated Businesses obtain their water supply from surface water sources such as reservoirs, lakes, rivers and streams. In addition, we also obtain water from ground water sources, such as wells and purchase water from other water suppliers.

The following chart sets forth the sources of water supply for our Regulated Businesses for 2011 by volume:

In our long-term planning, we evaluate quality, quantity, growth needs and alternate sources of water supply as well as transmission and distribution capacity. Sources of supply are seasonal in nature and weather conditions can have a pronounced effect on supply. In order to ensure that we have adequate sources of water supply, we use comprehensive planning processes and maintain contingency plans to minimize the potential impact on service through a wide range of weather fluctuations. In connection with supply planning for most surface or groundwater sources, we employ sophisticated models to determine safe yields under different rainfall and drought conditions. Surface and groundwater levels are routinely monitored so that supply capacity deficits may be predicted and mitigated, as needed, through demand management and additional supply development.

The percentage of finished water supply by source type for our top seven states by Regulated Businesses revenues for 2011 is as follows:

	Ground Water			Surface water			Purchased water
New Jersey		21	%		73	%		6	%
Pennsylvania		7	%		92	%		1	%
Illinois		32	%		57	%		11	%
Missouri(a)		12	%		87	%		1	%
Indiana		57	%		42	%		1	%
California(b)		67	%		—			33	%
West Virginia		—			100	%		—

(a) There are limitations in our Joplin service area where the projected source of water supply capacity is unable to meet projected peak demands under certain drought conditions. To manage this issue on the demand side, the water use of a large industrial customer can be restricted under an interruptible tariff. Additional wells have been and will be developed to address short-term supply deficiencies. Missouri-American Water Company is working with a consortium of agencies to determine a long-term supply solution for the Joplin, Missouri region.

(b) In Monterey, in order to augment our sources of water supply, we have implemented conservation rates and other programs to address demand and are utilizing aquifer storage and recovery facilities to store winter water for summer use. Additionally, in other areas, we are making arrangements to extend or expand our purchase of water from neighboring water providers.

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The level of treatment we apply to the water varies significantly depending upon the quality of the water source and customer stipulations. Surface water sources, such as rivers, typically require significant treatment, while some groundwater sources, such as aquifers, require chemical treatment only. In addition, a small amount of treated water is purchased from neighboring water purveyors. Treated water is transported through an extensive transmission and distribution network, which includes underground pipes, above ground storage facilities and numerous pumping facilities with the ultimate distribution of the treated water to the customers’ premises.

We also have installed production meters to measure the water that we deliver to our distribution network. We employ a variety of methods of customer meter reading to monitor consumption; ranging from meters with mechanical registers where consumption is manually recorded by meter readers to meters with electronic registers capable of transmitting consumption data to proximity devices (touch read) or via radio frequency to mobile or fixed network data collectors. The majority of new meters are able to support future advances in electronic meter reading.

Wastewater services involve the collection of wastewater from customers’ premises through sewer lines. The wastewater is then transported through a sewer network to a treatment facility, where it is treated to meet required effluent standards. The treated wastewater is finally returned to the environment as effluent, and the solid waste byproduct of the treatment process is disposed of in accordance with applicable standards and regulations.

Customers

We have a large and geographically diverse customer base in our Regulated Businesses. For the purposes of our Regulated Businesses, an active customer is defined as a connection to our water and/or wastewater networks. A customer with both water and wastewater would count as two customers. Also, as in the case of apartment complexes, businesses and many homes, multiple individuals may be served by a single connection.

Residential customers make up the majority of our customer base in all of the states in which we operate. In 2011, residential customers accounted for 91.1% of the customers and 59.0% of the operating revenue of our Regulated Businesses. We also serve commercial customers, such as shops and businesses; industrial customers, such as large-scale manufacturing and production operations; and public authorities, such as government buildings and other public sector facilities, including schools. We also supply water to public fire hydrants for firefighting purposes, to private fire customers for use in fire suppression systems in office buildings and other facilities as well as providing bulk water supplies to other water utilities for distribution to their own customers.

The following table sets forth the number of water and wastewater customers (by customer class) for our Regulated Businesses as of December 31, 2011, 2010, and 2009:

	December 31,
	2011				2010				2009
	Water		Wastewater		Water		Wastewater		Water		Wastewater
Residential		2,730,524		95,092		2,728,205		93,156		2,721,085		92,183
Commercial		216,415		5,462		216,967		5,355		216,964		5,292
Industrial		3,885		13		4,033		13		4,241		13
Private fire		33,887		10		33,610		11		33,062		3
Public authority & other		15,818		199		15,436		197		15,430		196
Total		3,000,529		100,776		2,998,251		98,732		2,990,782		97,687

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The following table sets forth water services operating revenue by customer class and wastewater services operating revenue, excluding other revenues, for our Regulated Businesses for 2011, 2010, and 2009:

	Year Ended December 31,
	2011		2010		2009
			(in millions)
Water service
Residential	$	1,339.4	$	1,300.2	$	1,185.9
Commercial		474.2		457.0		417.0
Industrial		116.0		110.2		97.5
Public and other		323.0		314.1		281.3
Total water services	$	2,252.6	$	2,181.5	$	1,981.7
Wastewater services		76.3		69.0		64.3
Total	$	2,328.9	$	2,250.5	$	2,046.0

Substantially all of our regulated water customers are metered, which allows us to measure and bill for our customers’ water consumption, typically on a monthly basis. Our wastewater customers are billed either on a fixed charge basis or based on their water consumption.

Customer usage of water is affected by weather conditions, particularly during the summer. Our water systems generally experience higher demand in the summer due to the warmer temperatures and increased usage by customers for lawn irrigation and other outdoor uses. Summer weather that is cooler and wetter than average generally serves to suppress customer water demand and can reduce water operating revenue and operating income. Summer weather that is hotter and drier than average generally increases operating revenues and operating income. However, when weather conditions are extremely dry and even if our water supplies are sufficient to serve our customers, our systems may be affected by drought-related warnings and/or water usage restrictions imposed by governmental agencies, thereby reducing customer demand and operating revenue. These restrictions may be imposed at a regional or state level and may affect our service areas, regardless of our readiness to meet unrestricted customer demands. Other factors affecting our customers’ usage of water include conservation initiatives, including the use of more efficient household fixtures and appliances among residential consumers; declining household sizes in the United States; and deterioration in the economy and credit markets which could have an adverse impact on our industrial and commercial customers’ operational and financial performance.

Customer growth in our Regulated Businesses is driven by (i) organic population growth in our authorized service areas; (ii) adding new customers to our regulated customer base by acquiring water and/or wastewater utility systems; and (iii) the sale of water to other community water systems. Generally, we add customers through tuck-ins of small water and/or wastewater systems, typically serving fewer than 10,000 customers, in close geographic proximity to areas where we currently operate our Regulated Businesses. We will continue to acquire water and wastewater utilities through tuck-ins. The proximity of tuck-in opportunities to our regulated footprint allows us to integrate and manage the acquired systems and operations using our existing management and to achieve efficiencies. Historically, pursuing tuck-ins has been a fundamental part of our growth strategy. We intend to continue to expand our regulated footprint geographically by acquiring water and wastewater systems in our existing markets and, if appropriate, certain markets in the United States where we do not currently operate our Regulated Businesses. We will also selectively seek larger acquisitions that allow us to acquire multiple water and wastewater utility systems in our existing and new markets. Before entering new regulated markets, we will evaluate the regulatory environment to ensure that we will have the opportunity to achieve an appropriate rate of return on our investment while maintaining our high standards for quality, reliability and compliance with environmental, health and safety and water quality standards.

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Supplies

Our water and wastewater operations require an uninterrupted supply of chemicals, energy and fuel, as well as maintenance material and other critical inputs. Many of these inputs are subject to short-term price volatility. Short-term price volatility is partially mitigated through existing procurement contracts, current supplier continuity plans, and the regulatory rate setting process.

Because of our geographic diversity, we maintain relationships with many chemical, equipment and service suppliers in the marketplace, and we do not rely on any single entity for a material amount of our supplies. We also employ a strategic sourcing process intended to ensure reliability in supply and long-term cost effectiveness. As a result of this process and our strong relationships with suppliers, we are able to mitigate interruptions in the delivery of the products and services that are critical to our operations.

We typically have a combination of standby power generation or dual electric service feeds at key facilities, multiple water production facilities, emergency interconnections with adjacent water systems and finished water storage that keep our operations running in the event of a temporary loss of our primary energy supplies.

Regulation

Economic Regulation

Our Regulated Businesses are generally subject to extensive economic regulation by their respective PUCs. The term “economic regulation” is intended to indicate that these state PUCs regulate the economic aspects of service to the public but do not generally establish water quality standards, which are typically set by the United States Environmental Protection Agency (“EPA”) and/or state environmental authorities. State PUCs have broad authority to regulate many of the economic and service aspects of the utilities. For example, state PUCs often issue certificates of public convenience and necessity (or similar authorizations) that may be required for a company to provide service in specific areas. They also approve the rates and conditions under which service is provided and have extensive authority to establish rules and regulations under which the utilities operate. Specific authority might differ from state to state, but in most states PUCs approve rates, accounting treatments, long-term financing programs, significant capital expenditures and plant additions, transactions and relationships between the regulated subsidiary and affiliated entities, reorganizations, mergers and acquisitions. In many instances, approvals are required prior to the transaction. Regulatory policies not only vary from state to state, but can change over time as well. These policies will affect the timing as well as the extent of recovery of expenses and the realized return on invested capital. Our results of operations are significantly affected by rates authorized by the PUCs in the states in which we operate, and we are subject to risks and uncertainties associated with rate case delays or inadequate rate recovery.

Economic regulation of utilities involves many competing, and occasionally conflicting, public interests and policy goals. The primary responsibility of PUCs is to promote the overall public interest by balancing the interests of customers and the utility. Although the specific approach to economic regulation varies, certain general principles are consistent across the states in which our regulated subsidiaries operate. For example, based on certain legal and regulatory principles, utilities are entitled to recover, through rates charged to customers, prudent and reasonable operating costs as well as an opportunity to earn an appropriate return on and recovery of prudent, used and useful capital investment necessary to provide service to customers. PUCs will also generally accord a utility the right to serve specific areas and will also provide investor-owned utilities with limited protection from competition because the requirement of an investor-owned utility to operate pursuant to a certificate of public convenience and necessity (or similar authorizations) typically prevents other investor-owned utilities from competing with it in the authorized area. In return, the utility undertakes the obligation to provide reliable service without unreasonable discrimination to all customers within the authorized area.

Our operating revenue is typically determined by reference to a volumetric charge based on consumption and a base fee component set by a tariff approved by the PUC. The process to obtain approval for a change in

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rates generally involves filing a petition or “rate case” by the utility with the PUC on a periodic basis as determined by the need to recover capital expenditures, reduced revenue, increased operating costs or the utility determines that its current authorized return is not sufficient, given current market conditions, to provide a reasonable return on investment. A PUC may also initiate a rate proceeding or investigation if it believes a utility may be earning in excess of its authorized rate of return or other issues exist which justify a review. PUCs may also impose other conditions on the content and timing of filings designed to affect rates. Rate cases often involve a lengthy administrative process which can be costly. The utility, the state PUC staff, consumer advocates, and other customers, who may participate in the process, generally submit testimony and supporting financial data from a twelve month period of time, known as the “test year.” State statutes and PUC rules and precedent usually determine whether the test year should be based on a historical period, a historical period adjusted for certain “known and measurable” changes or forecasted data. The majority of our states require the test year to be based on a historical period adjusted for certain known and measurable changes. The evidence is presented in public hearings held in connection with the rate case, which are economic and service quality fact-finding in nature, and are typically conducted in a trial-like setting before the PUC or an administrative law judge. During the process, the utility is required to provide PUC staff and intervenors with all relevant information they may request concerning the utility’s operations, costs and investments. The decision of the PUC should be based on the evidence presented at the hearing.

Some state PUCs are more restrictive than others with regard to the types of expenses and investments that may be recovered in rates as well as with regard to the transparency of their rate-making processes and how they reach their final rate determinations. However, in evaluating a rate case, state PUCs typically focus on a number of areas, including, the amount and prudence of investment in facilities; operating and maintenance expenses and taxes; the appropriate cost of capital and equity return; revenues at current and expected levels; allocation of the revenue requirements among customer classes; service quality and issues raised by customers.

Failure of the PUCs to recognize reasonable and prudent operating and capital costs can result in the inability of the utility to earn the allowed return and can have a significant impact on the operations and earnings of our Regulated Businesses. Rate cases and other rate-related proceedings can take several months to over a year to complete. Therefore, there is frequently a delay, or regulatory lag, between the time one of our regulated subsidiaries makes a capital investment or incurs an operating cost increase and when those costs are reflected in rates. For instance, an unexpected increase in chemical costs or new capital investment that is not reflected in the most recently completed rate case will generally not begin to be recovered by the regulated subsidiary until the effective date of the subsequent rate case. Our rate case management program is guided by the goals of obtaining efficient recovery of costs of capital and utility operating and maintenance costs, including costs incurred for compliance with environmental regulations. The management team at each of our regulated subsidiaries anticipates the time required for the regulatory process and files rate cases with the goal of obtaining rates that reflect as closely as possible the cost of providing service at the time the rates become effective. Even if rates are sufficient, we face the risk that we will not achieve the rates of return on and of invested capital that are permitted by the PUC.

Our regulated subsidiaries work with legislatures and PUCs to mitigate the adverse impact of regulatory lag through the adoption of positive regulatory policies. These policies include, for example, infrastructure replacement surcharges that allow rates to change rates outside the context of a general rate proceeding to reflect, on a more timely basis, investments to replace aging infrastructure necessary to sustain high quality, reliable service. Currently, Pennsylvania, Illinois, Missouri, Indiana, New York and California allow the use of infrastructure surcharges. In November 2011, the New Jersey Board of Public Utilities (“BPU”) voted unanimously to publish draft rules that, if adopted, would implement a distribution system improvement charge for specified water infrastructure investments. The draft rules were published for public comment in December 2011. Allowing time for resolution of public comments and final approval, April 2012 is the earliest estimate for the rule to become final.

Forward-looking test year mechanisms allow us to earn, on a more current basis, our current or projected usage and costs and a rate of return on our current or projected invested capital. Some states have permitted use

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of a fully forecasted test year instead of historical data to set rates. Examples of these states include: Illinois, Kentucky, New York, Tennessee and California. In all states in which we operate on a regulated basis, PUCs have allowed utilities to update historical data for certain “known and measurable” changes that occur for some limited period of time subsequent to the historical test year. This allows utilities to take account of more current costs or capital investments in the rate-setting process. The extent to which historical data can be updated will generally vary from state to state.

Surcharge mechanisms are also available in a number of states to reflect, outside of general rate proceeding, changes in major operating expenses which may be beyond the utility’s control. For example, New Jersey, California, Virginia and Illinois have allowed surcharges for purchased water costs. California has allowed surcharges for power and certain other costs, and New York has allowed annual reconciliations for revenues and expenses such as power, fuel, chemicals and property taxes.

Certain states have approved consolidated rates or single-tariff pricing policies. Consolidated rates or single-tariff pricing is the use of a unified rate structure for multiple water systems that are owned and operated by a single utility, but may or may not be contiguous or physically interconnected. The single-tariff pricing structure may be used fully or partially in a state, based on costs that are determined on a state-wide or intra-state regional basis, thereby moderating the impact of periodic fluctuations in local costs while lowering administrative costs for us and our customers. For states that do not employ singe-tariffs, we may have multiple general rate cases filed at any given point in time. States that have adopted a full or partial single-tariff pricing policy included: Pennsylvania, New Jersey, West Virginia, Kentucky, Ohio, Indiana, Illinois and Iowa. Therefore, of our seven largest states, five have some form of single-tariff pricing.

Another mechanism to address issues of regulatory lag is the potential ability, in certain circumstances, to recover in rates a return on utility plant before it is in service, instead of capitalizing an allowance for funds used during construction. Examples of states that have allowed such recovery include Pennsylvania, Ohio, Kentucky, Virginia, Illinois and California. In addition, some states, such as Indiana, allow the utility to seek pre-approval of certain capital projects and associated costs. In this pre-approval process, the PUC assesses the prudency of such projects.

In some states, the PUC has implemented mechanisms to enhance utility revenue stability in light of conservation initiatives, decreasing per capita consumption or other factors. Sometimes referred to as “decoupling,” these mechanisms, to some extent, separate recoverable revenues from volumes of water sold. For example, the state of California has decoupled revenues from water sold to help achieve the state initiative to reduce water usage by 20% by 2020. This progressive regulation enables utilities to encourage conservation, as revenues are not tied to sales. Also, as a result of this mechanism, utilities are less susceptible to consumption changes as a result of conservation, declining per capita usage or other factors affecting consumption. Likewise, New York has implemented a surcharge or credit based on the difference between actual net revenues for the preceding year and the net revenue target as estimated in the most recent rate case.

The Company pursues these positive regulatory policies as part of our rate and revenue management program to enhance our ability to provide high quality, sustainable, cost effective service to customers, to facilitate efficient recovery of our costs and investments, and to ensure positive short-term liquidity and long-term profitability. The ability of the Company to seek regulatory treatment as described above does not guarantee that the state PUCs will accept the Company’s proposal in the context of a particular rate case, and these policies will reduce, but not eliminate, regulatory lag associated with traditional rate making processes. However, the Company strives to use these and other regulatory policies to address issues of regulatory lag wherever appropriate. It is also our strategy to expand their use in areas where they may not currently apply.

Environmental, Health and Safety and Water Quality Regulation

Our water and wastewater operations are subject to extensive United States federal, state and local laws and regulations, and in the case of our Canadian operations, Canadian laws and regulations governing the protection

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of the environment, health and safety, the quality of the water we deliver to our customers, water allocation rights and the manner in which we collect, treat, discharge and dispose of wastewater. We are also subject to certain regulations regarding fire protection services in the areas we serve. These regulations include the Safe Drinking Water Act, the Clean Water Act and other federal, state, local and Canadian laws and regulations governing the provision of water and wastewater services, particularly with respect to the quality of water we distribute. We also are subject to various federal, state, local and Canadian laws and regulations governing the storage of hazardous materials, the management and disposal of hazardous and solid wastes, discharges to air and water, the cleanup of contaminated sites, dam safety and other matters relating to the protection of the environment and health and safety. State PUCs also set conditions and standards for the water and wastewater services we deliver.

Environmental, health and safety and water quality regulations are complex and change frequently. The overall trend has been that they have become more stringent over time. As newer or stricter standards are introduced, our capital and operating costs could increase. We incur substantial costs associated with compliance with environmental, health and safety and water quality regulation to which our Regulated Businesses are subject. In the past, we have generally been able to recover costs associated with compliance related to environmental, health and safety standards, but this recovery is affected by regulatory lag and the corresponding uncertainties surrounding rate recovery.

We maintain a comprehensive environmental policy including responsible business practices, compliance with environmental laws and regulations, effective use of natural resources, and stewardship of biodiversity. We believe that our operations are materially in compliance with, and in many cases surpass, minimum standards required by applicable environmental laws and regulations. Water samples from across our water systems are analyzed on a regular basis for material compliance with regulatory requirements. Across the Company, we conduct over one million water quality tests each year at our laboratory facilities and plant operations, including continuous on-line instrumentations such as monitoring turbidity levels, disinfectant residuals and adjustments to chemical treatment based on changes in incoming water. For 2011, we achieved a score of greater than 99% for drinking water compliance and according to the EPA statistics, American Water’s performance has been far better than the industry average over the last several years. In fact, in 2011, American Water was 28 times better than the industry average for compliance with drinking water quality standards (Maximum Contaminant Levels) and 118 times better for compliance with drinking water monitoring and reporting requirements.

We participate in the Partnership for Safe Water, the United States EPA’s voluntary program to meet more stringent goals for reducing microbial contaminants. With 67 of our 86 surface water plants receiving the program’s “Director” award, we account for approximately one-third of the plants receiving such awards nationwide. In addition, 62 American Water plants have received the “Five-Year Phase III” award, while 40 have been awarded the “Ten-Year Phase III” award.

Safe Drinking Water Act

The Federal Safe Drinking Water Act and regulations promulgated thereunder establish national quality standards for drinking water. The EPA has issued rules governing the levels of numerous naturally occurring and man-made chemical and microbial contaminants and radionuclides allowable in drinking water and continues to propose new rules. These rules also prescribe testing requirements for detecting contaminants, the treatment systems which may be used for removing contaminants and other requirements. Federal and state water quality requirements have become increasingly stringent, including increased water testing requirements, to reflect public health concerns.

To effect the removal or inactivation of microbial organisms, the EPA has promulgated various rules to improve the disinfection and filtration of drinking water and to reduce consumers’ exposure to disinfectants and byproducts of the disinfection process. In January 2006, the EPA promulgated the Long-term 2 Enhanced Surface Water Treatment Rule and the Stage 2 Disinfectants and Disinfection Byproduct Rule. In October 2006,

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the EPA finalized the Ground Water Rule, applicable to water systems providing water from underground sources. In 2006, the EPA also proposed revisions to the monitoring and reporting requirements of the existing Lead and Copper Rule. In 2012, we anticipate that the EPA will finalize revisions to the Total Coliform Rule that were part of the mandate of a Federal Advisory Committee appointed to negotiate the changes. Most of the anticipated changes to the rule will not be effective until 2013 or later. The EPA is actively considering regulations for a number of contaminants, including hexavalent chromium, fluoride, nitrosamines, perchlorate, some pharmaceuticals and certain volatile organic compounds, but we do not anticipate that any of these regulations will be completed in 2012.

Although it is difficult to project the ultimate costs of complying with the above or other pending or future requirements, we do not expect current requirements under the Safe Drinking Water Act to have a material impact on our operations or financial condition. In addition, capital expenditures and operating costs to comply with environmental mandates traditionally have been recognized by PUCs as appropriate for inclusion in establishing rates. As a result, we expect to fully recover the operating and capital costs resulting from these pending or future requirements.

Clean Water Act

The Federal Clean Water Act regulates discharges from drinking water and wastewater treatment facilities into lakes, rivers, streams and groundwater. In addition to requirements applicable to our wastewater collection systems, our operations require discharge permits under the National Pollutant Discharge Elimination System, (“NPDES”), permit program established under the Clean Water Act. Pursuant to the NPDES program, the EPA or implementing states set maximum discharge limits for wastewater effluents and overflows from wastewater collection systems. We believe that we maintain the necessary permits and approvals for the discharges from our water and wastewater facilities. From time to time, discharge violations occur at our facilities, some of which

result in fines. We do not expect any such violations or fines to have a material impact on our results of operations or financial condition.

Other Environmental, Health and Safety and Water Quality Matters

Our operations also involve the use, storage and disposal of hazardous substances and wastes. For example, our water and wastewater treatment facilities store and use chlorine and other chemicals which generate wastes that require proper handling and disposal under applicable environmental requirements. We also could incur remedial costs in connection with any contamination relating to our operations or facilities or our off-site disposal of wastes. Although we are not aware of any material cleanup or decontamination obligations, the discovery of contamination or the imposition of such obligations in the future could result in additional costs. Our facilities and operations also are subject to requirements under the United States Occupational Safety and Health Act and are subject to inspections thereunder. For further information, see “Business—Research and Development.”

Certain of our subsidiaries are involved in pending legal proceedings relating to environmental matters. These proceedings are described further in the section entitled “Item 3—Legal Proceedings.”

Competition

In our Regulated Businesses, we generally do not face direct competition in providing services in our existing markets because (i) we operate within those markets pursuant to certificates of public convenience and necessity (or similar authorizations) issued by state PUCs; and (ii) the high cost of constructing a new water and wastewater system in an existing market creates a barrier to market entry. Our Regulated Businesses do face competition from governmental agencies, other investor-owned utilities, large industrial customers with the ability to provide their own water supply/treatment process and strategic buyers that are entering new markets and/or making strategic acquisitions. Our largest investor-owned competitors, when pursuing acquisitions, based

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on a comparison of operating revenues and population served, are Aqua America Inc., United Water (owned by Suez Environnement), American States Water Co. and California Water Services Group.

Condemnation

The potential exists that portions of our subsidiaries’ utility assets could be acquired by municipalities or other local government entities through one or more of the following methods:

• eminent domain (also known as condemnation);

• the right of purchase given or reserved by a municipality or political subdivision when the original certificate of public convenience and necessity was granted; and

• the right of purchase given or reserved under the law of the state in which the utility subsidiary was incorporated or from which it received its certificate.

The acquisition consideration related to such a transaction initiated by a local government may be determined consistent with applicable eminent domain law, or may be negotiated or fixed by appraisers as prescribed by the law of the state or in the particular franchise or charter. We believe our operating subsidiaries would be entitled to fair market value for any assets required to be sold, and we are of the opinion that fair market value would be in excess of the book value for such assets.

We are periodically subject to condemnation proceedings in the ordinary course of business, the last of which occurred in September 2008. We actively monitor condemnation activities that may affect us as soon as we become aware of them. We do not believe that condemnation poses a material threat to our ability to operate our Regulated Businesses.

Our Market-Based Operations

In addition to our Regulated Businesses, we operate the following Market-Based Operations, which generated $327.8 million of operating revenue in 2011 representing 12.3% of total operating revenue for the same period. Of the lines of business outlined below, no single group within our Market-Based Operations generates in excess of 10% of our aggregate revenue.

Contract Operations Group

Our Contract Operations Group enters into public/private partnerships, including O&M and Design, Build and Operate (“DBO”) contracts for the provision of services to water and wastewater facilities for the United States military, municipalities, the food and beverage industry and other customers. We typically make no capital investment under these contracts with municipalities and other customers; instead we perform our services for a fee. During the contract term, we may make limited capital investments under our contracts with the United States military and certain industrial customers. Our Contract Operations Group generated revenue of $230.5 million in 2011, representing 70.3% of revenue for our Market-Based Operations.

On December 31, 2011, we completed the sale of our Applied Water Management, Inc. group (“AWM”) in two separate transactions for combined proceeds of approximately $3.0 million. AWM provided customized water and wastewater management solutions through contract operations with real estate developers, industrial clients, and small-to-midsized communities. Its annual revenue and net loss in 2011 were $21.6 million and $0.6 million, respectively. As noted above, this subsidiary is included in discontinued operations for all periods presented. Therefore, all amounts and statistics disclosed for the Contract Operations Group refers only to on-going operations of the Contract Operations Group.

We are currently party to more than 100 contracts, varying in size and scope, across the United States and Canada, with contracts ranging in term from two to 50 years. Included in the these contracts are nine 50-year

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contracts with the Department of Defense for the operation and maintenance of the water and wastewater systems and one 3-year sub-contract with a municipality, acting as primary contractor with the Department of Defense, for similar services on an interim basis until construction of new connections to an existing municipal facility are completed. All of our contracts with the U.S. government may be terminated, in whole or in part, prior to the end of the 50-year term for convenience of the U.S. government or as a result of default or non-performance by the subsidiary performing the contract. In either event, pursuant to the standard terms of the U.S. government contract termination provisions, we would be entitled to recover allowable costs that we may have incurred under the contract, plus the contract profit margin on incurred costs. The contract price for each of these contracts is subject to redetermination two years after commencement of operations and every three years thereafter. Price redetermination is a contract mechanism to periodically adjust the service fee in the next period to reflect changes in contract obligations and anticipated market conditions.

Homeowner Services Group

Our Homeowner Services Group, through our Service Line Protection Program, provides services to domestic homeowners and smaller commercial establishments to protect against the cost of repairing broken or leaking water pipes and clogged or blocked sewer pipes inside and outside their accommodations.

Our LineSaver™ program involves partnering with municipalities to offer our protection programs to homeowners serviced by the municipalities. Our Homeowner Services Group has approximately 900,000 customer contracts in 17 states.

Terratec Environmental Ltd

Our Market-Based Operations also includes our biosolids management group, Terratec, which is located in Canada and provides environmentally sustainable management and disposal of biosolids and wastewater by-products.

Competition

We face competition in our Market-Based Operations from a number of service providers, including Veolia Environnement, American States, OMI and Southwest Water, particularly in the area of O&M contracting. Securing new O&M contracts is highly competitive, as these contracts are awarded based on a combination of customer relationships, service levels, competitive pricing, references and technical expertise. We also face competition in maintaining existing O&M contracts to which we are a party, as the municipal and industrial fixed term contracts frequently come up for renegotiation and are subject to an open bidding process.

Research and Development

We established a formal research and development program in 1981 with the goal of improving water quality and operational effectiveness in all areas of our business. Our research and development personnel are located in New Jersey. In addition, our quality control and testing laboratory in Belleville, Illinois supports research through sophisticated testing and analysis. Since its inception, our research and development program has evolved to become a leading water-related research program, achieving advancements in the science of drinking water, including sophisticated water testing procedures and desalination technologies.

Since the formation of the EPA in 1970, we have collaborated with the agency to achieve effective environmental, health and safety and water quality regulation. This relationship has developed to include sharing of our research and national water quality monitoring data in addition to our treatment and distribution system optimization research. Our engagement with the EPA has helped us to achieve a leadership position for our company within the water and wastewater industry and has provided us with early insight into emerging regulatory issues and initiatives, thereby allowing us to anticipate and to accommodate our future compliance requirements.

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In 2011, we spent $2.6 million on research and development compared to $2.8 million spent in 2010 and 2009. Approximately one-quarter of our research budget is comprised of competitively awarded outside research grants. Such grants reduce the cost of research and allow collaboration with leading national and international researchers.

We believe that continued research and development activities are critical in providing quality and reliable service at reasonable rates, in maintaining our leadership position in the industry and will provide us with a competitive advantage as we seek additional business with new and existing customers.

Support Services

Our American Water Works Service Company subsidiary provides shared services and corporate governance that achieve economies of scale through central administration. These services are provided predominantly to our Regulated Businesses under the terms of contracts with these companies that have been approved by state PUCs, where necessary. These services, which are provided at cost, may include accounting, administration, business development, corporate secretarial, education and training, engineering, financial, health and safety, human resources, information systems, legal, operations, procurement, rates, security, risk management, water quality and research and development. These arrangements afford our operating companies professional and technical talent on an economical and timely basis. We also operate two national customer service centers, which are located in Alton, Illinois and Pensacola, Florida.

Our security department provides oversight and governance of physical and information security throughout our operations and is responsible for designing, implementing, monitoring and supporting active and effective physical and information security controls. We have complied with EPA regulations concerning vulnerability assessments and have made filings to the EPA as required. Vulnerability assessments are conducted regularly to evaluate the effectiveness of existing security controls and serve as the basis for further capital investment in security for the facility. Information security controls are deployed or integrated to prevent unauthorized access to company information systems, assure the continuity of business processes dependent upon automation, ensure the integrity of our data and support regulatory and legislative compliance requirements. While we do not make public comments on the details of our security programs, we are in contact with federal, state and local law enforcement agencies to coordinate and improve the security of our water delivery systems and to safeguard our water supply.

Employee Matters

Currently, approximately 49% of our workforce is represented by unions. We have 83 collective bargaining agreements in place with 19 different unions representing our unionized employees. In September 2010, we declared “impasse” in negotiations of our national benefits agreement with most of the labor unions representing employees in our Regulated Businesses. The prior agreement expired on July 31, 2010; however negotiations did not produce a new agreement. We implemented our last, best and final offer on January 1, 2011 in order to maintain health care coverage for our employees in accordance with terms of the offer. The unions have challenged our right to implement our last, best, and final offer. In this regard, following the filing by the Utility Workers Union of America of an unfair labor practice charge, the National Labor Relations Board (“NLRB”) issued a complaint against us in January 2012, claiming that we implemented the last, best and final offer without providing sufficient notice of the existence of a dispute with the Federal Mediation and Conciliation Service, a state mediation agency, and several state departments of labor. We have asserted that we did, in fact, provide sufficient notice. A hearing date on the matter has not been set. In addition, six local unions filed grievances or demands for arbitration under their respective local collective bargaining agreements regarding our implementation of the last, best and final offer. In response, we filed a declaratory judgment action against the local unions in United States District Court for the District of New Jersey seeking, among other things, an injunction preventing the unions from filing grievances or demanding arbitration under the local collective bargaining agreements with respect to the implementation of our last, best and final offer. Three of the unions were removed from the litigation after they agreed to a dismissal with prejudice. Two of the unions were

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removed from the New Jersey District Court action, and the Company is pursuing similar declaratory judgment actions against the unions in United States District Courts in Pennsylvania and West Virginia. We will continue to defend our position in any challenge presented by the unions. Management does not expect any work disruption by union members at this time. In addition to matters relating to the expired national benefit agreement, five local union contracts covering approximately 700 employees expired without a new agreement being reached prior to December 31, 2011. One contract relating to employees in St. Louis, Missouri was negotiated to impasse and our last, best and final offer was implemented on July 11, 2011. There have been no work stoppages with respect to these contracts. Nevertheless, management has developed contingency plans that will be implemented as necessary if a work stoppage or strike does occur. Over one-quarter of our local union contracts will expire during 2012.

Available Information

We are subject to the reporting requirements of the Securities Exchange Act of 1934, as amended. We file or furnish annual, quarterly and current reports, proxy statements and other information with the United States Securities and Exchange Commission (“SEC”). You may obtain a copy of any of these reports, free of charge, from the Investor Relations section of our website, http://www.amwater.com, shortly after we file or furnish the information to the SEC. Information contained on our website shall not be deemed incorporated into, or to be a part of, this report.

You may also obtain a copy of any of these reports directly from the SEC. You may read and copy any material we file or furnish with the SEC at their Public Reference Room, located at 100 F Street N.E., Washington, D.C. 20549. The phone number for information about the operation of the Public Reference Room is 1-800-732-0330 (if you are calling from within the United States), or 202-551-8090. Because we electronically file our reports, you may also obtain this information from the SEC internet website at http://www.sec.gov. You can obtain additional contact information for the SEC on their website.

The American Water corporate governance guidelines and the charters for each of the standing committees of the board of directors, together with the American Water Code of Ethics and additional information regarding our corporate governance, are available on our website, http://www.amwater.com, and will be made available, without charge, in print to any shareholder who requests such documents from Investor Relations Department, American Water Works Company, Inc., 1025 Laurel Oak Road, Voorhees, NJ, 08043.

ITEM 1A. RISK FACTORS

We operate in a market and regulatory environment that involves significant risks, many of which are beyond our control. In addition to the other information included or incorporated by reference in this Form 10-K, the following factors should be considered in evaluating our business and future prospects. Any of the following risks, either alone or taken together, could materially and adversely affect our business, financial position, results of operations or cash flows and liquidity.

Risks Related to Our Industry and Business

Our utility operations are subject to extensive economic regulation. Decisions by state PUCs and other regulatory agencies can significantly affect our business and results of operations.

Our Regulated Businesses provide water and wastewater services to our customers through subsidiaries that are economically regulated by state PUCs. Economic regulation affects the rates we charge our customers and has a significant impact on our business and results of operations. Generally, the state PUCs authorize us to charge rates that they determine are sufficient to recover our prudently incurred operating expenses, to enable us to finance the addition of new, or the replacement of existing, water and wastewater infrastructure and to provide us the opportunity to earn what they determine to be an appropriate rate of return on our invested capital and a return of our invested capital.

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Our ability to successfully implement our business plan and strategy depends upon the rates authorized by the various state PUCs. We periodically file rate increase applications with state PUCs. The ensuing administrative process may be lengthy and costly. We can provide no assurances that our rate increase requests will be approved, or that any approval will be given in a timely manner. Moreover, a PUC may not approve a rate request to an extent that is sufficient to cover our expenses, including purchased water and costs of chemicals, fuel and other commodities used in our operations; enable us to recover our investment; and provide us an opportunity to earn an appropriate rate of return on our investment, in which case our business, financial condition, results of operations, cash flow and liquidity may be adversely affected. Even if rates are sufficient, we face the risk that we will not achieve the rates of return on our invested capital and a return of our invested capital to the extent permitted by state PUCs. This could occur if water usage is less than anticipated in establishing rates, as billings to customers are, to a considerable extent, based on usage in addition to a base rate, or if our investments or expenses prove to be higher than was estimated in establishing rates.

Our operations and the quality of water we supply are subject to extensive environmental, water quality and health and safety laws and regulations. Compliance with increasingly stringent laws and regulations could impact our operating costs; and violations of such laws and regulations could subject the company to substantial liabilities and costs.

Our water and wastewater operations are subject to extensive United States federal, state and local laws and regulations and, in the case of our Canadian operations, Canadian laws and regulations that govern the protection of the environment, health and safety, the quality of the water we deliver to our customers, water allocation rights, and the manner in which we collect, treat, discharge and dispose of wastewater. These requirements include the United States Clean Water Act of 1972, which we refer to as the Clean Water Act, and the United States Safe Drinking Water Act of 1974, which we refer to as the Safe Drinking Water Act, and similar state and Canadian laws and regulations. We are also required to obtain various environmental permits from regulatory agencies for our operations. In addition, state PUCs also set conditions and standards for the water and wastewater services we deliver. If we deliver water or wastewater services to our customers that do not comply with regulatory standards, or otherwise violate environmental laws, regulations or permits, or other health and safety and water quality regulations, we could incur substantial fines, penalties or other sanctions or costs, as well as damage to our reputation. In the most serious cases, regulators could force us to discontinue operations and sell our operating assets to another utility or to a municipality. Given the nature of our business which, in part, involves supplying water for human consumption, any potential non-compliance with, or violation of, environmental, water quality and health and safety laws or regulations would likely pose a more significant risk to us than to a company not similarly involved in the water and wastewater industry.

We incur substantial operating and capital costs on an ongoing basis to comply with environmental, water quality and health and safety laws and regulations. These laws and regulations, and their enforcement, generally have become more stringent over time, and new or stricter requirements could increase our costs. Although we may seek to recover ongoing compliance costs in our rates, there can be no guarantee that the various state PUCs or similar regulatory bodies that govern our Regulated Businesses would approve rate increases to recover such costs or that such costs will not materially and adversely affect our financial condition, results of operations, cash flows and liquidity.

We may also incur liabilities if, under environmental laws and regulations, we are required to investigate and clean up environmental contamination at our properties, including potential spills of hazardous chemicals, such as chlorine, which we use to treat water, or at off-site locations where we have disposed of waste or caused an adverse environmental impact. The discovery of previously unknown conditions, or the imposition of cleanup obligations in the future, could result in significant costs and could adversely affect our financial condition, results of operations, cash flows and liquidity. Such remediation costs may not be covered by insurance and may make it difficult for us to secure insurance at acceptable rates in the future.

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The current regulatory rate setting structure may result in a significant delay, or “regulatory lag,” from the time that we invest in infrastructure improvements, incur increased operating expenses or experience declining water usage, to the time at which we can address these events through the rate case application process; our inability to minimize regulatory lag could adversely affect our business.

There is typically a delay, or regulatory lag, between the time one of our regulated subsidiaries makes a capital investment or incurs an operating expense increase and the time when those costs are reflected in rates. In addition, billings permitted by state PUCs typically are, to a considerable extent, based on the volume of water usage in addition to a minimum base rate. Thus, we may experience a regulatory lag between the time our revenues are affected by declining usage and the time we are able to adjust the rate per gallon of usage to address declining usage. Our inability to reduce this regulatory lag could have an adverse effect on our financial condition, results of operations, cash flow and liquidity.

Several state PUCs are permitting rates to be adjusted outside of the rate case application process through surcharges that address capital investments to replace aging infrastructure, and increases in costs beyond the utility’s control, such as purchased water costs, property taxes and other expenditures. These surcharge mechanisms enable us to adjust rates closer to the time costs have been incurred than would be the case under the rate case application process. Currently, seven states permit us to use infrastructure surcharges related to our capital investments to replace aging infrastructure. These surcharges periodically are adjusted based on factors such as project completion or future budgeted expenditures, and specific surcharges are eliminated once the related capital investment is incorporated in new PUC-approved base rates. In addition to the infrastructure surcharges, three states have permitted us to add surcharges for purchased water costs, one state has permitted us to add surcharges for power and conservation costs, and one state has permitted us to add surcharges for expenses such as utility and chemical costs. While these surcharges have been a positive development, some state PUCs have not approved surcharges for infrastructure improvement, no state PUC has enabled us to add a surcharge for all of the operating expenses described above, and no state PUC has enabled us to address declining water usage through a surcharge. Although we intend to expand our efforts to obtain state PUC approval of surcharges to address infrastructure investments, increases in operating expenses and declining water usage, our efforts may not be successful, in which case our business, financial condition, results of operations, cash flow and liquidity may be adversely affected.

Availability of water supplies, restrictions on use, natural hazards, severe weather conditions, competing uses and economic conditions may adversely affect our access to sources of water, the demand for water services or our ability to supply water to customers.

Our ability to meet the existing and future demand of our customers depends on the availability of an adequate supply of water. As a general rule, sources of public water supply, including rivers, lakes, streams and groundwater aquifers, are held in the public trust and are not owned by private interests. As a result, we typically do not own the water that we use in our operations, and the availability of our water supply is established through allocation rights (determined by legislation or court decisions) and passing-flow requirements set by governmental entities. Passing-flow requirements set minimum volumes of water that must pass through specified water sources, such as rivers and streams, in order to maintain environmental habitats and meet water allocation rights of downstream users. Allocation rights are imposed to ensure sustainability of major water sources and passing-flow requirements are most often imposed on source waters from smaller rivers, lakes and streams. These requirements, which can change from time to time, may adversely impact our water supply. Drought, overuse of sources of water, the protection of threatened species or habitats, or other factors may limit the availability of ground and surface water. For example, in our Monterey County, California operations, we are seeking to augment our sources of water supply, principally to comply with an order of the California State Water Resources Control Board that our subsidiary, California-American Water Company (“CAWC”), significantly decrease its diversion from the Carmel River in accordance with a reduction schedule running through December 31, 2016. We are also required to augment our Monterey County sources of water supply to comply with the requirements of the Endangered Species Act. We have implemented conservation rates and other programs to address demand and are utilizing aquifer storage and recovery facilities to store winter water

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for summer use. We were hopeful that we could address the water supply issues in a meaningful way through a Regional Desalination Project (the “Project”) that was to be implemented through a Water Purchase Agreement and ancillary agreements (the “Agreements”) among the Marina Coast Water District (“MCWD”), the Monterey County Water Resources Agency (“MCWRA”) and CAWC. As part of the Project, CAWC was to construct a conveyance pipeline from the desalination facility. We also planned to construct four additional pipelines and two pump stations (the “Ancillary Facilities”). However, the Project was subject to considerable delay and disputes among the parties. In July 2011, MCWRA advised MCWD and CAWC that the Agreements were void. By letter delivered to MCWD and MCWRA on September 28, 2011, CAWC terminated the Agreements based on MCWRA’s repudiation of the Agreements (MCWD has continued to assert that the Agreements remain in effect). Nevertheless, the parties agreed to participate in mediation in an attempt to resolve issues relating to the Project and the Agreements. In October 2011, during the pendency of the mediation, CAWC filed a petition (the “Petition”) with the California Public Utility Commission (“CPUC”) seeking clarification that it may go forward with constructing the Ancillary Facilities regardless of the status of the Project. MCWD and the California Division of Ratepayer Advocates are opposing the Petition. Ultimately, the mediation was not successful and ended on January 16, 2012. On January 17, 2012, CAWC announced that it had withdrawn support of the Agreements. In a prehearing conference with respect to the Petition, CAWC advised the administrative law judge assigned to the matter that it will seek CPUC approval of an alternate proposal. The administrative law judge directed CAWC to file, jointly with the MCWD and MCWRA if possible, a status report addressing various issues relating to the Project, and to submit a compliance filing to address CAWC’s plans to move forward on a new project. The filings are due by March 1, 2012. We cannot predict the ultimate effect of the events described above on CAWC’s efforts to secure alternative sources of water. If CAWC is unable to secure an alternative source of water, our business, financial condition, results of operations and cash flows could be adversely affected.

Government restrictions on water use may also result in decreased use of water services, even if our water supplies are sufficient to serve our customers, which may adversely affect our financial condition and results of operations. Seasonal drought conditions that would impact our water services are possible across all of our service areas. If a regional drought were to occur, governmental restrictions may be imposed on all systems within a region independent of the supply adequacy of any individual system. There were voluntary conservation efforts or water use restrictions implemented during certain periods of 2011 in Pennsylvania and New Jersey. Following drought conditions, water demand may not return to pre-drought levels even after restrictions are lifted. Decreased use of water services resulting from any of these events may adversely affect our business, financial condition, results of operations and cash flows.

Service interruptions due to severe weather events are possible across all our service areas. These include winter storms and freezing conditions, high wind conditions, tornados, earthquakes, high water conditions in or near designated flood plains, hurricanes and severe electrical storms. These weather events may affect the condition or operability of our facilities, limiting or preventing us from delivering water or wastewater services to our customers, or requiring us to make substantial capital expenditures to repair any damage. In the third quarter of 2011, our New Jersey and Pennsylvania subsidiaries experienced service interruptions in certain of our operating areas and, in some cases, a loss in customers as a result of the extreme weather, including Hurricane Irene and other severe storms in the Northeast. In addition, the devastating tornado that struck Joplin, Missouri on May 22, 2011 caused extensive damage to our infrastructure and the water distribution system. Among other things, we lost our service center and plant storage buildings and suffered damage to the roof and windows at our water treatment plant, as well as to many of our vehicles. In addition, while our water treatment plant remained operational, the lack of electricity forced us to operate on generator power until electric power was restored within the next two days. We also had to address more than 4,000 leaking customer service lines and 25 torn fire service lines. Because it was not possible to maintain system pressure initially, the Missouri Department of Natural Resources issued a boil water order. The order was lifted after we restored full pressure to the system, flushed the entire system and completed sampling tests, all within six days after the order was issued. Any interruption in our ability to supply water or to collect, treat and properly dispose of wastewater, or any costs associated with restoring service, could adversely affect our financial condition and results of operations.

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Furthermore, losses from business interruptions or damage to our facilities might not be covered by our insurance policies and such losses may make it difficult for us to secure insurance at acceptable rates in the future.

Adverse economic conditions can cause our customers, particularly industrial customers, to curtail operations. A curtailment of operations by an industrial customer would typically result in reduced water usage. In more severe circumstances, the decline in usage could be permanent. Any decrease in demand resulting from difficult economic conditions could adversely affect our financial condition and results of operations.

Regulatory and environmental risks associated with the collection, treatment and disposal of wastewater may impose significant costs.

The wastewater collection, treatment and disposal operations of our subsidiaries are subject to substantial regulation and involve significant environmental risks. If collection or treatment systems fail, overflow, or do not operate properly, untreated wastewater or other contaminants could spill onto nearby properties or into nearby streams and rivers, causing damage to persons or property, injury to aquatic life and economic damages, which may not be recoverable in rates. This risk is most acute during periods of substantial rainfall or flooding, which are the main causes of sewer overflow and system failure. Liabilities resulting from such damage could adversely and materially affect our business, results of operations and financial condition. Moreover, if we are deemed liable for any damage caused by overflow, our losses might not be covered by insurance, and such losses may make it difficult for us to secure insurance at acceptable rates in the future.

Our inability to efficiently implement our business transformation project, could result in higher than expected costs or otherwise adversely impact our operations and profitability.

We have undertaken a “business transformation” project, which is intended to improve our business processes and upgrade our antiquated core information technology systems. This multi-year, enterprise-wide initiative is intended to support our broader strategic initiatives. The project is intended to optimize workflow throughout our field operations, improve our back-office operations and enhance our customer service capabilities. The scale and anticipated future costs associated with the business transformation project are significant and we could incur costs significantly in excess of budgeted costs. Any technical or other difficulties in developing or implementing this initiative may increase the costs of the project and have an adverse effect on our operations and reporting processes, including our internal control over financial reporting. When we make adjustments to our operations, we may incur incremental expenses prior to realizing the benefits of a more efficient workforce and operating structure. Further, we may not realize anticipated cost improvements and greater efficiencies from the project. We can provide no guarantee that we will be able to achieve timely or adequate rate recovery of any increased costs associated with the business transformation project. As of December 31, 2011, expenditures on the project totaled $139.7 million. We anticipate that total expenditures of as much as $280 million will be required to complete the project.

Currently, we operate numerous information technology systems that have varying degrees of integration, sometimes leading to inefficiencies. Therefore, delays in completion of the business transformation project will also delay cost savings and efficiencies expected to result from the project. We may also experience difficulties consolidating our current systems, moving to a common set of operational processes and implementing a successful change management process. These difficulties may impact our ability to meet customer needs efficiently. Any such delays or difficulties may have a material and adverse impact on our business, client relationships and financial results.

Our Regulated Businesses require significant capital expenditures and may suffer if we fail to secure appropriate funding to make investments, or if we experience delays in completing major capital expenditure projects.

The water and wastewater utility business is very capital intensive. We invest significant amounts of capital to add, replace and maintain property, plant and equipment. In 2011, we invested $924.9 million in net

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Company-funded capital improvements. The level of capital expenditures necessary to maintain the integrity of our systems could increase in the future. We fund capital improvement projects using cash generated from operations, borrowings under our revolving credit facility and commercial paper programs and issuances of long-term debt and equity securities. We can provide no assurance that we will be able to access the debt and equity capital markets on favorable terms or at all.

In addition, we believe that our dividend policy could limit our ability to pursue growth. In particular, the use of cash to pay dividends could affect our ability to make large acquisitions or pursue other growth opportunities that require cash investments in amounts greater than our available cash and external financing resources. In order to fund construction expenditures, acquisitions (including tuck-in acquisitions), principal and interest payments on our indebtedness, and dividends at the level currently anticipated under our dividend policy, we expect that we will need additional financing. However, we intend to retain sufficient cash from operating activities after the distribution of dividends to fund a portion of our capital expenditures.

If we do not obtain sufficient capital, we may be unable to maintain our existing property, plant and equipment, realize our capital investment strategies, meet our growth targets and successfully expand the rate base upon which we are able to earn future returns on our investment and a return of our investment. Even if we have adequate resources to make required capital expenditures, we face the additional risk that we will not complete our major capital expenditures on time, as a result of construction delays or other obstacles. Each of these outcomes could adversely affect our financial condition and results of operations.

Weather conditions could adversely affect demand for our water service and our revenues.

Demand for our water during the warmer months is generally greater than during cooler months due primarily to additional requirements for water in connection with irrigation systems, swimming pools, cooling systems and other outside water use. Throughout the year, and particularly during typically warmer months, demand tends to vary with temperature, rainfall levels and rainfall frequency. In the event that temperatures during the typically warmer months are cooler than normal, or if there is more rainfall than normal, the demand for our water may decrease and adversely affect our revenues.

Our inability to access the capital or financial markets could affect our ability to meet our liquidity needs at reasonable cost and our ability to meet long-term commitments, which could adversely affect our financial condition and results of operations.

In addition to cash from operations, we rely on our revolving credit facility, commercial paper programs, and the capital markets to satisfy our liquidity needs. In this regard, our principal external source of liquidity is our revolving credit facility. We regularly use our commercial paper program as a principal source of short-term borrowing due to the generally more attractive rates we obtain in the commercial paper market. However, disruptions in the capital markets could limit our ability to access capital. For example, in September 2008, we were unable to access short-term liquidity through our commercial paper program, and were compelled to borrow under our credit facilities with a syndicate of banks. This resulted in an increase in our borrowing costs until the time we again were able to access the commercial paper market. Although our difficulties in accessing capital were resolved as the severity of the recent financial crisis subsided, we cannot assume that similar adverse events in the financial markets will not occur again in the future. Moreover, while our credit facility lending banks have met all of their obligations, disruptions in the credit markets, changes in our credit ratings, or deterioration of the banking industry’s financial condition could discourage or prevent lenders from meeting their existing lending commitments, extending the terms of such commitments, or agreeing to new commitments. In order to meet our short-term liquidity needs, particularly if borrowings through the commercial paper market are unavailable, we maintain an $840 million revolving credit facility. Commitments of $685 million under this revolving credit facility mature on September 15, 2013, and the remaining $155 million of commitments expire on September 15, 2012. Our inability to renew or replace these commitments could materially increase our cost of capital and adversely affect our financial condition, results of operations and liquidity.

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American Water Capital Corp. (“AWCC”), our financing subsidiary, had no outstanding borrowings under the credit facilities and $32.0 million of outstanding letters of credit under this credit facility as of February 21, 2012. AWCC had $94.7 million of outstanding commercial paper as of February 21, 2012. We cannot assure that our lenders will meet their existing commitments or that we will be able to access the commercial paper or loan markets in the future on terms acceptable to us or at all.

Longer term disruptions in the capital and credit markets as a result of uncertainty, reduced financing alternatives, or failures of significant financial institutions could adversely affect our access to the liquidity needed for our business. Any significant disruption in the capital and credit markets, or financial institution failures could require us to take measures to conserve cash until the market stabilizes or until alternative financing can be arranged. Such measures could include deferring capital expenditures, reducing or suspending dividend payments, and reducing other discretionary expenditures.

Any impediments to our access to the capital markets, failure of our lenders to meet their commitments, increased interest expense, or cash conservation measures resulting from financial market disruptions or otherwise could adversely affect our business, financial condition, results of operations, cash flow, and liquidity.

Market conditions may unfavorably impact the value of benefit plan assets and liabilities, as well as assumptions related to the benefit plans, which may require us to provide significant additional funding.

The performance of the capital markets affects the values of the assets that are held in trust to satisfy significant future obligations under our pension and postretirement benefit plans. These assets are subject to market fluctuations, which may cause investment returns to fall below our projected return rates. A decline in the market value of the pension and postretirement benefit plan assets will increase the funding requirements under our pension and postretirement benefit plans if future returns on these assets are insufficient to offset the decline in value. Additionally, the Company’s pension and postretirement benefit plan liabilities are sensitive to changes in interest rates. As interest rates decrease, thereby reducing returns, our liabilities increase, potentially increasing benefit expense and funding requirements. Further, changes in demographics, including increased numbers of retirements or increases in life expectancy assumptions may also increase the funding requirements of our obligations related to the pension and other postretirement benefit plans. Future increases in pension and other postretirement costs as a result of reduced plan assets may not be fully recoverable in rates, and our results of operations and financial position could be negatively affected.

In addition, market factors can affect assumptions we use in determining funding requirements with respect to our pension and postretirement plans. For example, a relatively modest change in our assumptions regarding discount rates can materially affect our calculation of funding requirements. To the extent that market data compels us to reduce the discount rate used in our assumptions, our benefit obligations could be materially increased, which could adversely affect our financial position and results of operations.

Our indebtedness could affect our business adversely and limit our ability to plan for or respond to changes in our business, and we may be unable to generate sufficient cash flows to satisfy our liquidity needs.

As of December 31, 2011, our indebtedness (including preferred stock with mandatory redemption requirements) was $5,905.0 million, and our working capital (defined as current assets less current liabilities) was in a deficit position. Our indebtedness could have important consequences, including:

• limiting our ability to obtain additional financing to fund future working capital requirements or capital expenditures;

• exposing us to interest rate risk with respect to the portion of our indebtedness that bears interest at a variable rate;

• limiting our ability to pay dividends on our common stock or make payments in connection with our other obligations;

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• impairing our access to the capital markets for debt and equity

• likely requiring that an increasing portion of our cash flows from operations be dedicated to the payment of the principal of and interest on our debt, thereby reducing funds available for future operations, acquisitions, dividends on our common stock or capital expenditures;

• limiting our ability to take advantage of significant business opportunities, such as acquisition opportunities, and to react to changes in market or industry conditions; and

• placing us at a competitive disadvantage compared to those of our competitors that have less debt.

In order to meet our capital expenditure needs, we may be required to make additional borrowings under our credit facilities or issue new debt securities in the capital markets. Moreover, additional borrowings may be required to refinance outstanding indebtedness. Debt maturities and sinking fund payments in 2012 and 2013 are $28.9 million and $112.6 million, respectively. We can provide no assurances that we will be able to access the debt capital markets on favorable terms, if at all. If new debt is added to our current debt levels, the related risks we now face could intensify, limiting our ability to refinance existing debt on favorable terms.

We will depend primarily on operations to fund our expenses and to pay the principal and interest on our outstanding debt. Therefore, our ability to pay our expenses and satisfy our debt service obligations depends on our future performance, which will be affected by financial, business, economic, competitive, legislative, regulatory and other factors beyond our control. If we do not have sufficient cash flows to pay the principal and interest on our outstanding debt, we may be required to refinance all or part of our existing debt, sell assets, borrow additional funds or sell additional equity. In addition, if our business does not generate sufficient cash flows from operations, or if we are unable to incur indebtedness sufficient to enable us to fund our liquidity needs, we may be unable to plan for or respond to changes in our business, which could cause our operating results and prospects to be affected adversely.

Work stoppages and other labor relations matters could adversely affect our results of operations.

Currently, approximately 49% of our workforce is represented by unions. We have 83 collective bargaining agreements in place with 19 different unions representing our unionized employees. We might not be able to renegotiate labor contracts on terms that are favorable to us. Any negotiations or dispute resolution processes undertaken in connection with our labor contracts could be delayed or affected by labor actions or work stoppages. Labor actions, work stoppages or the threat of work stoppages, and our failure to obtain favorable labor contract terms during renegotiations may adversely affect our financial condition, results of operations, cash flows and liquidity. In September 2010, we declared “impasse” in negotiations of our national benefits agreement with most of the labor unions representing employees in our Regulated Businesses. The prior agreement expired on July 31, 2010; however, negotiations did not produce a new agreement. We implemented our “last, best and final” offer on January 1, 2011 in order to provide health care coverage for our employees in accordance with the terms of the offer. The unions have challenged our right to implement our last, best, and final offer. In this regard, following the filing by the Utility Workers Union of America of an unfair labor practice charge, the National Labor Relations Board (“NLRB”) issued a complaint against us in January 2012, claiming that we implemented the last, best and final offer without providing sufficient notice of the existence of a dispute with the Federal Mediation and Conciliation Service, a state mediation agency, and several state departments of labor. We have asserted that we did, in fact, provide sufficient notice. A hearing date on the matter has not been set. In addition, six local unions filed grievances or demands for arbitration under their respective local collective bargaining agreements regarding our implementation of the last, best and final offer. In response, we filed a declaratory judgment action against the local unions in United States District Court for the District of New Jersey seeking, among other things, an injunction preventing the unions from filing grievances or demanding arbitration under the local collective bargaining agreements with respect to the implementation of our last, best and final offer. Three of the unions were removed from the litigation after they agreed to a dismissal with prejudice. Two of the unions were removed from the New Jersey District Court action, and the Company is pursuing similar declaratory judgment actions against the unions in United States District Courts in Pennsylvania and West Virginia. We will continue to defend our position in any challenge presented by the unions. In addition to

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the expired national benefit agreement, five local union contracts covering approximately 700 employees expired without a new agreement being reached prior to December 31, 2011. One contract relating to employees in St. Louis, Missouri was negotiated to impasse and our last, best, and final offer was implemented on July 11, 2011. In addition, over one-quarter of our local union contracts will expire during 2012. Although no work stoppages have occurred with respect to the expired contracts described above, we cannot provide assurance that a work stoppage or strike will not occur. While we have developed contingency plans to be implemented as necessary if a work stoppage or strike does occur, we cannot assure that a strike or work stoppage would not have a material adverse impact on our results of operations, financial position or cash flows.

Contamination of our sources of water could result in service interruptions and human exposure to hazardous substances and subject our subsidiaries to civil or criminal enforcement actions, private litigation and cleanup obligations.

Our water supplies are subject to contamination, including contamination from naturally-occurring compounds, chemicals in groundwater systems, pollution resulting from man-made sources, such as perchlorate and methyl tertiary butyl ether (“MTBE”), and possible terrorist attacks. If one of our water supplies is contaminated, we may have to interrupt the use of that water supply and locate an adequate supply of water from another water source, including, in some cases, through the purchase of water from a third-party supplier. If we are unable to access a substitute water supply in a cost-effective manner, our financial condition, results of operations, cash flows, liquidity and reputation may be adversely affected. In addition, we may incur significant costs in order to treat the contaminated source through expansion of our current treatment facilities, or development of new treatment methods. We might not be able to recover costs associated with treating or decontaminating water supplies through rates, or recovery of these costs may not occur in a timely manner. Moreover, we could be held liable for environmental damage as well as damages arising from toxic tort or other lawsuits, criminal enforcement actions, contractual obligations or other consequences arising out of human exposure to hazardous substances in our drinking water supplies.

The failure of, or the requirement to repair, upgrade or dismantle, any of our dams may adversely affect our financial condition and results of operations.

We own approximately 100 dams. A failure of any of those dams could result in injuries and downstream property damage for which we may be liable. The failure of a dam would also adversely affect our ability to supply water in sufficient quantities to our customers and could adversely affect our financial condition and results of operations. Any losses or liabilities incurred due to a failure of one of our dams might not be covered by insurance policies or be recoverable in rates, and such losses may make it difficult for us to secure insurance at acceptable rates in the future.

We also are required from time to time to decommission, repair or upgrade the dams that we own. The cost of such repairs can be and has been material. We might not be able to recover such costs through rates. The inability to recover these higher costs or delayed recovery of the costs as a result of regulatory lag can affect our financial condition, results of operations, cash flows and liquidity. The federal and state agencies that regulate our operations may adopt rules and regulations requiring us to dismantle our dams. In Monterey County, California, CAWC filed an application with the CPUC in September, 2010 to seek approval for a project to reroute the Carmel River and remove the San Clemente Dam, which is owned by CAWC. As part of the application, CAWC is seeking recovery of certain historical costs, totaling approximately $26.9 million, related to studies to determine whether the dam could withstand significant flooding and severe earthquakes meeting defined criteria, efforts to develop a project to address seismic issues, the identification and analysis of possible alternative project options, and activities undertaken pursuant to the directives of Federal and State government agencies, including the California Department of Water Resources, Division of Safety of Dams (“DSOD”), which is acting as the lead agency under the State and Federal environmental review laws. On November 10, 2011, a Proposed Decision (“PD”) was issued by the administrative law judge assigned to the matter. In the PD, the administrative law judge recommended that recovery of virtually all of the historical costs should be denied.

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CAWC has filed comments with the CPUC contending that the PD is unreasonable, unsupported by and contrary to the evidence, and contrary to law and policy. The PD is currently under review by the CPUC, which has delayed issuing a decision on several occasions and most recently has indicated that it will not vote on a decision until April 19, 2012. While we believe there are sound reasons for the CPUC to modify the PD to permit recovery of the historical costs, in the event recovery is not permitted, our results of operations would be materially adversely affected for the period in which we incur a charge with respect to the write off of the historical costs, most of which currently are recorded as regulatory assets, and our cash flows in future years would be adversely affected.

Any failure of our network of water and wastewater pipes and water reservoirs could result in losses and damages that may affect our financial condition and reputation.

Our operating subsidiaries distribute water and collect wastewater through an extensive network of pipes and store water in reservoirs located across the United States. A failure of major pipes or reservoirs could result in injuries and property damage for which we may be liable. The failure of major pipes and reservoirs may also result in the need to shut down some facilities or parts of our network in order to conduct repairs. Such failures and shutdowns may limit our ability to supply water in sufficient quantities to our customers and to meet the water and wastewater delivery requirements prescribed by government regulators, including state PUCs with jurisdiction over our operations, and adversely affect our financial condition, results of operations, cash flows, liquidity and reputation. Any business interruption or other losses might not be covered by insurance policies or be recoverable in rates, and such losses may make it difficult for us to secure insurance at acceptable rates in the future. Moreover, to the extent such business interruptions or other losses are not covered by insurance, they may not be recovered through rate adjustments.

Risks associated with our portfolio optimization efforts may adversely affect us.

Under our portfolio optimization initiative, we will continue to seek to acquire or invest in additional water and/or wastewater systems while disposing of other systems. These transactions are designed to enable us to achieve a more rationalized portfolio, cost structure improvements and an enhanced financial profile. We will consider acquiring systems in markets in the United States where we do not currently operate our Regulated Businesses and through tuck-ins. We also will continue to seek to enter into related market-based businesses and services that complement our businesses. Acquisition transactions may result in:

• incurrence of debt and contingent liabilities;

• dilutive issuances of our equity securities;

• failure to realize anticipated benefits;

• failure of acquired entities to have or to maintain effective internal control over financial reporting;

• fluctuations in quarterly results;

• exposure to unknown risks and liabilities, such as environmental liabilities; and

• other acquisition-related expenses.

With respect to dispositions, we may be unable to sell, on acceptable terms, systems that we no longer believe are suitable for our portfolio.

We may also experience difficulty in obtaining required regulatory approvals for acquisitions or dispositions, and any regulatory approvals we obtain may require us to agree to costly and restrictive conditions imposed by regulators. We may not identify all significant risks when reviewing a potential transaction, and we could be exposed to potential liabilities for which we will not be indemnified or, in the case of dispositions, we may be required to continue to assume liabilities with respect to systems that we sell. We also may encounter difficulties in integrating new businesses, including bringing newly acquired businesses up to the necessary level of regulatory compliance, retaining and integrating key personnel, achieving strategic objectives and integrating

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acquired assets and technological systems. The demands of identifying and transitioning newly acquired businesses or pursuing investment opportunities may also divert management’s attention from other business concerns and otherwise disrupt our business. Any of these risks may adversely affect our financial condition, results of operations and cash flows.

Changes in laws and regulations over which we have no control and changes in certain agreements can significantly affect our business and results of operations.

New legislation, regulations, government policies or court decisions can materially affect our operations. The individuals who serve as regulators are elected or are political appointees. Therefore, elections which result in a change of political administration or new appointments may also result in changes in the individuals who serve as regulators and the policies of the regulatory agencies that they serve. New laws or regulations, new interpretations of existing laws or regulations, changes in agency policy, including those made in response to shifts in public opinion, or conditions imposed during the regulatory hearing process may affect our business in a number of ways that could have an adverse effect on our business, financial condition, results of operations, cash flows and liquidity, including the following:

• making it more difficult for us to raise our rates and, as a consequence, to recover our costs or earn our expected rates of return;

• changing the determination of the costs, or the amount of costs, that would be considered recoverable in rate cases;

• changing water quality or delivery service standards or wastewater collection, treatment, discharge and disposal standards with which we must comply;

• restricting our ability to terminate our services to customers who owe us money for services previously provided or limiting our bill collection efforts;

• requiring us to provide water services at reduced rates to certain customers;

• restricting our ability to buy or sell assets or issue securities;

• changing regulations that affect the benefits we expected to receive when we began offering services in a particular area;

• changing or placing additional limitations on change in control requirements relating to any concentration of ownership of our common stock;

• making it easier for governmental entities to convert our assets to public ownership via eminent domain;

• placing limitations, prohibitions or other requirements on the sharing of information and transactions by or between a regulated utility and its affiliates, including us, our service company and any of our other subsidiaries;

• restricting or prohibiting our extraction of water from rivers, streams, reservoirs or aquifers; and

• revoking or altering the terms of the certificates of public convenience and necessity (or similar authorizations) issued to us by state PUCs.

We have recorded a significant amount of goodwill, and we may never realize the full value of our intangible assets, causing us to record impairments that may negatively affect our results of operations.

Our total assets include substantial goodwill. At December 31, 2011, our goodwill totaled $1,195.1 million. The goodwill is primarily associated with the acquisition of American Water by an affiliate of our previous owner in 2003 and the acquisition of E’Town Corporation by a predecessor to our previous owner in 2001. Goodwill represents the excess of the purchase price the purchaser paid over the fair value of the net tangible and

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intangible assets acquired. Goodwill is recorded at fair value on the date of an acquisition and is reviewed annually or more frequently if changes in circumstances indicate the carrying value may not be recoverable. As required by the applicable accounting rules, we have taken significant non-cash charges to operating results for goodwill impairments in the past. In the first quarter of 2009, we recorded a non-cash charge to our financial results for a goodwill impairment in the amount of $450.0 million, which reduced net income by $443.0 million. In the aggregate, goodwill impairment charges including those recognized in our discontinued operations taken in each year from 2006 through 2009 totaled approximately $1.93 billion and reduced net income by approximately $1.91 billion.

We may be required to recognize an impairment of goodwill in the future due to market conditions or other factors related to our performance. These market events could include a decline over a period of time of our stock price, a decline over a period of time in valuation multiples of comparable water utilities, the lack of an increase in our market price consistent with our peer companies, or decreases in control premiums. A decline in the forecasted results in our business plan, such as changes in rate case results or capital investment budgets or changes in our interest rates, could also result in an impairment charge. Recognition of impairments of a significant portion of goodwill would negatively affect our reported results of operations and total capitalization, the effect of which could be material and could make it more difficult to maintain its credit ratings, secure financing on attractive terms, maintain compliance with debt covenants and meet expectations of our regulators.

The assets of our Regulated Businesses are subject to condemnation through eminent domain.

Municipalities and other government subdivisions have historically been involved in the provision of water and wastewater services in the United States, and organized efforts may arise from time to time in one or more of the service areas in which our Regulated Businesses operate to convert our assets to public ownership and operation through exercise of the governmental power of eminent domain. Should a municipality or other government subdivision seek to acquire our assets through eminent domain, we may resist the acquisition. Contesting an exercise of condemnation through eminent domain may result in costly legal proceedings and may divert the attention of the affected Regulated Business’s management from the operation of its business. Moreover, out efforts to resist the acquisition may not be successful.

If a municipality or other government subdivision succeeds in acquiring the assets of one or more of our Regulated Businesses through eminent domain, there is a risk that we will not receive adequate compensation for the business, that we will not be able to keep the compensation, or that we will not be able to divest the business without incurring significant one-time charges.

We may not be able to fully utilize our U.S. and state net operating loss carryforwards.

As of December 31, 2011, we had U.S. federal and state net operating loss (“NOL”) carryforwards of approximately $1,187.4 million and $739.8 million, respectively. Our federal NOL carryforwards begin to expire in 2024, and our state NOL carryforwards will expire between 2012 and 2031. Our ability to utilize our NOL carryforwards is primarily dependent upon our ability to generate sufficient taxable income. Moreover, because our previous owner’s divestiture of its stock was considered an “ownership change” under Section 382 of the Internal Revenue Code, the amount of NOL carryforwards that may be utilized in any year is limited. Our management believes the federal NOL carryforwards are more likely than not to be recovered and therefore currently require no valuation allowance. At December 31, 2011, $196.1 million of the state NOL carryforwards have been offset by a valuation allowance because the Company does not believe these NOLs will more likely than not be realized in the future, and we have, in the past, been unable to utilize certain of our NOLs. The establishment or increase of a valuation allowance in the future would reduce our deferred income tax assets and our net income.

Our actual results may differ from those estimated by management in making its assessment as to our ability to use the NOL carryforwards. Moreover, changes in income tax laws, the economy and general business environment could affect the future utilization of the NOL carryforwards. If we are unable to fully utilize our NOL carryforwards to offset taxable income generated in the future, our financial position, results of operations and cash flows could be materially adversely affected.

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Our Market-Based Operations, through American Water (excluding our regulated subsidiaries) provide performance guarantees, including financial guarantees or deposits, to our public-sector and public clients, who may seek to enforce the guarantees if our Market-Based Operations do not satisfy certain obligations.

Under the terms of some of our agreements for the provision of services to water and wastewater facilities with municipalities, other governmental entities and other customers, American Water (excluding our regulated subsidiaries) provides guarantees of specified performance obligations of our Market-Based Operations, including financial guarantees or deposits. In the event our Market-Based Operations fail to perform these obligations, the entity holding the guarantees may seek to enforce the performance commitments against us or proceed against the deposit. In that event, our financial condition, results of operations, cash flows, and liquidity could be adversely affected.

At December 31, 2011, we had remaining performance commitments as measured by remaining contract revenue totaling approximately $3,113.0 million, and this amount is likely to increase if our Market-Based Operations grow. The presence of these commitments may adversely affect our financial condition and make it more difficult for us to secure financing on attractive terms.

Our Market-Based Operations’ long-term contracts with the Department of Defense may be terminated for the convenience of the U.S. Government and are subject to periodic contract price redetermination.

All of our contracts with the Department of Defense for the operation and maintenance of water and wastewater systems may be terminated, in whole or in part, prior to the end of the 50-year term for convenience of the U.S. Government or as a result of default or non-performance by the subsidiary performing the contract. In addition, the contract price for each of these military contracts is subject to redetermination two years after commencement of operations and every three years thereafter. Price redetermination is a contract mechanism to periodically adjust the service fee in the next period to reflect changes in contract obligations and anticipated market conditions. Any early contract termination or unfavorable price redetermination could adversely affect our results of operations.

We operate a number of water and wastewater systems under O&M contracts and face the risk that the owners of those systems may fail to maintain those systems, which may negatively affect us as the operators of the systems.

We operate a number of water and wastewater systems under O&M contracts. Pursuant to these contracts, we operate the system according to the standards set forth in the applicable contract, and it is generally the responsibility of the owner to undertake capital improvements. In some cases, we may not be able to convince the owner to make needed improvements in order to maintain compliance with applicable regulations. Although violations and fines incurred by water and wastewater systems may be the responsibility of the owner of the system under these contracts, those non-compliance events may reflect poorly on us as the operator of the system and damage our reputation, and in some cases, may result in liability to the same extent as if we were the owner.

Our Market-Based Operations are party to long-term contracts to operate and maintain water and wastewater systems under which we may incur costs in excess of payments received.

Some of our Market-Based Operations enter into long-term contracts pursuant to which they agree to operate and maintain a municipality’s, federal government’s or other party’s water or wastewater treatment and delivery facilities, which includes responsibility for certain major maintenance for some of those facilities, in exchange for an annual fee. Our Market-Based Operations are generally subject to the risk that costs associated with operating and maintaining the facilities, including production costs such as purchased water, electricity, fuel and chemicals used in water treatment, may exceed the fees received from the municipality or other contracting party. In addition, directly or through our market-based subsidiaries, we often guarantee our Market-Based Operations’ obligations under those contracts. Losses under these contracts or guarantees may adversely affect our financial condition, results of operations, cash flows and liquidity.

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We rely on our information technology (“IT”) systems to assist with the management of our business and customer and supplier relationships, and a disruption of these systems could adversely affect our business.

Our IT systems are an integral part of our business, and a serious disruption of our IT systems could significantly limit our ability to manage and operate our business efficiently, which, in turn, could cause our business and competitive position to suffer and adversely affect our results of operations. We depend on our IT systems to bill customers, process orders, provide customer service, manage construction projects, manage our financial records, track assets, remotely monitor certain of our plants and facilities and manage human resources, inventory and accounts receivable collections. Our IT systems also enable us to purchase products from our suppliers and bill customers on a timely basis, maintain cost-effective operations and provide service to our customers. A number of our current IT systems are antiquated, and it is increasingly difficult to obtain upgrades to, and support for, these systems. While we intend to replace these systems through the business transformation process described above, for the time being we remain subject to risks that are underscored by the age of our IT systems. Specifically, our IT systems are vulnerable to damage or interruption from:

• power loss, computer systems failures, and internet, telecommunications or data network failures;

• operator negligence or improper operation by, or supervision of, employees;

• physical and electronic loss of customer data due to security breaches, misappropriation and similar events;

• computer viruses;

• intentional acts of vandalism and similar events; and

• hurricanes, fires, floods, earthquakes and other natural disasters.

These events may result in physical and electronic loss of customer or financial data, security breaches, misappropriation and other adverse consequences. In addition, the lack of redundancy for certain of our IT systems, including billing systems, could exacerbate the impact of any of these events on us.

In addition, we may not be successful in developing or acquiring technology that is competitive and responsive to the needs of our business, and we might lack sufficient resources to make the necessary upgrades or replacements of our outdated existing technology to allow us to continue to operate at our current level of efficiency.

We may be required to adopt International Financial Reporting Standards (“IFRS”) or changes in generally accepted accounting principles in the United States (“GAAP”) that, among other things, could limit our ability to defer recognition of costs deemed material or otherwise could negatively impact our business, financial condition or results of operations.

Currently, our accounting and financial reporting is based on GAAP. In 2008, the SEC proposed a series of milestones, sometimes referred to as the “Proposed Roadmap,” that would guide the SEC in determining whether to transition from GAAP to IFRS. Among matters considered by the SEC was a staged transition into IFRS reporting for public companies, beginning for fiscal years ending on or after December 15, 2014 for the largest public companies. However, persons commenting on the Proposed Roadmap expressed differing views about the proposed approach. In response, the SEC issued a statement in February 2010 that, while expressing the SEC’s continued support for a single set of high-quality global accounting standards, directed the SEC staff to execute a work plan to aid the SEC in evaluating the impact that the use of IFRS by U.S. companies would have on the securities market. The SEC staff has not yet issued a final report on the work plan. Recent statements by the SEC staff have indicated that the final report on the work plan may be expected in 2012. It is unclear whether the SEC will decide whether, and if so when, IFRS would be incorporated into financial reporting by U.S. public companies.

Another initiative that has affected financial reporting by U.S. public companies is efforts by the U.S. Financial Accounting Standards Board, or the “FASB,” and the International Accounting Standards Board, or the

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“IASB,” to develop compatible accounting standards for use in both domestic and cross-border financial reporting. The FASB and IASB have worked on a number of projects to achieve accounting convergence with respect to specific accounting topics, which have resulted in the adoption of some new standards and continuing efforts on other topics.

Under GAAP, we are subject to the accounting procedures to address the effects of certain types of regulation, which, among other things, allow us to defer recognition of certain costs and record them on the balance sheet as regulatory assets if we believe it is probable that we will be allowed to recover those costs through future rate increases. Currently, IFRS does not contain provisions equivalent to the current GAAP accounting procedures. The adoption of the IFRS standards or the adoption of other new accounting or financial reporting standards, either through the convergence efforts of the FASB and IASB or otherwise, could affect our reported performance, which in turn could unfavorably impact our business, financial condition or results of operations. Furthermore, the transition to and application of new accounting or financial reporting standards could result in increased administrative costs.

ITEM 1B. UNRESOLVED STAFF COMMENTS

None.

ITEM 2. PROPERTIES

Our properties consist of transmission and distribution mains and conduits, water and wastewater treatment plants, pumping wells, tanks, meters, supply lines, dams, reservoirs, buildings, vehicles, land, easements, software rights and other facilities and equipment used for the operation of our systems, including the collection, treatment, storage and distribution of water, and the collection and treatment of wastewater. Substantially all of our properties are owned by our subsidiaries, and a substantial portion of our property is subject to liens of our mortgage bonds. We lease our corporate offices, equipment and furniture, located in Voorhees, New Jersey from certain of our wholly-owned subsidiaries. These properties are utilized by our directors, officers and staff in the conduct of the business.

Our regulated subsidiaries own, in the states in which they operate, transmission and distribution mains, pump stations, treatment plants, storage tanks, reservoirs and related facilities. A substantial acreage of land is owned by our Regulated Businesses, the greater part of which is located in watershed areas, with the balance being principally sites of pumping and treatment plants, storage reservoirs, tanks and standpipes. Our Market-Based Operations’ properties consist mainly of spreading and waste transportation equipment, office furniture and IT equipment and are primarily located in New Jersey and Canada. Approximately 50% of all our properties are located in New Jersey and Pennsylvania.

We maintain property insurance against loss or damage to our properties by fire or other perils, subject to certain exceptions. For insured losses, we are self-insured to the extent that any losses are within the policy deductible or exceed the amount of insurance maintained. Any such losses could have a material adverse effect on our consolidated financial condition or results of operations.

We believe that our properties are generally maintained in good operating condition and in accordance with current standards of good water and wastewater works industry practice, and units of property are replaced as and when necessary.

ITEM 3. LEGAL PROCEEDINGS

Alternative Water Supply in Lieu of Carmel River Diversions

In 1995, the California State Water Resources Control Board issued an administrative order (the “1995 Order”) to CAWC requiring CAWC to implement an alternative water supply in lieu of diversions from the Carmel River.

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The State Water Resources Control Board held administrative hearings in the summer of 2008 to address claims that CAWC has exceeded its water diversion rights in the Carmel River and has not diligently pursued establishing an alternative water supply as required by the 1995 Order. The State Water Resources Control Board adopted a Cease and Desist Order applicable to CAWC on October 20, 2009 (the “2009 Order”). The 2009 Order finds that CAWC has not sufficiently implemented actions to terminate its unpermitted diversions from the Carmel River as required by the 1995 Order. The 2009 Order requires, among other things, that CAWC significantly decrease its yearly diversions from the Carmel River according to a set reduction schedule running from the date the 2009 Order was adopted until December 31, 2016, at which point all unpermitted diversions must end. Failure to effect the decrease in diversions mandated by the 2009 Order could result in substantial penalties. The 2009 Order also requires that CAWC plan, design and implement, within 24 months of the date the 2009 Order was adopted, a project or projects designed to reduce the need for Carmel River diversions by at least 500 acre feet per year. CAWC constructed an aquifer storage and recovery well that satisfied this requirement in advance of the 24 month deadline. CAWC has appealed the 2009 Order to the Superior Court of California challenging the findings and requirements of the 2009 Order. We can provide no assurances, however, that the appeal will be successful or that, if unsuccessful, CAWC will be able to comply with the diversion reduction requirements and other remaining requirements under the 2009 Order or that any such compliance will not result in material additional costs or obligations to us. On December 2, 2010, the CPUC approved the Project, involving the construction of a desalination facility on the California central coast, north of Monterey. The Project was to be implemented through Agreements among the MCWD, the MCWRA and CAWC. As part of the Project, a conveyance pipeline from the desalination facility, designed to facilitate CAWC’s purchase of water from the facility, was to be constructed by CAWC. The CPUC also approved construction of four additional pipelines and two pump stations (the “Ancillary Facilities”). The desalination facility was to be constructed and owned by MCWD, and MCWRA was to construct the wells that were to supply water to the desalination facility. The Project was intended, among other things, to fulfill CAWC’s obligations under the 1995 Order, in addition to other obligations.

The Project was subject to delay due to, among other things, funding delays and investigations and inquiries initiated by public authorities relating to an alleged conflict of interest concerning a former member of the MCWRA Board of Directors (the “Former Director”). The Former Director was paid for consulting work by a contractor to MCWD while serving on the MCWRA Board of Directors. The contractor subsequently was retained as project manager for the Project. On July 7, 2011, MCWRA advised MCWD and CAWC that the Agreements were void as a result of the conduct of the Former Director. Subsequently, on August 12, 2011, CAWC advised MCWD and MCWRA that they have defaulted in performance of certain financing obligations under the Water Purchase Agreement. By letter delivered to MCWD and MCWRA on September 28, 2011, CAWC terminated the Agreements, based on MCWRA’s repudiation of the Agreements. In other communications among the parties, each of MCWD and MCWRA have stated that it complied with the financing obligations, and MCWD further responded that, among other things, CAWC did not comply on a timely basis with an obligation under the Water Purchase Agreement that CAWC provide a letter of credit. MCWD has also asserted that the Agreements remain in effect.

CAWC, MCWRA and MCWD agreed to participate in a mediation process with respect to disputes among the parties relating to the Agreements. In October 2011, during the pendency of the mediation, CAWC filed the Petition with the CPUC seeking clarification that it may go forward with constructing the Ancillary Facilities regardless of the status of the Project. MCWD and the California Division of Ratepayer Advocates are opposing the Petition.

Ultimately, the mediation was not successful, and terminated on January 16, 2012. On January 17, 2012, CAWC announced that it has withdrawn support of the Agreements. In addition, CAWC has evaluated various alternatives to the Project. At a prehearing conference with respect to the Petition held on January 24, 2012, CAWC advised the administrative law judge assigned to the matter that it will seek CPUC approval of an alternate project. The administrative law judge directed CAWC to file, jointly with MCWD and MCWRA if

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possible, a status report addressing various issues related to the Project and to submit a compliance filing to address CAWC’s plans to move forward on a new project. The filings are due by March 1, 2012. We cannot predict the ultimate effect of the events described above on CAWC’s efforts to secure alternative sources of water.

San Clemente Dam

The San Clemente Dam is a 106-foot high concrete arch dam located approximately 18.5 miles from the Pacific Ocean on the Carmel River. It was constructed in 1921 and has been operated by CAWC since 1966. In 1980, the DOSD directed CAWC to evaluate the structural integrity of the dam in the event of severe earthquakes or floods that could overtop the dam. In 1992, CAWC concluded that under certain conditions, the San Clemente Dam might not be stable in the event of a “Maximum Credible Earthquake” (the maximum earthquake that appears capable of occurring under the presently known geologic framework). The studies also concluded that a “Probable Maximum Flood” (the flood that may be expected from the most severe combination of critical meteorological and hydrologic conditions that is reasonably possible in the drainage basin under study) could overtop the dam by fourteen feet and cause excessive erosion in the area of the downstream abutments. Based on these findings, DSOD ordered CAWC to improve the San Clemente Dam to address these issues.

Since 1992, there have been numerous engineering and environmental studies regarding the proposed solution to the San Clemente Dam’s stability. Although dam buttressing was originally the favored project of CAWC and DSOD, CAWC began to explore dam removal on a parallel track in response to comments made by the National Oceanic and Atmospheric Administration’s National Marine Fisheries Services (“NMFS”) on DSOD’s 1999 Draft Environmental Impact Report. DSOD certified the Final Environmental Impact Report/Environmental Impact Statement (“EIR/EIS”) in January 2008. The Final EIR/EIS focused on two possible projects, the dam buttressing project and a project to reroute the Carmel River and remove the dam (the “Reroute and Removal Project”), but remained neutral as to which project CAWC should pursue.

Currently, the Reroute and Removal Project is CAWC’s preferred project. Subject to CPUC approval and ratepayer recovery, CAWC has committed to pay an amount equivalent to the estimated cost of buttressing the dam (approximately $49 million). The California State Coastal Conservancy has committed to secure approximately $34 million from State, Federal, and private foundation resources to fund the difference between the approximate cost of dam buttressing and the cost of the Reroute and Removal Project. In September 2011, CAWC filed an application with the CPUC for authorization to implement the Reroute and Removal Project and to recover through rates the $49 million prospective costs associated with the Reroute and Removal Project over a twenty-year period. In addition, CAWC sought to recover certain historical costs, totaling approximately $26.9 million, related to studies to determine whether the dam could withstand a Probable Maximum Flood and or Maximum Credible Earthquake, efforts to develop a project to address seismic issues, the identification and analysis of possible alternative project options, and activities undertaken pursuant to the directives of Federal and State government agencies, including DSOD, which is acting as the lead agency under the State and Federal environmental review laws.

On November 10, 2011, the administrative law judge assigned to the application issued a PD denying recovery of virtually all of the historical costs, but providing recovery of the $49 million prospective costs over a twenty-year period. The administrative law judge also recommended placing a firm cap on projected costs (i.e., additional unanticipated costs could not be recovered), and imposing additional limitations such as exclusion of any equity return from the recovery and reduction of the amount to be recovered based on the appraisal value of land to be donated by CAWC. In response, CAWC filed comments with the CPUC contending that the PD is unreasonable, unsupported by and contrary to the evidence, and contrary to law and policy. On January 4, 2012, the administrative law judge issued a revised PD, recommending that CAWC be ordered to show cause why it should not be fined or otherwise sanctioned for an alleged misrepresentation regarding descriptions of the use of the dam as a point of water diversion. We believe the administrative law judge’s allegation is meritless and

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vigorously disagree with the administrative law judge’s characterization. CAWC has requested the opportunity to respond to the unfounded allegation and demonstrate that it is invalid.

CAWC has met with the CPUC Commissioners to communicate the various reasons it believes the PD should be modified or an alternate decision should be issued. The PD is currently under review by the CPUC, which has delayed issuing a decision on several occasions and most recently has indicated that it will not vote on a decision until April 19, 2012. While the Company believes there are sound reasons for the CPUC to modify the PD to permit recovery of at least most historical costs and overturn other recommendations adverse to CAWC, in the event recovery of the historical costs is not permitted, the Company would, among other things, incur a charge to earnings with respect to the write-off of most of the historical costs, which currently are reflected in regulatory assets.

Endangered Species Matters

In 1998, the National Oceanic and Atmospheric Administration, (the “NOAA”), listed the South Central California Coast steelhead trout as threatened pursuant to the federal Endangered Species Act, and subsequently designated the Carmel River as critical habitat for those trout. In 2001, CAWC entered into a conservation agreement with NOAA, requiring CAWC to implement certain measures to protect the steelhead trout and its habitat in the Carmel River watershed, study the removal of the previously mentioned San Clemente Dam and explore long-term water sources other than a new reservoir in the Carmel River. Since that time, CAWC has implemented a number of measures to reduce the impact of its operations on the steelhead trout and other species, including pursuing permits to construct the previously mentioned desalination project as an alternative source of water. In early 2004, NOAA informed CAWC of its concern that CAWC’s ongoing operations would cause the “take” of significant numbers of steelhead trout during the several remaining years required to implement the desalination project. In June 2006, CAWC and NOAA entered a settlement agreement whereby CAWC agreed to fund certain additional projects to improve habitat conditions for and aid in the recovery of steelhead trout in the Carmel River watershed. Under this 2006 agreement, CAWC was required, among other things, to make an initial payment of $3.5 million plus six annual installments of $1.1 million. The settlement agreement required that all payments made by CAWC to NOAA be used for mitigation projects in the Carmel River watershed. NOAA agreed not to assess any penalties or otherwise prosecute CAWC for any “take” of steelhead trout, so long as CAWC complied with the settlement agreement. Effective March 3, 2009, CAWC and NOAA executed an amended settlement agreement, which supersedes the 2006 agreement, to allow the required payments to be made to and managed by a California state agency under an existing mitigation program, thereby ensuring that settlement payments will be used for mitigation projects in the Carmel River watershed (the lack of such assurance caused CAWC to delay payments under the 2006 agreement). The 2009 amendment also extended the duration of the agreement for an additional year, which, among other things, resulted in CAWC’s agreement to make an additional $1.1 million payment and a one year extension of NOAA’s agreement not to assess any penalties or otherwise prosecute CAWC for any “take” of steelhead trout. Consistent with the amended agreement, CAWC paid an initial $3.5 million in April 2009, made the first $1.1 million installment payment in July 2010, the second $1.1 million installment payment in July 2011 and is scheduled to make the third installment payment in July 2012, and additional installment payments annually through July 2016. The settlement agreement authorizes CAWC to terminate these payments once CAWC has complied with the State Water Resources Control Board’s 1995 order to reduce its diversions.

The CPUC has authorized the recovery through rates of, and CAWC is recovering, the initial $3.5 million payment and the 2009 installment payment. CAWC’s application for recovery of the 2010 installment payment is pending before the CPUC, and CAWC plans to file an application for recovery of the 2011 and 2012 payments in the second half of 2012.

The settlement agreement also requires CAWC and NOAA to meet and negotiate a resolution to NOAA’s concerns regarding changes to CAWC’s operations on the Carmel River to protect the fish and improve its habitat. CAWC and NOAA have deferred these additional negotiations. CAWC also undertakes activities to

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protect the threatened California red-legged frog and its habitat in the Carmel River pursuant to a prior agreement with the U.S. Fish and Wildlife Service (“USFWS”). This agreement has expired, and CAWC is in discussions with USFWS to renew the agreement.

On March 14, 2008, the Sierra Club and the Carmel River Steelhead Association notified CAWC of their intent to file a citizen suit, 60 days therefrom, for violations of the federal Endangered Species Act alleging the “take” of steelhead trout by CAWC along the Carmel River and seeking injunctive relief to reduce river water diversions and increase river flow and fish passage facilities. On June 25, 2009, the Sierra Club and the Carmel River Steelhead Association filed suit in United States District Court for the Northern District of California, seeking to enjoin CAWC’s pumping on the Carmel River. The suit was dismissed on CAWC’s motion on January 8, 2010. The Sierra Club and the Carmel River Steelhead Association also filed an administrative complaint with the California State Water Resources Control Board in December 2008, claiming that certain fish passage facilities do not meet existing permit requirements. The State Water Resources Control Board has not acted on this complaint pending the completion of work that CAWC is undertaking to improve fish passage at that dam.

Other Matters

In addition, in November 2010, the Ontario Ministry of Justice commenced a proceeding against Terratec Environmental Ltd., one of the Company’s Canadian subsidiaries, alleging the violation of the Ontario Water Resource Act, in connection with the alleged discharge of anaerobic digestate into a creek that leads to Lake Ontario. Terratec has been engaged in negotiations with the Ontario Ministry of Justice to settle this matter and anticipates that penalties will not be material.

Periodically, the Company is involved in other proceedings or litigation arising in the ordinary course of business. We do not believe that the ultimate resolution of these matters will materially affect the Company’s financial position or results of operations. However, litigation and other proceedings are subject to many uncertainties, and the outcome of individual matters is not predictable with assurance. It is possible that some litigation and other proceedings could be decided unfavorably to us, and that any such unfavorable decisions could have a material adverse effect on the Company’s business, financial condition, results of operations, and cash flows.

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

Prior to April 23, 2008, there was no established public trading market for our common stock. Since April 23, 2008, our common stock has traded on the NYSE under the symbol “AWK.” As of February 21, 2012, there were 175,717,124 shares of common stock outstanding and approximately 1,179 record holders of common stock.

The following table sets forth the per-share range of the high and low closing sales prices of our common stock as reported on the NYSE and the cash dividends paid and declared per share for the years ended December 31, 2011 and 2010.

	2011										2010
	First Quarter		Second Quarter		Third Quarter		Fourth Quarter		Year		First Quarter		Second Quarter		Third Quarter		Fourth Quarter		Year
Dividends paid per common share	$	0.22	$	0.22	$	0.23	$	0.23	$	0.90	$	0.21	$	0.21	$	0.22	$	0.22	$	0.86
Dividend declared per common share	$	0.22	$	0.45	$	0.23	$	0.23	$	1.13	$	0.21	$	0.21	$	0.22	$	0.22	$	0.86
Price range of common stock
—High	$	28.33	$	30.70	$	31.03	$	32.78	$	32.78	$	23.23	$	22.15	$	23.49	$	25.73	$	25.73
—Low	$	25.17	$	27.87	$	25.39	$	28.34	$	25.17	$	20.75	$	19.92	$	20.00	$	23.47	$	19.92

For information on securities authorized for issuance under our equity compensation please, see Item 12, “Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters.”

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ITEM 6. SELECTED FINANCIAL DATA

	For the Years Ended December 31,
	2011		2010		2009			2008			2007
	(in thousands, except per share data)
Statement of operations data(1):
Operating revenues	$	2,666,236	$	2,555,035	$	2,290,446		$	2,193,157		$	2,067,124
Goodwill impairment charges		—		—	$	428,036		$	712,727		$	484,387
Operating income (loss)	$	803,136	$	728,122	$	183,835		$	(155,221	)	$	32,138
Income (loss) from continuing operations	$	304,929	$	255,072	$	(219,998	)	$	(529,291	)	$	(322,654	)
Income (loss) from continuing operations per basic common share(2)	$	$1.74	$	$1.46	$	(1.31	)	$	(3.31	)	$	(2.02	)
Income (loss) from continuing operations per diluted common share(2)	$	$1.73	$	$1.46	$	(1.31	)	$	(3.31	)	$	(2.02	)

	As of December 31,
	2011		2010		2009		2008		2007
	(in thousands)
Cash and cash equivalents	$	14,207	$	13,112	$	22,256	$	9,542	$	13,481
Utility plant and property, net of depreciation	$	10,872,042	$	10,241,342	$	9,708,885	$	9,218,396	$	8,502,333
Total assets	$	14,776,391	$	14,086,246	$	13,459,368	$	13,231,818	$	12,951,327
Short-term and long-term debt	$	5,882,956	$	5,658,473	$	5,434,463	$	5,251,979	$	4,949,359
Redeemable preferred stock	$	22,036	$	22,794	$	23,011	$	23,208	$	23,347
Total debt and redeemable preferred stock	$	5,904,992	$	5,681,267	$	5,457,474	$	5,275,187	$	4,972,706
Common stockholders’ equity	$	4,235,837	$	4,127,725	$	4,000,859	$	4,102,001	$	4,542,046
Preferred stock without mandatory redemption requirements	$	4,547	$	4,547	$	4,557	$	4,557	$	4,568
Total stockholders’ equity	$	4,240,384	$	4,132,272	$	4,005,416	$	4,106,558	$	4,546,614

	For the Years Ended December 31,
	2011			2010			2009			2008			2007
	(in thousands, except per share data)
Other data:
Cash flows provided by (used in):
Operating activities	$	808,357		$	774,933		$	596,156		$	552,169		$	473,712
Investing activities	$	(912,397	)	$	(746,743	)	$	(703,611	)	$	(1,033,667	)	$	(746,578	)
Financing activities	$	105,135		$	(37,334	)	$	120,169		$	477,559		$	256,593
Construction expenditures, included in investing activities	$	(924,858	)	$	(765,636	)	$	(785,265	)	$	(1,008,806	)	$	(750,810	)
Dividends paid per common share	$	0.90		$	0.86		$	0.82		$	0.40			—
Dividends declared per common share	$	1.13		$	0.86		$	0.82		$	0.40		$	—

(1) On September 28, 2007, Thames US Holdings, at the time an indirect wholly-owned subsidiary of RWE, was merged with and into American Water, with American Water as the surviving entity. American Water was an indirect wholly-owned subsidiary of RWE until its initial public offering in April 2008. The historical consolidated financial statements of American Water represent the consolidated results of the Company, formerly issued under the name Thames Water Aqua US Holdings, Inc. and Subsidiary Companies.

(2) The number of shares used to compute income (loss) from continuing operations per basic common share and income (loss) from continuing operations per diluted common share for the fiscal years ended December 31, 2007 is 160.0 million after giving effect to the 160,000-for-1 stock split on November 7, 2007. For the years ended December 31, 2009 and 2008, there are no dilutive incremental common shares included in diluted earnings per share as all potentially dilutive instruments would be anti-dilutive.

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ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

You should read the following discussion together with the financial statements and the notes thereto included elsewhere in this Form 10-K. This discussion contains forward-looking statements that are based on management’s current expectations, estimates and projections about our business, operations and financial performance. The cautionary statements made in this Form 10-K should be read as applying to all related forward-looking statements whenever they appear in this Form 10-K. Our actual results may differ materially from those currently anticipated and expressed in such forward-looking statements as a result of a number of factors, including those we discuss under “Risk Factors” and elsewhere in this Form 10-K. You should read “Risk Factors” and “Forward-Looking Statements.” Certain 2010 and 2009 amounts have been reclassified to conform to the 2011 presentation.

Executive Overview

General

American Water Works Company, Inc. (herein referred to as “American Water” or the “Company”) is the largest investor-owned United States water and wastewater utility company, as measured both by operating revenue and population served. Our approximately 7,000 employees provide drinking water, wastewater and other water related services to an estimated 15 million people in more than 30 states and in two Canadian provinces. Our primary business involves the ownership of water and wastewater utilities that provide water and wastewater services to residential, commercial and industrial customers. Our Regulated Businesses that provide these services are generally subject to economic regulation by state regulatory agencies in the states in which they operate. The federal government and the states also regulate environmental, health and safety and water quality matters. Our on-going Regulated Businesses currently provide services in 16 states and serves approximately 3.1 million customers based on the number of connections to our water and wastewater networks. We report the results of these businesses in our Regulated Businesses segment. We also provide services that are not subject to economic regulation by state regulatory agencies. We report the results of these businesses in our Market-Based Operations. As noted under “Business Section,” our financial condition and results of operations are influenced by a variety of industry-wide factors, including but not limited to (i) economic utility regulation; (ii) economic environment; (iii) the need for infrastructure investment; (iv) an overall trend of declining water usage per customer; (iv) weather and seasonality; and (vi) access to and quality of water supply.

In 2011, we continued the execution of our strategic goals. Our commitment to operational excellence led to success in portfolio optimization, increased regulated operating efficiency and improved performance of our Market-Based Operations, and enabled us to provide increased value to our customers and investors. In 2011, our goals were to implement the execution of the portfolio optimization, resolve rate cases outstanding at the beginning of 2011, initiate state specific efforts to address the decline in water usage, continue improvement in our O&M efficiency ratio, increase our earned rate of return to more closely align with that which is authorized by the PUCs, selectively expand our Market-Based Operations’ business, as well as, optimize our municipal contract operations’ business model.

2011 Financial Results

All financial information in this Management’s Discussion and Analysis of Financial Condition and Results of Operations (MD&A), reflects only continuing operations. As previously disclosed in our Form 10-K for the year ended December 31, 2010, as part of our portfolio optimization initiative, we entered into agreements to sell our regulated subsidiaries in Arizona, New Mexico and our regulated water and wastewater systems in Texas. The sale of the Texas subsidiary assets was completed in June 2011. In addition, on July 8, 2011, the Company entered into an agreement to sell our Ohio subsidiary. Additionally, on December 13, 2011, we entered in to an agreement to sell Applied Water Management, Inc. which was part of our Contract Operations line of business within our Market-Based segment. Therefore, the financial results of these entities have been presented as discontinued operations for all periods, unless otherwise noted. See Note 3 to Consolidated Financial Statements for further details on our discontinued operations.

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Our results for the year ended December 31, 2011 demonstrated significant progress in difficult and challenging economic and regulatory environments. We continued to increase our net income, while making significant capital investment in our infrastructure and implementing operational efficiency improvements necessary to offset increases in production and employee benefit costs.

Despite challenging weather events in the northeast region of the United Sates in the third quarter of 2011, for the year ended December 31, 2011, we generated $2,666.2 million in total operating revenue, and $803.1 million in operating income compared to total operating revenue of $2,555.0 million, and $728.1 million in operating income in 2010. Our Regulated Businesses, our largest operating segment, generated $2,368.9 million in operating revenue, representing 88.8% of our consolidated operating revenue compared to $2,285.7 in operating revenues representing 89.5% of our consolidated operating revenue in 2010. This increase of 3.6% in operating revenues, when compared to 2010, was primarily driven by rate increases offset by decrease in sales volume in all customer classes in 2011. Additionally, for the year ended December 31, 2011, our Market-Based Operations generated $327.8 million in operating revenue, compared to $294.7 million in operating revenues in 2010, an increase of 11.2%.

For the year ended December 31, 2011, we reported net income of $309.6 million, or diluted earnings per share of $1.75 compared to net income of $267.8 million, or diluted EPS of $1.53 for the comparable period in 2010. Net income for 2011 includes a benefit of $15.1 million, or $0.09 diluted earnings per share, as a result of the benefit from the cessation of depreciation on property, plant and equipment and a charge of $25.1 million or $0.14 diluted earnings, per share, to reduce the net asset values, of certain of our discontinued operations, which include associated parent company goodwill, to their net realizable values. Net income from continuing operations was $304.9 million for the year ended December 31, 2011 compared to net income from continuing operations of $255.1 million for the year ended December 31, 2010. Diluted earnings from continuing operations per average common share was $1.73 for the year ended December 31, 2011 as compared to $1.46 for year ended December 31, 2010. In addition, we generated increased cash flow from operations during 2011 of $808.4 million, compared to $774.9 million in 2010.

The primary drivers contributing to the increase in net income from continuing operations for the year ended December 31, 2011 were increased revenues resulting from rate increases as well as slightly higher revenues in our Market-Based Operations segment partially offset by higher operation and maintenance expense, depreciation and amortization expense and general taxes. See “Consolidated Results of Operations and Variances” and “Segment Results” below for further detailed discussion of the consolidated results of operations, as well as our business segments.

Implementation of Portfolio Optimization Initiative

In 2011, we continued to execute our plan for optimizing our portfolio. As part of a strategic review of our business activities, the company completed its acquisition of 11 water and 48 wastewater systems in Missouri in May 2011 for a purchase price of $3.3 million, leveraging the strength of our large-scale operations in that state. The acquisition adds an additional 1,700 water customers and nearly 2,000 wastewater customers to our regulated operations. Under a separate agreement, the sale of the Texas subsidiary assets was completed in June 2011.

In January 2011, we announced that we had entered into an agreement with EPCOR Water (USA) Inc. to sell 100 percent of the stock of our regulated water and wastewater operating companies located in Arizona and New Mexico. On January 31, 2012, we received approximately $461.0 million of sales proceeds as a result completing the divestiture of these regulated operating companies. We plan to use the proceeds from the sale to reduce equity financing requirements and to pay down commercial paper.

On July 8, 2011, we entered into an agreement to purchase seven regulated water systems in New York for approximately $71 million, adding approximately 50,000 customers to New York regulated operations. In a separate agreement, American Water will sell its eight regulated water systems and one wastewater system in

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Ohio for approximately $89 million, plus assumed liabilities of approximately $31 million for an enterprise value of approximately $120 million. Ohio American Water serves approximately 58,000 customers. The completion of both transactions is subject to customary closing conditions, including regulatory approval by public utility commissions in both New York and Ohio. We expect the closing on these transactions to occur in the first half of 2012.

On December 31, 2011, we completed the sale of AWM which was part of our Contract Operations line of business within our Market-Based segment, in two separate transactions for combined proceeds of approximately $3.0 million. Also in 2011, we continued to bring new water solutions to challenged water and wastewater systems by acquiring several smaller systems in Pennsylvania, Missouri and New Jersey.

Capital Investments

We invested approximately $925 million and $766 million in Company-funded capital improvements in 2011 and 2010, respectively. These capital investments are needed on an ongoing basis to comply with existing and new regulations, renew aging treatment and network assets, provide capacity for new growth and ensure system reliability, security and quality of service. The need for continuous investment presents a challenge due to the potential for regulatory lag, or the delay in recovering our operating expenses and earning an appropriate rate of return on our invested capital and a return of our invested capital. In conjunction with our capital program, management continued its focus on reducing regulatory lag during 2011. For 2012 we anticipate spending approximately $900 million on Company—funded capital investments, including expenditures associated with our business transformation project.

During 2011, we continued to move forward with our business transformation project to enhance processes and upgrade antiquated legacy systems in order to generate efficiencies and to better meet our customer needs in a more cost effective manner. Also, during 2011, we decided to accelerate the timeline of this project due to its criticality to the business. Since the inception of the project, we completed our evaluation of appropriate software solutions and selected our software vendor as well as our system integrator. We worked with the system integrator to analyze our current processes and to design a blueprint for business processes and new systems that will enable business transformation. During 2011, we completed the detailed design and build of the Enterprise Resource Planning (“ERP”) application. Also, in 2011, we began the design of the customer information and enterprise asset management systems.

We expect the ERP application to go-live in August 2012 and the new customer information system and enterprise asset management system—implemented by the end of 2013. Total expenditures spent for our business transformation project through December 31, 2011 approximates $139.7 million with $105.3 million of that amount spent in 2011.

Rate Cases and Regulatory Matters

In 2011, we received authorizations for additional annualized revenues from general rate cases, totaling $78.8 million. In April 2011, we received final orders in our Tennessee and West Virginia rate cases, both of which were filed in 2010. On August 1, 2011, our Virginia rate case, which was filed in 2010 and for which interim rates had been in effect under bond subject to refund since the third quarter of 2010, was approved. In November 2011, we received final authorizations in our Pennsylvania rate case and our Hawaii rate case, both of which were filed in 2011.

Additionally settlements have been reached, in our general rate cases in Missouri and New York, which could provide approximately $30 million in additional annualized revenues if approved in accordance with the settlement agreement. There is no assurance that the settlement amounts, or any portion thereof, will be approved as they are pending regulatory approvals and are all subject to change. Details of this case will be released upon final approval.

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On February 23, 2012, the Iowa Utilities Board approved an additional $2.8 million of annualized revenues for our Iowa subsidiary. The increase approximates what we had been collecting since July 29, 2011 under interim rates and the partial settlement that was reached in October 2011.

On February 6, 2012, we filed a general rate case in Virginia requesting additional annualized revenues for jurisdictional and non-jurisdictional customers of $6.0 million. As of February 23, 2012, we are awaiting final orders in seven states where we have continuing operations, including Missouri and New York, where settlement agreements are pending, requesting additional annualized revenues of $245.5 million. Of the outstanding cases, only one was filed in 2010, five cases were filed in 2011 and the Virginia case was filed in 2012. There is no assurance that all, or any portion thereof, of any requested increases will be granted.

Also, in 2011, we were granted $26.2 million in additional annualized revenues, assuming constant sales volumes from infrastructure charges in several of our states. In January 2012, additional annualized revenue of $1.7 million resulting from infrastructure charges in our Illinois subsidiary became effective.

In addition to our general rate case filings and infrastructure charge filings, during 2011 we made other filings including cost of capital, pre-construction cost, and interim rates true-ups. We do not expect these filings to have a material impact on our results of operations, financial condition or cash flows.

As disclosed in more detail under Item 3, “Legal Proceedings” in this report, our subsidiary, California- American Water Company (“CAWC”) filed an application with the California Public Utilities Commission (“CPUC”) in September, 2010 to seek approval for a project to reroute the Carmel River and remove the San Clemente Dam in Monterey, California. The dam is owned by CAWC. As part of the application, CAWC is seeking recovery of certain historical costs, totaling approximately $26.9 million, related to studies to determine whether the dam could withstand significant flooding and severe earthquakes meeting defined criteria, efforts to develop a project to address seismic issues, the identification and analysis of possible alternative project options, and activities undertaken pursuant to the directives of Federal and State government agencies, including the California Department of Water Resources, Division of Safety of Dams (“DSOD”), the lead agency under the State and Federal environmental review laws. On November 10, 2011, a Proposed Decision (“PD”) was issued by the administrative law judge assigned to the matter. In the PD, the administrative law judge recommended that recovery of virtually all of the historical costs should be denied. CAWC has filed comments with the CPUC contending that the PD is unreasonable, unsupported by and contrary to the evidence, and contrary to law and policy. The PD is currently under review by the CPUC, which has delayed issuing a decision on several occasions and most recently has indicated that it will not vote on a decision until April 19, 2012. At December 31, 2011, most of the historical charges related to the dam are recorded as regulatory assets on our consolidated balance sheet. While we believe there are sound reasons for the CPUC to modify the PD to permit recovery of the historical costs, in the event recovery is not permitted, we would incur a charge equal to the carrying value of the historical costs included in regulated assets. If partial recovery is allowed, the effect on regulated assets would be reduced.

Continue Improvement in O&M Efficiency Ratio for our Regulated Businesses

Our O&M efficiency ratio (a non-GAAP measure) is defined as our regulated operation and maintenance expense divided by regulated operating revenues where both operation and maintenance expense and operating revenues are adjusted to eliminate purchased water expense. Our O&M efficiency ratio was 43.8% for the year ended December 31, 2011 compared to 45.5% and 47.7% for the years ended December 31, 2010 and 2009, respectively. We evaluate our operating performance using this measure as it is the primary measure of the efficiency of our regulated operations. This information is intended to enhance an investor’s overall understanding of our operating performance. O&M efficiency ratio is not a measure defined under GAAP and may not be comparable to other companies’ operating measures or deemed more useful than the GAAP information provided elsewhere in this report. The following table provides reconciliation between operation and maintenance expense and operating revenues, as determined in accordance with GAAP, and to those amounts utilized in the calculation of our O&M efficiency ratio for the years ended December 31, 2011, 2010 and 2009.

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Regulated O&M Efficiency Ratio (a Non-GAAP Measure)

	For the Years Ended December 31,
	2011			2010			2009
				(in thousands)
Total regulated O&M expense	$	1,092,611		$	1,095,446		$	1,036,565
Less: Regulated purchased water expense		99,008			99,834			89,502
Adjusted regulated O&M expense(a)	$	993,603		$	995,612		$	947,063
Total regulated operating revenues	$	2,368,891		$	2,285,656		$	2,076,563
Less: Regulated purchased water expense*		99,008			99,834			89,502
Adjusted regulated operating revenues(b)	$	2,269,883		$	2,185,822		$	1,987,061
Regulated O&M efficiency ratio(a)/(b)		43.8	%		45.5	%		47.7	%

* Note calculation assumes purchased water revenues approximate purchased water expenses.

Other initiatives:

In 2011, we began addressing regulatory lag in a number of our states. In all of the rate cases that we filed in 2011, we addressed declining usage trends. Additionally, in November 2011, the New Jersey Board of Public Utilities (BPU) voted unanimously to publish draft rules that if adopted would implement a distribution system improvement charge (“DSIC”) for specified water infrastructure investments for our New Jersey subsidiary. The draft rules were published for public comment in December 2011. Allowing time for resolution of public comments and final approval, April 2012 is the earliest estimate for the rule to become final. Assuming the rule becomes final, New Jersey American Water Company intends to file a foundational filing to support planned investments and, under the draft rules, the BPU will have 90 days to act on this filing. After approval of the foundational filing, recovery filings for eligible investments will be semi-annual with rates taking effect two months after the filing.

Also, in 2011, we issued our first full corporate responsibility report, securing our position as the first U.S. water and wastewater company to report on environmental, social and governance performance against Global Reporting Index guidelines. This biennial report includes the company’s priorities, policies and approaches to corporate responsibility, and covers performance for the 2010 fiscal year. As a trusted steward of our most precious resource—water—the company believes having a corporate management approach oriented toward corporate responsibility is key to our long-term success and the ability to provide high-quality services to our customers and maintain trust with them and all our stakeholders. The report can be found on the company’s Web site.

2012 and Beyond

Our strategy for the future will continue to focus on earning an appropriate rate of return on our investments, promoting constructive regulatory frameworks, expanding the Regulated Businesses segment through focused acquisitions and pursuing “regulated-like” opportunities in our Market-Based Operations. We will also continue to modernize our infrastructure and focus on operational efficiencies.

In particular for 2012, we will focus on continuing our portfolio optimization initiative. We finalized our sale of regulated operations in Arizona and New Mexico on January 31, 2012 and expect to finalize the divestiture of our Ohio operating company in the first quarter of 2012. Also, in the first quarter of 2012, we expect to complete the acquisition of the seven regulated water utilities in New York. We will continue to identify additional value-added opportunities.

Also, in 2012, we will continue to actively address regulatory lag that impacts returns on investments. We expect to file four general rates cases as well as file for infrastructure surcharges in four to six states. Additionally, we expect to continue to address declining usage trends via rate case or other filings. The demand

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for water has been lower than expected in 2011, even though usage volumes for water increased in 2010 compared to 2009. In addition, increased water conservation, including the use of more efficient household fixtures and appliances among residential consumers, combined with declining household sizes in the United States, have contributed to a trend of declining water usage per residential customer. All of the states served by our Regulated Businesses have experienced a declining trend in water usage per residential customer, with the rate decline in the various states averaging 2.1% and ranging between 1.3% and 3.42% annually over the last 5 years, some of which may have been attributable to variations in weather conditions. Because the characteristics of residential water use are driven by many factors, including socio-economic and other demographic characteristics of our service areas, climate, seasonal weather patterns and water rates, these declining trends vary by state and service area and change over time. Our Regulated Businesses are heavily dependent upon operating revenues generated from rates we charge to our customers for the volume of water they use. Declining usage due to conservation or the economic environment contribute to regulatory lag and will have a negative impact on our long-term operating revenues if we are unable to secure appropriate regulatory treatment to offset the usage decline.

Additionally in 2012, we will continue to make efficient use of our capital. We expect to invest approximately $900 million to upgrade infrastructure, enhance infrastructure surcharge like mechanisms and optimize our supply chain process. We also expect to continue to improve our regulated O&M efficiency ratio, of which our 5 year goal, which began in 2011, is to be below 40%; increase our earned regulated return; and expand our Market-Based Operations with a focus on the Homeowners Services Group and Military Contract Operations; and optimize our municipal contract operations business model to provide for value creation for both American Water and the municipality.

We are committed to operating our business responsibly and managing our operating and capital costs in a manner that serves our customers and produces value for our shareholders. We are committed to an ongoing strategy to make ourselves more effective, efficient and innovative.

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Results of Operations

The following table sets forth our consolidated statement of operations data for the years ended December 31, 2011, 2010 and 2009:

	Years Ended December 31,
	2011			2010			2009
Operating revenues	$	2,666,236		$	2,555,035		$	2,290,446
Operating expenses
Operation and maintenance		1,301,794			1,290,941			1,182,376
Depreciation and amortization		351,821			330,264			309,874
General taxes		210,478			205,597			186,620
(Gain) loss on asset dispositions and purchases		(993	)		111			(295	)
Impairment charge		0			0			428,036
Total operating expenses, net		1,863,100			1,826,913			2,106,611
Operating income		803,136			728,122			183,835
Other income (expenses)
Interest, net		(312,415	)		(313,765	)		(296,623	)
Allowance for other funds used during construction		13,131			9,644			8,342
Allowance for borrowed funds used during construction		5,923			5,225			5,529
Amortization of debt expense		(5,055	)		(4,516	)		(6,609	)
Other, net		(1,040	)		4,714			(680	)
Total other income (expenses)		(299,456	)		(298,698	)		(290,041	)
Income (loss) from continuing operations before income taxes		503,680			429,424			(106,206	)
Provision for income taxes		198,751			174,352			113,792
Income (loss) from continuing operations		304,929			255,072			(219,998	)
Income (loss) from discontinued operations, net of tax		4,684			12,755			(13,085	)
Net income (loss)	$	309,613		$	267,827		$	(233,083	)
Basic earnings per common share:(a)
Income (loss) from continuing operations	$	1.74		$	1.46		$	(1.31	)
Income (loss) from discontinued operations, net of tax	$	0.03		$	0.07		$	(0.08	)
Net income (loss)	$	1.76		$	1.53		$	(1.39	)
Diluted earnings per common share:(a)
Income (loss) from continuing operations	$	1.73		$	1.46		$	(1.31	)
Income (loss) from discontinued operations, net of tax	$	0.03		$	0.07		$	(0.08	)
Net income (loss)	$	1.75		$	1.53		$	(1.39	)
Average common shares outstanding during the period:
Basic		175,484			174,833			168,164
Diluted		176,531			175,124			168,164

(a) Amounts may not sum due to rounding.

Comparison of consolidated Results of Operations for the Years Ended December 31, 2011 and 2010

Operating revenues. Consolidated operating revenues for the year ended December 31, 2011 increased $111.2 million, or 4.4%, compared to the same period in 2010. Contributing to this increase was higher revenues

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in our Regulated Businesses of $83.2 million which was mainly the result of rate increases and higher revenues in our Market-Based Operations segment of $33.1 million, which was primarily due to a $22.3 million increase in the Contract Operations Group revenues attributable to incremental capital project activity associated with our military services contracts. For further information see the respective “Operating Revenues” discussions within the “Segment Results.”

Operation and maintenance. Consolidated operation and maintenance expense for the year ended December 31, 2011 increased $10.9 million, or 0.8%, compared to 2010. This change was driven by a $21.8 million increase in our Market-Based Operations segment primarily related to the increased capital activity associated with our military contracts partially offset by a $2.8 million decrease in our Regulated Businesses segment. The remaining $8.1 million decrease was mainly due to additional expenses in 2010 attributable to a $5.0 million contribution to the American Water Charitable Foundation, a 501c(3) organization that was established in December 2010 to encourage and support employees volunteerism and community giving and severance costs of $2.7 million associated with changes in certain senior management positions. For further information see the respective “Operation and Maintenance” discussions within the “Segment Results.”

Depreciation and amortization. Depreciation and amortization expense increased by $21.6 million, or 6.5%, for the year ended December 31, 2011 compared to the same period in the prior year as a result of additional utility plant placed in service.

General taxes. General taxes expense, which includes taxes for property, payroll, gross receipts, and other miscellaneous items, increased by $4.9 million, or 2.4%, for the year ended December 31, 2011 compared to the year ended December 31, 2010. This increase was principally due to higher gross receipts taxes of $4.6 million, primarily in our New Jersey regulated subsidiary.

Impairment charge. No impairment charge was recorded for our continuing operations in 2011 or 2010.

Other income (expenses). Other income and (expenses) increased $0.8 million or 0.3% for the year ended December 31, 2011 compared to the same period in the prior year. This increase is attributable to an increase in allowance for funds used during construction (“AFUDC”) of $4.2 million resulting from increased construction activity and a decrease in interest expense, net of interest income, of $1.4 million partially offset by a decrease in Other, net. The decrease in Other, net of $5.8 million is mainly due to the inclusion in 2010, the release of the remaining balance of a loss reserve amounting to $1.3 million, resulting from the resolution of the outstanding issues and uncertainties, incremental rental revenues of $2.6 million and the recognition of funds received related to the methyl tertiary butyl ether (“MTBE”) legal settlement for $1.9 million resulting from the outcome of a subsidiary’s rate order.

Provision for income taxes. Our consolidated provision for income taxes increased $24.4 million, or 14.0%, to $198.8 million for the year ended December 31, 2011. The effective tax rates for the years ended December 31, 2011 and 2010 were 39.5% and 40.6%, respectively. The rate for the twelve months ended December 31, 2011 includes a $4.5 million tax benefit related to one of our operating companies contributing non-utility property to a county authority within its operating area.

Income from discontinued operations, net of tax. As noted above, the financial results of our regulated water and wastewater systems in Arizona, New Mexico, Texas and Ohio and our Applied Water Management, Inc subsidiary within the Market-Based Operations segment have been classified as discontinued operations for all periods presented. The decrease in income from discontinued operations, net of tax is primarily related to a $25.1 million charge record to reduce the net asset values of those businesses classified as discontinued operation, which included associated parent company goodwill, to their net realizable values. This charge was offset by a benefit of $15.1 related to the cessation of depreciation for our Arizona, New Mexico, Texas and Ohio subsidiaries in accordance with GAAP for the year ended December 31, 2011 of $15.1 million.

Net income (loss). Net income for 2011 was $309.6 million compared to net income of $267.8 million for 2010. The variation between the periods is the result of the aforementioned changes.

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Comparison of Consolidated Results of Operations for the Years Ended December 31, 2010 and 2009

Operating revenues. Our operating revenues increased by $264.6 million, or 11.6%, to $2,555.0 million for 2010 from $2,290.4 million for 2009. Regulated Businesses’ revenues increased by $209.1 million, or 10.1%, for 2010 compared to 2009 primarily attributable to rate increases and increased consumption. The Market-Based Operations’ revenues for 2010 increased by $56.5 million, or 23.7%, from 2009 and was mainly attributable to higher revenues in the Contract Operations and Homeowner Services Groups. For further information see the respective “Operating Revenues” discussions within the “Segment Results.”

Operation and maintenance. Operation and maintenance expense increased $108.6 million, or 9.2%, for 2010 compared to 2009. This increase was due to higher operation and maintenance expense in our Regulated Businesses of $58.9 million and in our Market-Based Operations business of $47.6 million. Additionally, 2010 included a $5.0 million contribution to the American Water Charitable Foundation, a 501-c(3) organization that was established in December 2010 to encourage and support employees volunteerism and community giving and severance costs of $2.7 million associated with changes in certain senior management positions. For further information on the Regulated Businesses and Market-Based Operations variances see the respective “Operation & Maintenance” discussions within the “Segment Results.”

Depreciation and amortization. Depreciation and amortization expense increased by $20.4 million, or 6.6%, for 2010 compared to 2009. This increase was due to our continued investment in our infrastructure and capital expenditures, many of which were placed into service in 2010 by our Regulated Businesses. This increase was partially offset by the $2.4 million write-off of certain software costs in 2009.

General taxes. General taxes expense, which includes taxes for property, payroll, gross receipts, and other miscellaneous items, increased by $19.0 million, or 10.2% in 2010 compared to the same period in 2009. This increase was due to higher gross receipts taxes of $6.7 million, primarily in our New Jersey regulated subsidiary, higher property taxes of $5.6 million throughout our regulated operations, higher payroll taxes of $3.3 million as a result of our increased wages and salaries for the year December 31, 2010 and higher capital stock taxes of $1.7 million.

Impairment charge. No impairment charge was recorded in 2010. For the twelve months ended December 31, 2009, we recorded an impairment charge to goodwill for our continuing operations totaling $428.0 million. Our Regulated Businesses recorded a charge to goodwill in the amount of $426.2 million and our Market-Based Operations recorded a charge to goodwill of $1.8 million. The 2009 impairment charge, which was recorded in the first quarter of 2009, was primarily related to the high degree of stock market volatility experienced and as of March 31, 2009, the sustained period for which the Company’s market price was below its carrying value.

Other income (expenses). Interest expense, net of interest income, which is the primary component of our other income (expenses), increased by $17.1 million, or 5.8%, for 2010 compared to 2009. The increase is primarily due to the refinancing of short-term debt with long-term debt during 2009 as well as increased borrowing associated with capital expenditures. As a result of the volatile market conditions in 2008, the Company utilized its short-term debt credit facilities to fund our capital projects and other operating needs which resulted in higher short-term borrowings in the first half of 2009. Our short term borrowings were steadily reduced during 2009 through a significant number of long-term debt refinancing with fixed interest rates. The increase in fixed rate long-term debt resulted in higher interest expense for the year ended December 31, 2010. Allowance for funds used during construction (“AFUDC”) increased by $1.0 million for 2010 compared to the same period in 2009 as a result of increased construction activity. Furthermore, other income increased due to higher joint venture income and changes in market value of Company-held deferred compensation. Other items affecting other income (expense) include the release of the remaining balance of a loss reserve of $1.3 million as a result of the resolution of outstanding issues and uncertainties that occurred during 2010 as well as the recognition of funds received related to the MTBE legal settlement for $1.9 million resulting from the outcome of a subsidiary’s rate order.

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Provision for income taxes. Our consolidated provision for income taxes increased $60.6 million, or 53.2%, to $174.4 million for 2010 from $113.8 million in 2009. The effective tax rates in 2010 and 2009 were 40.6% and (107.1%) respectively. The 2009 effective tax rate reflects the tax effects of the 2009 goodwill impairment charge, as the Company considers this charge as infrequently occurring or unusual. In addition to the tax benefits associated with the goodwill impairment charge, 2009 also included tax benefits attributable to the impact of tax law changes as well as other discrete items. The Company’s annual effective tax rate was 40.83% and 36.63% for 2010 and 2009, respectively, excluding the impact of the goodwill impairment charge and various other discrete items.

Income from discontinued operations, net of tax. The change is primarily attributable to the inclusion in 2009 operating expenses of an impairment charge, net of tax of $21.6 million.

Net income (loss). Net income for 2010 was $267.8 million compared to a net loss of $233.1 million for 2009. The variation between the periods is the result of the aforementioned changes.

Segment Results

We have two operating segments, which are also our reportable segments: the Regulated Businesses and the Market-Based Operations. These segments are determined based on how we assess performance and allocate resources. We evaluate the performance of our segments and allocated resources based on several factors, with the primary measure being income from continuing operations before income taxes.

Regulated Segment

The following table summarizes certain financial information for our Regulated Businesses for the periods indicated:

	For the years ended December 31,
	2011		2010		2009
			(in thousands)
Operating revenues	$	2,368,891	$	2,285,656	$	2,076,563
Operation and maintenance expense		1,092,611		1,095,446		1,036,565
Operating expenses, net		1,609,276		1,587,963		1,497,453
Income from continuing operations before income taxes		535,445		478,629		371,919

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Operating Revenues. Our primary business involves the ownership of water and wastewater utilities that provide services to residential, commercial, industrial and other customers. This business is subject to state regulation and our results of operations are impacted significantly by rates authorized by the state regulatory commissions in the states in which we operate. The table below details additional annualized revenues awarded, including step increases and assuming a constant volume, resulting from rate authorizations granted in 2011, 2010 and 2009.

	Years Ended December 31,
	2011		2010		2009
	(in millions)
State
General Rate Cases:
Pennsylvania(1)	$	62.1	$	8.4	$	56.0
New Jersey(2)		—		39.9		1.6
Kentucky		—		18.8		10.3
Missouri		—		28.0		—
Illinois		—		41.4		—
Indiana		—		31.5		—
California(3)		—		14.6		16.0
West Virginia		5.1		—		5.2
Virginia(4)		4.8				—
Tennessee		5.6		—		—
Iowa		—		—		6.1
Other		1.2		0.8		0.9
Total—General Rate Cases	$	78.8	$	183.4	$	96.1

(1) 2010 amount includes additional increases of $3.2 million in 2011 and $2.6 million in 2012.

(2) 2009 amount includes additional increases of $0.5 million effective in 2010 and $0.4 million effective in 2011.

(3) 2009 amount includes additional increases of $1.3 million effective in 2010 and $1.8 million in 2011;

(4) The new rates in 2011 provided for additional annualized revenue of $4.3 million for jurisdictional customers and a $0.5 million increase for non-jurisdictional customers which are not subject to commission filing.

The effective date for the 2011 Pennsylvania rate increase was November 11, 2011. The Virginia, Tennessee and West Virginia increases were effective March 6, 2011, April 5, 2011 and April 19, 2011 respectively. The effective dates for the larger rate increases granted in 2010 were October 1, 2010, July 1, 2010, April 23, 2010 and May 3, 2010, in Kentucky, Missouri, Illinois and Indiana, respectively. Rate increases granted in 2010 for Pennsylvania and New Jersey were not effective until January 1, 2011. The effective date for the 2009 Pennsylvania rate increase was November 7, 2009.

As previously noted, an increasing number of states are permitting rates to be adjusted outside of a general rate case for certain costs, such as a return on capital investments to replace aging infrastructure. The following table details additional annualized revenue authorized through infrastructure surcharge mechanisms which were

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granted in 2011, 2010 and 2009. As these surcharges are typically rolled into the new base rates and therefore are reset to zero when new base rates are effective, certain of these charges may also be reflected in the total general rate case amounts awarded in the table above if the order date was following the infrastructure surcharge filing date.

	Years Ended December 31,
	2011		2010		2009
	(in millions)
Infrastructure Charges:
Pennsylvania	$	16.4	$	8.5	$	15.2
Missouri		5.8		3.2		2.7
Indiana		—		5.4		3.8
Illinois		3.7		0.7		0.9
Other		0.3		0.4		1.4
Total—Infrastructure Charges	$	26.2	$	18.2	$	24.0

Comparison of Results of Operations for the Years Ended December 31, 2011 and 2010

Operating revenues increased by $83.2 million, or 3.6%, for the year ended December 31, 2011 compared to the same period in 2010. The increase in revenues was primarily due to rate increases obtained through rate authorizations for a number of our operating companies of which the impact was approximately $133.8 million partially offset by decreased revenues of $57.0 million attributable to decreased consumption in 2011 compared 2010. The majority of this decrease occurred in our New Jersey and Pennsylvania subsidiaries mainly as a result of the extreme weather conditions, including the impacts associated with Hurricane Irene and other severe storms in the Northeast region of the United States during the third quarter of 2011. The following table sets forth the amounts and percentages of Regulated Businesses’ revenues and water sales volume by customer class:

	For the Years Ended December 31,
	2011				2010*				2011				2010*
	Operating Revenues (dollars in thousands)								Water Sales Volume (gallons in millions)
Customer Class
Water service:
Residential	$	1,339,429	56.5	%	$	1,300,167	56.9	%		180,916	51.2	%		187,062	51.3	%
Commercial		474,191	20.0	%		456,994	20.0	%		81,455	23.0	%		84,086	23.0	%
Industrial		115,981	4.9	%		110,175	4.8	%		39,295	11.1	%		39,860	10.9	%
Public and other		302,276	12.8	%		291,393	12.7	%		52,069	14.7	%		54,059	14.8	%
Other water revenues		20,712	0.9	%		22,672	1.0	%		—	—			—	—
Total water revenues		2,252,589	95.1	%		2,181,401	95.4	%		353,735	100.0	%		365,067	100.0	%
Wastewater service		76,301	3.2	%		69,049	3.0	%
Other revenues		40,001	1.7	%		35,206	1.6	%
	$	2,368,891	100.0	%	$	2,285,656	100.0	%

* Certain reclassifications have been made between customer classes to conform to the 2011 presentation.

The following discussion related to water services indicates the increase or decrease in the Regulated Businesses’ revenues and associated billed water sales volumes in gallons by customer class.

Water Services—Water service operating revenues from residential customers for year ended December 31, 2011 totaled $1,339.4 million, a $39.3 million increase, or 3.0%, over the same period of 2010, mainly due to rate increases offset by decreases in sales volume. The volume of water sold to residential customers

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decreased by 3.3% for the year ended December 31, 2011 to 180.9 billion gallons, from 187.1 billion gallons for the same period in 2010. We believe that factors contributing to the decline could include the aforementioned weather conditions in the third quarter 2011, an increased customer focus on conservation, the use of more efficient appliances and the current economic climate. The extent to which these items individually contribute to the overall decline is difficult to measure.

Water service operating revenues from commercial water customers for the year ended December 31, 2011 increased by $17.2 million, or 3.8%, to $474.2 million for the same period in 2010. These increases were mainly due to rate increases partially offset by decreases in sales volume. The volume of water sold to commercial customers decreased by 3.1% for the year ended December 31, 2011, to 81.5 billion gallons, from 84.1 billion gallons for the year ended December 31, 2010. We believe that factors contributing to this decline include wetter weather conditions, an increased customer focus on conservation as well as the current economic environment in certain areas in which we operate. Similar to the above, the extent to which these items individually contribute to the overall decline is difficult to measure.

Water service operating revenues from industrial customers totaled $116.0 million for the year ended December 31, 2011, an increase of $5.8 million, or 5.3%, from those recorded for the same period of 2010, mainly due to rate increases offset by a slight decrease in sales volume. The volume of water sold to industrial customers totaled 39.3 billion gallons for the year ended December 31, 2011, a decrease of 1.5% from the 39.9 billion gallons for the year ended December 31, 2010.

Water service operating revenues from public and other customers, including municipal governments, other governmental entities and resale customers increased $10.9 million, or 3.7% to $302.3 million, for the year ended December 31, 2011 from $291.4 million in the same period of 2010. Revenues from municipal governments for fire protection services and customers requiring special private fire service facilities totaled $126.9 million for the year ended December 31, 2011, an increase of $7.1 million compared to the same period of 2010. Revenues generated by sales to governmental entities and resale customers totaled $175.4 million, an increase of $3.8 from the year ended December 31, 2010.

Wastewater services—Our subsidiaries provide wastewater services in 9 states. Revenues from these services increased by $7.3 million, or 10.5%, to $76.3 million for the year ended December 31, 2011, from the same period of 2010. The increase was primarily attributable to rate increases in a number of our operating companies.

Other revenues—Other revenues include such items as reconnection charges, initial application service fees, certain rental revenues, revenue collection services for others and similar items. The increase in revenues for the year ended December 31, 2011 as compared to the same period in the prior year was mainly the result of increased rental revenues.

Operation and maintenance. Operation and maintenance expense decreased $2.8 million, or 0.3%, for the year ended December 31, 2011, compared to the year ended December 31, 2010. Operation and maintenance expense for 2011 and 2010, by major expense category, were as follows:

	For the Years Ended December 31,
	2011		2010		Increase (Decrease)			Percentage
	(in thousands)
Production costs	$	262,563	$	268,529	$	(5,966	)		(2.2	)%
Employee-related costs		489,836		486,969		2,867			0.6	%
Operating supplies and services		187,709		181,968		5,741			3.2	%
Maintenance materials and services		73,376		75,846		(2,470	)		(3.3	)%
Customer billing and accounting		43,368		44,024		(656	)		(1.5	)%
Other		35,759		38,110		(2,351	)		(6.2	)%
Total	$	1,092,611	$	1,095,446	$	(2,835	)		(0.3	)%

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Production costs including fuel and power, purchased water, chemicals and waste disposal decreased by $6.0 million, or 2.2%, for 2011 compared to 2010. Production costs by major expense type were as follows:

	For the Years Ended December 31,
	2011		2010		Increase (Decrease)			Percentage
	(in thousands)
Fuel and power	$	87,879	$	89,203	$	(1,324	)		(1.5	)%
Purchased water		99,008		99,834		(826	)		(0.8	)%
Chemicals		48,354		50,875		(2,521	)		(5.0	)%
Waste disposal		27,322		28,617		(1,295	)		(4.5	)%
Total	$	262,563	$	268,529	$	(5,966	)		(2.2	)%

The decrease in our fuel and power costs was primarily due to the decreased water sales volumes. The decrease in purchased water is primarily attributable to the decreased usage, most notably in our New Jersey subsidiary due to wet weather conditions, previously discussed, as well as in our California subsidiary as customer needs were met with internally produced water. The decrease in chemical costs is also due to higher consumption in 2010 as a result of much drier and warmer weather in the Northeast region of the United States. We also experienced favorable pricing in some of our operating companies in 2011. The waste disposal cost decrease was mainly due to the recognition, in 2010, of $1.9 million of previously deferred costs allowed by a cost recovery mechanism in one of our operating companies.

Employee-related costs including wage and salary, group insurance, and pension expense increased $2.9 million, or 0.6%, for 2011 compared to 2010. These employee-related costs represented 44.8% and 44.5% of operation and maintenance expenses for 2011 and 2010, respectively and include the categories shown in the following table:

	For the Years Ended December 31,
	2011		2010		Increase (Decrease)			Percentage
	(in thousands)
Salaries and wages	$	327,777	$	331,913	$	(4,136	)		(1.2	)%
Pensions		68,885		58,134		10,751			18.5	%
Group insurance		75,120		79,958		(4,838	)		(6.1	)%
Other benefits		18,054		16,964		1,090			6.4	%
Total	$	489,836	$	486,969	$	2,867			0.6	%

The overall increase in employee-related costs was primarily driven by increased pension expense. The increase in pension expense for the year ended December 31, 2011 was primarily due to increased contributions in certain of our regulated operating companies whose costs and revenue requirements are based on the actual cash contributions to our pension trust account. This increase was partially offset by lower salaries and wages and group insurance expenses. The decrease in salaries and wages for the year ended December 31, 2011 compared to the same period in the prior year was driven by vacant positions and lower severance expenses partially offset by increased incentive costs and annual wage increases. Group insurance decreased mainly due to lower postretirement benefits other than pension as the result of changes to the design of our medical plan and vacant positions as compared to the same period in the prior year.

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Operating supplies and services include expenses for office operation, legal and other professional services, including transportation expenses, information systems rental charges and other office equipment rental charges. Overall, these costs increased $5.7 million, or 3.2% for the year ended December 31, 2011 compared to the same period in 2010.

	For the Years Ended December 31,
	2011		2010		Increase (Decrease)			Percentage
	(in thousands)
Contracted services	$	72,582	$	66,077	$	6,505			9.8	%
Office supplies and services		27,718		28,727		(1,009	)		(3.5	)%
Transportation		26,323		26,330		(7	)		0.0	%
Rents		15,619		15,745		(126	)		(0.8	)%
Other		45,467		45,089		378			0.8	%
Total	$	187,709	$	181,968	$	5,741			3.2	%

The above increases are primarily due to higher contracted services of $6.5 million for the year ended December 31, 2011, mainly as a result of backfilling positions, including those left open by employees transferring to our business transformation project as well as the use of contractors for other specific projects. Additionally, 2011 included the recording of an anticipated recovery of expenses related to costs incurred as a result of severe weather storms, primarily Hurricane Irene, which have been recorded in their respective expense lines. Also contributing to the increase was the fact that the same period in 2010 included a reversal of a $3.5 million payment previously made by our California operating company to the California Department of Fish and Game (“CDFG”) on behalf of the National Oceanographic and Atmospheric Administration (“NOAA”). This reversal was the result of an advice letter issued by the California Public Utility Commission which allowed for rate recovery of such payment.

Maintenance materials and services, which includes emergency repair as well as costs for preventive maintenance, decreased $2.5 million, or 3.3%, for 2011 compared to 2010.

	For the Years Ended December 31,
	2011		2010		Increase (Decrease)			Percentage
	(in thousands)
Maintenance services and supplies	$	73,376	$	75,846	$	(2,470	)		(3.3	)%

The decrease of $2.5 million in 2011 is mainly attributable to lower preventive maintenance expenses throughout our regulated subsidiaries, including tank painting, meter testing, pump, tank and well maintenance, and paving costs.

Customer billing and accounting expenses decreased by $0.7 million, or 1.5%, for 2011 compared to 2010.

	For the Years Ended December 31,
	2011		2010		Increase (Decrease)			Percentage
	(in thousands)
Uncollectible accounts expense	$	16,060	$	18,052	$	(1,992	)		(11.0	)%
Postage		12,382		12,348		34			0.3	%
Other		14,926		13,624		1,302			9.6	%
Total	$	43,368	$	44,024	$	(656	)		(1.5	)%

The decrease of $2.0 million in the uncollectible accounts expense was the result of improved collection in our receivables in excess of 120 days. This decrease is partially offset by the increase in the Other category mainly due to an increase in collection agency fees.

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Other operation and maintenance expenses include casualty and liability insurance premiums and regulatory costs. These costs decreased by $2.4 million, or 6.2%, for 2011 compared to 2010.

	For the Years Ended December 31,
	2011		2010		Increase (Decrease)			Percentage
	(in thousands)
Insurance	$	28,325	$	28,244	$	81			0.3	%
Regulatory expenses		7,434		9,866		(2,432	)		(24.7	)%
Total	$	35,759	$	38,110	$	(2,351	)		(6.2	)%

The decrease in regulatory expenses was mainly driven by rate case expenses which were deferred in one of our subsidiaries.

Operating expenses. The increase in operating expenses for the year ended December 31, 2011 is primarily due to higher depreciation expense of $20.5 million resulting from additional utility plant placed in service and increased general taxes of $5.0 million principally attributable to higher gross receipts taxes in our New Jersey regulated subsidiary. Offsetting these increases is lower operation and maintenance expense, as explained above.

Income from continuing operations before income taxes. The $56.8 million increase for the year ended December 31, 2011, compared to the same period in the prior year, is the result of the aforementioned operating revenue and operating expenses variations.

Comparison of Results of Operations for the Years Ended December 31, 2010 and 2009

Operating revenues increased by $209.1 million, or 10.1%, for the year ended December 31, 2010 compared to the same period in 2009. The increase in revenues was primarily attributable to rate increases and increased consumption. The following table sets forth the amounts and percentages of Regulated Businesses’ revenues and water sales volume by customer class:

	For the Years Ended December 31,
	2010*				2009*				2010				2009*
	Operating Revenues (dollars in thousands)								Water Sales Volume (gallons in millions)
Customer Class
Water service:
Residential	$	1,300,167	56.9	%	$	1,185,861	57.1	%		187,062	51.3	%		184,680	52.0	%
Commercial		456,994	20.0	%		417,076	20.1	%		84,086	23.0	%		81,823	23.0	%
Industrial		110,175	4.8	%		97,475	4.7	%		39,860	10.9	%		35,543	10.0	%
Public and other		291,393	12.7	%		267,277	12.9	%		54,059	14.8	%		53,354	15.0	%
Other water revenues		22,672	1.0	%		14,007	0.6	%		—	—			—	—
Total water revenues		2,181,401	95.4	%		1,981,696	95.4	%		365,067	100.0	%		355,400	100.0	%
Wastewater service		69,049	3.0	%		64,260	3.1	%
Other revenues		35,206	1.6	%		30,607	1.5	%
	$	2,285,656	100.0	%	$	2,076,563	100.0	%

* Certain reclassifications have been made between customer classes to conform to the 2011 presentation.

The following discussion related to water services indicates the increase or decrease in the Regulated Businesses’ revenues and associated billed water sales volumes in gallons by customer class.

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Water services—Water service operating revenues from residential customers for 2010 increased $114.3 million, or 9.6%, from 2009, and is primarily due to rate increases and a slight increase in sales volume. The volume of water sold to residential customers increased by 2.4 billion gallons, or 1.3%, from 2009. We attribute this increase to warmer and drier weather in the Mid-Atlantic region of the United States, primarily in the third quarter of 2010 partially offset by wetter weather in parts of the Midwest region of the United States.

Water service operating revenues from commercial water customers for 2010 increased by $39.9 million, or 9.6%, mainly due to rate increases in addition to an increase in sales volume compared to 2009. The volume of water sold to commercial customers increased by 2.3 billion gallons, or 2.8%, from 2009. We believe this increase is due to the combination of the aforementioned weather conditions and improved economic environment in certain states in which we operate.

Water service operating revenues from industrial customers for 2010 increased by $12.7 million, or 13.0%, from 2009, mainly due to rate increases and an increase in sales volume. The volume of water sold to industrial customers increased 4.3 billion gallons, or 12.1%, from 2009. We believe that this increase is due to an improved economic environment in certain states in which we operate.

Water service operating revenues from public and other customers increased $24.1 million, or 9.0%, from 2009 mainly due to rate increases. Revenues from municipal governments for fire protection services and customers requiring special private fire service facilities totaled $119.8 million for 2010, an increase of $7.8 million from 2009. Revenues generated by sales to governmental entities and resale customers for 2010 totaled $171.6 million, an increase of $16.3 million from 2009.

Wastewater services—Our subsidiaries provide wastewater services in 9 states. Revenues from these services for 2010 increased by $4.8 million, or 7.5%, from 2009. The increase was primarily attributable to increases in rates charged to customers in a number of our operating companies.

Other revenues—Other revenues include such items as reconnection charges, initial application service fees, rental revenues, revenue collection services for others and similar items. For 2010, other revenues increased by $4.6 million mainly due to an increase in rental revenues compared to the same period in the prior year.

Operation and maintenance. Operation and maintenance expense increased $58.9 million, or 5.7%, for 2010 compared to 2009. The following table summarizes these expenses by major expense category as follows:

	For the Years Ended December 31,
	2010		2009		Increase (Decrease)			Percentage
	(in thousands)
Production costs	$	268,529	$	253,908	$	14,621			5.8	%
Employee-related costs		486,969		451,004		35,965			8.0	%
Operating supplies and services		181,968		180,328		1,640			0.9	%
Maintenance materials and services		75,846		60,818		15,028			24.7	%
Customer billing and accounting		44,024		45,004		(980	)		(2.2	)%
Other		38,110		45,503		(7,393	)		(16.2	)%
Total	$	1,095,446	$	1,036,565	$	58,881			5.7	%

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Production costs including fuel and power, purchased water, chemicals and waste disposal increased by $14.6 million, or 5.8%, for 2010 compared to 2009. Production costs by major expense type were as follows:

	For the Years Ended December 31,
	2010		2009		Increase (Decrease)			Percentage
	(in thousands)
Fuel and power	$	89,203	$	84,649	$	4,554			5.4	%
Purchased water		99,834		89,502		10,332			11.5	%
Chemicals		50,875		54,564		(3,689	)		(6.8	)%
Waste disposal		28,617		25,193		3,424			13.6	%
Total	$	268,529	$	253,908	$	14,621			5.8	%

The increase in regulated fuel and power costs was driven by higher costs primarily due to increased production volumes. The increase in purchased water is primarily attributable to higher costs incurred by our suppliers that are passed on to us. The majority of this purchased water increase is in states that permit us to pass-through this increase to our customers without the need for of a full rate proceeding. The decrease in chemical costs is primarily the result of favorable contract pricing in addition to favorable water quality due to reduced rainfall in several of our operating subsidiaries. Waste disposal costs increased primarily due to $1.9 million related to the recognition of previously deferred costs allowed by a cost recovery mechanism in one of our operating companies as well as increases in sludge removal costs in one of our regulated operating companies.

Employee-related costs including wage and salary, group insurance, and pension expense increased $36.0 million, or 8.0%, for 2010 compared to 2009. These employee-related costs represented 44.5% and 43.5% of operation and maintenance expenses for 2010 and 2009, respectively and include the categories shown in the following table.

	For the Years Ended December 31,
	2010		2009		Increase (Decrease)		Percentage
	(in thousands)
Salaries and wages	$	331,913	$	307,120	$	24,793		8.1	%
Pensions		58,134		51,984		6,150		11.8	%
Group insurance		79,958		75,081		4,877		6.5	%
Other benefits		16,964		16,819		145		0.9	%
Total	$	486,969	$	451,004	$	35,965		8.0	%

A driver of the increase in salaries and wages was due to wage increases, higher incentive compensation and severance expenses as well as increased overtime costs of $5.1 million in certain of our regulated operating companies. Pension expense increased for the year ended December 31, 2010 due to increased pension contributions by certain of our regulated operating companies whose costs are recovered based on the actual cash contributions to our pension trust account. This increase was partially offset by a decrease in the amortization of actuarial losses attributable to higher than expected returns on plan assets in 2009. Group insurance increased due to the deferral of $2.7 million of costs in 2009 as part of our Pennsylvania subsidiary’s rate order. The remainder of the cost increase is attributable to the rising cost of health care.

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Operating supplies and services include the day-to-day expenses of office operation, legal and other professional services, as well as information systems and other office equipment rental charges. For 2010 these costs increased by $1.6 million, or 0.9%, compared to 2009.

	For the Years Ended December 31,
	2010		2009		Increase (Decrease)			Percentage
	(in thousands)
Contracted services	$	66,077	$	63,483	$	2,594			4.1	%
Office supplies and services		28,727		28,147		580			2.1	%
Transportation		26,330		24,533		1,797			7.3	%
Rents		15,745		15,339		406			2.6	%
Other		45,089		48,826		(3,737	)		(7.7	)%
Total	$	181,968	$	180,328	$	1,640			0.9	%

The increase in operating supplies and services is attributable to higher consulting expenses and increased transportation costs due to higher gasoline prices during 2010 compared to 2009. Offsetting these increases is the reversal of the $3.5 million payment previously expensed by our California operating company to the CDFG on behalf of NOAA in 2010.

Maintenance materials and services, which includes emergency repairs, as well as costs for preventive maintenance, increased $15.0 million, or 24.7%, for 2010 compared to 2009.

	For the Years Ended December 31,
	2010		2009		Increase (Decrease)		Percentage
	(in thousands)
Maintenance services and supplies	$	75,846	$	60,818	$	15,028		24.7	%

The increased costs above were mainly attributable to higher levels of tank painting, meter testing, pump, tank and well maintenance, and paving costs throughout our regulated subsidiaries.

Customer billing and accounting expenses decreased by $1.0 million, or 2.2%, for 2010 compared to 2009.

	For the Years Ended December 31,
	2010		2009		Increase (Decrease)			Percentage
	(in thousands)
Uncollectible accounts expense	$	18,052	$	20,700	$	(2,648	)		(12.8	)%
Postage		12,348		11,777		571			4.8	%
Other		13,624		12,527		1,097			8.8	%
Total	$	44,024	$	45,004	$	(980	)		(2.2	)%

The decrease in the uncollectible accounts expense was the result of improved collection in our receivables in excess of 120 days which had a favorable impact of $2.7 million on our uncollectible account expense partially offset by increased reserves due to higher accounts receivable balances as a result of increased revenues. This decrease is partially offset by the increase in the other category mainly due to an increase in collection agency fees.

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Other operation and maintenance expenses include casualty and liability insurance premiums and regulatory costs. These costs decreased by $7.4 million, or 16.2%, for 2010 compared to 2009.

	For the Years Ended December 31,
	2010		2009		Increase (Decrease)			Percentage
	(in thousands)
Insurance	$	28,244	$	31,596	$	(3,352	)		(10.6	)%
Regulatory expenses		9,866		13,907		(4,041	)		(29.1	)%
Total	$	38,110	$	45,503	$	(7,393	)		(16.2	)%

The decrease in insurance expense is primarily due to the positive resolution of prior years’ claims in 2010 compared to 2009. Regulatory expenses were higher in 2009 as compared to 2010 due to the write-off of rate case expenses of $3.5 million in our California subsidiary in 2009.

Operating expenses. The increase in operating expenses for the year ended December 31, 2010 compared to the same period in the prior year is primarily due to the increase in operation and maintenance expense, as explained above, higher depreciation expense of $14.7 million and increased general taxes of $16.3 million. The increase in depreciation expense is attributable to our continued investment in our infrastructure and capital expenditures, partially offset by a $2.4 million write-off of certain software costs in 2009. The general taxes increase was due to higher gross receipts taxes of $6.5 million, primarily in our New Jersey regulated subsidiary, higher property taxes of $5.7 million throughout our regulated operating companies, higher capital stock taxes of $1.7 million mainly in our Pennsylvania subsidiary, and higher payroll taxes of $1.9 million as a result of our increased wages and salaries for the year December 31, 2010.

Income from continuing operations before income taxes. The $106.7 million increase for the year ended December 31, 2010, compared to December 31, 2009, is the result of the aforementioned changes in operating revenue and operating expenses.

Market-Based Operations

The following table provides certain financial information for our Market-Based Operations segment for the periods indicated:

	For the years ended December 31,
	2011		2010		2009
	(in thousands)
Operating revenues	$	327,815	$	294,723	$	238,180
Operation and maintenance expense		278,459		256,634		209,084
Operating expenses, net		290,854		269,060		217,643
Income from continuing operations before income taxes		39,250		30,443		25,168

Comparison of Results of Operations for the Years Ended December 31, 2011 and 2010

Operating revenues. The increase in revenues for the year ended December 31, 2011, compared to the same period in 2010, is primarily attributable to an increase in the Contract Operations Group revenues of $22.3 million. This increase is mainly the result of incremental revenues associated with military construction and operations & maintenance projects related to our water and wastewater contracts of $43.7 million, offset by lower revenues associated with other expired and terminated contracts.

Operation and maintenance. Operation and maintenance expense increased $21.8 million, or 8.5%, for the year ended December 31, 2011, compared to the year ended December 31, 2010.

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The following table provides information regarding operation and maintenance expense for the years ended December 31, 2011, and 2010, by major expense category:

	For the years ended December 31,
	2011		2010		Increase (Decrease)			Percentage
	(Dollars in thousands)
Production costs	$	47,897	$	54,203	$	(6,306	)		(11.6	%)
Employee-related costs		75,012		80,596		(5,584	)		(6.9	%)
Operating supplies and services		108,657		83,951		24,706			29.4	%
Maintenance materials and services		38,568		34,484		4,084			11.8	%
Other		8,325		3,400		4,925			144.9	%
Total	$	278,459	$	256,634	$	21,825			8.5	%

Production costs are comprised of fuel and power, purchased water, chemicals and waste disposal costs. The overall decrease in production costs is mainly attributable to decreased fuel and purchased power as well as chemical costs for the year ended December 31, 2011, as compared to the same period in the prior year, as a result of the cessation of costs related to contracts that terminated and expired during 2010.

Employee-related costs, including wage and salary, group insurance and other employee benefits, decreased $5.6 million for the year ended December 31, 2011, compared to the same period in 2010. The decrease in these costs for the year ended December 31, 2011 is primarily due to lower expenses related to expired and terminated contracts partially offset by increased costs associated with our military contracts. Additionally, costs were also lower due to reduced headcount attributable to both eliminated as well as vacant positions compared to the same period in 2010.

Operating supplies and services consist primarily of contracted services and expenses of office operation, legal and other professional services, transportation expenses, as well as information systems rental charges and other office equipment rental charges. The increase in these expenses in 2011 compared to the same period in the prior year was primarily attributable to the higher expenses associated with our Contract Operations Group, which is related to the increased activity with our military construction projects corresponding with the increase in revenues, partially offset by lower expenses due to expired and terminated contracts.

The increase in maintenance materials and supplies of $4.1 million is primarily due to higher maintenance expenses due to increased contract work, corresponding with the increase in revenues.

Other operation and maintenance expenses include casualty and liability insurance premiums and uncollectible accounts expense. Uncollectible accounts expense increased $3.7 million in 2011 and was mainly due to an increase in accounts written-off and deferred revenue advanced billing adjustments in Homeowners Services.

Operating expense. The increase in operating expenses for the year ended December 31, 2011 is primarily driven by the increase in operation and maintenance expense, which is explained above.

Income from continuing operations before income taxes. The $8.8 million increase for the year ended December 31, 2011, is the result of the aforementioned changes in operating revenues and operating and maintenance expense.

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Comparison of Results of Operations for the Years Ended December 31, 2010 and 2009

Operating revenues. The Market-Based Operations’ revenues for 2010 increased by $56.5 million, or 23.7%, from 2009. The increase in these revenues was primarily attributable to higher revenues in our Contract Operations Group revenues of $52.1 million associated with our entry into the industrial operations and maintenance market through an acquisition in December 2009, hereafter referred to as the “Contract Operations’ Acquisition,” increased military contract revenues mainly attributable to incremental contract work awarded to us in 2010, the full year effect in 2010 of two new military contracts announced in 2009 and increased revenues in Homeowner Services, mainly, as a result of increased product penetration within its existing customer base. These increases were partially offset by lower O&M and design and build contract revenues.

Operation and maintenance. Operation and maintenance expense increased $47.6 million, or 22.7%, for the year ended December 31, 2010, compared to the year ended December 31, 2009. Operation and maintenance expenses for 2010 and 2009, by major expense category, were as follows:

	For the years ended December 31,
	2010		2009		Increase (Decrease)			Percentage
	(Dollars in thousands)
Production costs	$	54,203	$	46,848	$	7,355			15.7	%
Employee-related costs		80,596		55,491		25,105			45.2	%
Operating supplies and services		83,951		77,498		6,453			8.3	%
Maintenance materials and services		34,484		24,840		9,644			38.8	%
Other		3,400		4,407		(1,007	)		(22.9	%)
Total	$	256,634	$	209,084	$	47,550			22.7	%

The primary driver of the increase is attributable to our Contract Operations’ Acquisition which accounted for $37.5 million of the increase. The remainder of the increase is mainly due to higher costs related to military contracts resulting from incremental construction projects and growth mainly related to the Fort Meade and Fort Belvoir locations. In addition, Homeowner Services experienced higher contactor repair costs of $3.6 million due to prior claim true-ups coupled with continued growth.

Operating expenses. The increase in operating expenses for the year ended December 31, 2010, from the same period in the prior year, is primarily due to the increase in operation and maintenance expense, as explained above, higher depreciation expense of $1.7 million and increased general taxes of $2.2 million.

Income from continuing operations before income taxes. The $5.3 million increase for the year ended December 31, 2010, compared to December 31, 2009, is the result of the aforementioned changes in operating revenue and operating expenses.

Liquidity and Capital Resources

We regularly evaluate cash requirements for current operations, commitments, development activities and capital expenditures. Our business is very capital intensive and requires significant capital resources. A portion of these capital resources is provided by internally generated cash flows from operations. When necessary, we obtain additional funds from external sources in the debt and equity capital markets and through bank borrowings. Our access to external financing on reasonable terms depends on our credit ratings and current business conditions, including that of the water utility industry in general as well as conditions in the debt or equity capital markets. If these business and market conditions deteriorate to the extent that we no longer have access to the capital markets at reasonable terms, we have access to revolving credit facility with aggregate bank commitments of $840.0 million. We rely on this revolving credit facility and the capital markets to fulfill our short-term liquidity needs, to issue letters of credit and to back our commercial paper program. Disruptions in the

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credit markets may discourage lenders from extending the terms of such commitments or agreeing to new commitments. Market disruptions may also limit our ability to issue debt and equity securities in the capital markets. See “—Credit Facilities and Short-Term Debt.”

In order to meet our short-term liquidity needs, we primarily issue commercial paper which is backed by AWCC’s revolving credit facility. AWCC had no outstanding borrowings and $36.5 million of outstanding letters of credit under its credit facilities as of December 31, 2011. As of December 31, 2011, AWCC had $813.5 million available under our credit facilities that we can use to fulfill our short-term liquidity needs, to issue letters of credit and back our $481.0 million outstanding commercial paper. We can provide no assurances that our lenders will meet their existing commitments or that we will be able to access the commercial paper or loan markets in the future on terms acceptable to us or at all.

In addition, our regulated operating companies receive advances and contributions from customers, home builders and real estate developers to fund construction necessary to extend service to new areas. Advances for construction are refundable for limited periods, which vary according to state regulations, as new customers begin to receive service or other contractual obligations are fulfilled. Amounts which are no longer refundable are reclassified to contributions in aid of construction. Utility plant funded by advances and contributions is excluded from the rate base. Generally, we depreciate contributed property and amortize contributions in aid of construction at the composite rate of the related property. Some of our subsidiaries do not depreciate contributed property, based on regulatory guidelines. A reduction in advances and contributions in aid of construction could reduce our liquidity.

We use our capital resources, including cash, to (i) fund capital requirements, including construction expenditures, (ii) pay off maturing debt, (iii) pay dividends, (iv) fund pension and postretirement welfare obligations and (v) invest in new and existing ventures. We spend a significant amount of cash on construction projects that we expect to have a long-term return on investment. Additionally, we operate in rate-regulated environments in which the amount of new investment recovery may be limited, and where such recovery takes place over an extended period of time, as our recovery is subject to regulatory lag. See “Business—Regulation—Economic Regulation.” We expect to fund future maturities of long-term debt through a combination of external debt and cash flows from operations. Since we continue to make investments equal to or greater than our cash flows from operating activities, we have no plans to reduce debt significantly.

The Company believes it has sufficient liquidity and ability to manage its expenditures should there be a substantial disruption of the capital and credit markets.

The Company expects to have access to liquidity in the capital markets on favorable terms before the maturity dates of its current credit facilities. In addition, the Company can delay major capital investments or other funding requirement or pursue financing from other sources to preserve liquidity, if necessary. The Company believes it can rely upon cash flows from operations to meet its obligations and fund its minimum required capital investments for an extended period of time.

Cash Flows from Operating Activities

Cash flows from operating activities primarily result from the sale of water and wastewater services and, due to the seasonality of demand, are weighted toward the third quarter of each fiscal year. Our future cash flows from operating activities will be affected by economic utility regulation; infrastructure investment; inflation; compliance with environmental, health and safety standards; production costs; customer growth; declining per customer usage of water; weather and seasonality; and overall economic conditions.

Cash flows from operating activities have been a reliable, steady source of funding, sufficient to meet operating requirements, make our dividend payments and fund a portion of our capital expenditures requirements. We will seek access to debt and equity capital markets to meet the balance of our capital

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expenditure requirements as needed. There can be no assurance that we will be able to access such markets successfully on favorable terms or at all. Operating cash flows can be negatively affected by changes in our rate regulated environments or changes in our customers’ economic outlook and ability to pay for service in a timely manner. We can provide no assurance that our customers’ historical payment pattern will continue in the future.

The following table provides a summary of the major items affecting our cash flows from operating activities for the periods indicated:

	2011			2010			2009
	(in thousands)
Net income (loss)	$	309,613		$	267,827		$	(233,083	)
Add (subtract):
Non-cash operating activities(1)		673,795			598,612			1,016,826
Changes in working capital(2)		11,679			45,751			(60,141	)
Pension and postretirement healthcare contributions		(186,730	)		(137,257	)		(127,446	)
Net cash flows provided by operations	$	808,357		$	774,933		$	596,156

(1) Includes, depreciation and amortization, provision for deferred income taxes, amortization of deferred investment tax credits, provision for losses on utility accounts receivable, allowance for other funds used during construction, (gain) loss on sale of assets, and pension and non-pension post retirement benefits expense and other non-cash items. Details of each component can be found in the Consolidated Statements of Cash Flows.

(2) Changes in working capital include changes to accounts receivable and unbilled utility revenue, income taxes receivable, other current assets, accounts payable, taxes accrued (including income taxes), interest accrued and other current liabilities.

The increase in cash flows from operations for the year ended December 31, 2011 compared to the same period in 2010 is primarily driven by additional revenues in 2011 offset by additional pension contributions and the receipt of a tax refund in the first half of 2010 that did not occur in 2011.

The increase in cash flows from operations during 2010 compared to 2009 is primarily due to an increase in revenues and the change in working capital.

The Company currently expects to make pension and postretirement benefit contributions to the plan trusts of $156.7 million in 2012, of which $40.4 million was already made in 2012. In addition, we currently estimate that contributions will amount to $132.1 million in 2013, $155.1 million in 2014, $148.8 million in 2015 and $132.0 million in 2016. Actual amounts contributed could change materially from these estimates as a result of changes in assumptions and investment returns.

Cash Flows from Investing Activities

Cash flows used in investing activities were as follows for the periods indicated:

	For the Years Ended December 31,
	2011			2010			2009
	(in thousands)
Net capital expenditures	$	(924,858	)	$	(765,636	)	$	(785,265	)
Other investing activities, net(1)		12,461			18,893			81,654
Net cash flows used in investing activities	$	(912,397	)	$	(746,743	)	$	(703,611	)

(1) Includes acquisitions, proceeds from the sale of assets and securities, removal costs from property, plant and equipment retirements, net funds released and other.

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The increase in our capital expenditures for the year ended December 31, 2011 is attributable to the construction of and replacement of certain treatment facilities, and infrastructure in our Pennsylvania subsidiary as well as increased capital spending associated with our business transformation project (“BT”) as we moved into its design and build phase.

Current estimates indicate that BT expenditures could total as much as $280 million prior to any AFUDC allowed. Through December 31, 2011, we have spent $139.7 million on the project with $105.3 million spent in 2011. Expenditures associated with BT are included in the estimated capital investment spending of $900 million for 2012 and $800 million to $1 billion in the foreseeable future as outlined above. As with any other initiative of this magnitude, there are risks that could result in increased costs. Any technical difficulties in developing or implementing this initiative, such as implementing a successful change management process, may result in delays, which in turn, may increase the costs of the project and also delay and, perhaps, reduce any cost savings and efficiencies expected to result from the initiative. When we make adjustments to our operations, we may incur incremental expenses prior to realizing the benefits of a more efficient workforce and operating structure. While we believe such expenditures can be recovered through regulated rates, we can provide no guarantee that we will be able to achieve timely rate recovery of these increased costs associated with this transformation project. Any such delays or difficulties encountered with such recovery may have a material and adverse impact on our business, customer relationships and financial results. We believe that the goals of BT—increasing our operating efficiency and effectiveness and controlling the costs associated with the operation of our business—are important to providing the quality service to our customers and communities we serve.

Cash flows used in investing activities increased in 2010 compared to 2009 mainly due to the change in “Other investing activities” in 2010 which resulted from the change in the net restricted funds released attributable primarily to the drawdown of the restricted funds by our Kentucky and Pennsylvania regulated operating companies. This increase was partially offset by a decrease in capital expenditures as a result of delayed construction in the first quarter of 2010 due to the severe weather conditions in certain states in which we operate as well as a higher spending in 2009 on water treatment plant expenditures as a number of facilities were under construction in 2009.

As previously noted, in 2012, we estimate that Company-funded capital investment will total approximately $900 million and for years in the foreseeable future beyond 2012 we estimate that such investment will be between $800 million and $1 billion annually. We intend to invest capital prudently to provide essential services to our regulated customer base, while working with regulators in the various states in which we operate to have the opportunity to earn an appropriate rate of return on our investment and a return of our investment.

Our infrastructure investment plan consists of both infrastructure renewal programs, where we replace infrastructure as needed and major capital investment projects, where we construct new water and wastewater treatment and delivery facilities to meet new customer growth and water quality regulations. Our projected capital expenditures and other investments are subject to periodic review and revision to reflect changes in economic conditions and other factors.

The following table provides a summary of our historical capital expenditures:

	For the Years Ended December 31,
	2011		2010		2009
	(in thousands)
Transmission and distribution	$	298,564	$	299,303	$	309,851
Treatment and pumping		191,771		133,473		125,031
Services, meter and fire hydrants		175,635		157,982		153,455
General structures and equipment		84,059		88,932		94,141
Business transformation project		99,891		22,462		5,139
Sources of supply		58,066		31,452		44,127
Wastewater		16,872		32,032		53,521
Total capital expenditures	$	924,858	$	765,636	$	785,265

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Capital expenditures for the year ended December 31, 2011 increased by $159.2 million or 20.8% compared to the same period in 2010, mainly as a result of the increased BT expenditures of $77.4 million and increased treatment and pumping expenditures of $58.3 million as a result of certain water treatment plants projects in our Pennsylvania, New Jersey and Indiana subsidiaries.

Capital expenditures for 2010 decreased by $19.6 million or 2.5% from $785.3 million in 2009 as a result of delayed construction due to severe weather conditions in the first quarter of 2010 in certain states in which we operate, and increased water treatment facility expenditures in 2009.

One avenue to seek growth is through tuck-ins, by helping commissions with troubled water systems as well as other acquisitions that are complementary to our existing business and support the continued geographical diversification and growth of our operations. Generally, acquisitions are funded initially with short-term debt and later refinanced with the proceeds from long-term debt or equity offerings.

The following provides a summary of the acquisitions and dispositions affecting our cash flows from investing activities in the years indicated:

2011:

• We paid approximately $7.2 million for numerous regulated water and wastewater systems in Missouri, New Jersey, and Pennsylvania, with the largest associated with the acquisition of 11 regulated water systems and 48 wastewater systems in Missouri in May 2011 for a purchase price of $3.3 million.

• We received approximately $10.0 million for the sale of assets and securities, including $6.2 million associated with the sale of our Texas subsidiary’s assets and $2.9 million from the sale of the Applied Water Management subsidiary.

2010:

• We paid approximately $1.6 million for five regulated water systems and one wastewater system.

2009:

• We paid approximately $18.1 million for seven acquisitions which consisted of six regulated water and wastewater systems and the Contract Operations’ Acquisition.

In January 2012, we received $461.0 million in sales proceeds associated with the divestiture of our Arizona and New Mexico subsidiaries. The proceeds will be used to reduce our outstanding commercial paper and fund company operations.

Our investing activities could require considerable capital resources which we have generated through operations and attained through financing activities. We can provide no assurances that these resources will be sufficient to meet our expected investment needs and may be required to delay or reevaluate our investment plans.

Cash Flows from Financing Activities

Our financing activities, primarily focused on funding construction expenditures, include the issuance of long-term and short-term debt, mainly through AWCC. We access capital markets on a regular basis, subject to market conditions. As a result of the anticipated proceeds from the divestiture of our Arizona and New Mexico regulated businesses, we funded the majority of our 2011 cash requirements with commercial paper which will reduced upon receipt of the proceeds from the transaction.

Additionally, because of this transaction and our overall cash flows from operations, we do not anticipate the need for an equity offering in 2012. In addition, new infrastructure may be funded with customer advances and contributions for construction (net of refunds). This amounted to $22.3 million, $7.0 million and $21.2 million for the years ended December 31, 2011, 2010 and 2009, respectively.

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On May 1, 2009, we and AWCC filed a universal shelf registration statement that enabled us to offer and sell from time to time various types of securities, including common stock, preferred stock and debt securities, all subject to market demand and ratings status. During 2011 and 2010, no common stock or preferred stock offerings were made pursuant to this filling.

Pursuant to a public offering in June 2009, the Company completed the sale of 14.5 million shares of common stock at $17.25 per share. The proceeds from the offering, net of underwriters’ discounts and expenses payable by the Company, were $242.3 million. The proceeds from the offering were used to repay short-term debt. At the same time, RWE continued to divest of its investment in the Company. During the remainder of 2009, RWE continued to divest of its remaining investment in the Company through the sale of additional shares and as a result in November 2009, RWE became fully divested of our common stock. The Company did not receive any proceeds from the RWE sales of the Company’s shares.

In regards to debt financings, the following long-term debt was issued in 2011:

Company	Type	Interest Rate	Maturity		Amount (in  thousands)
Other subsidiaries	Private activity bonds and government funded debt –fixed rate	0.00%-1.56%		2031	$	12,510
Total issuances					$	12,510

The following long-term debt was retired through optional redemption or payment at maturity during 2011:

Company	Type	Interest Rate	Maturity		Amount (in  thousands)
American Water Capital Corp.	Senior notes-fixed rate	6.00%-8.25%		2011-2039	$	28,287
Other subsidiaries	Private activity bonds and government funded debt-fixed rate	0.00%-5.90%		2011-2034		7,976
Other subsidiaries	Mortgage bonds—fixed rate	8.21%-9.71%		2011-2022		33,191
Other subsidiaries	Mandatory redeemable preferred stock	4.60%-9.18%		2013-2019		1,888
Other	Capital leases & other					4,078
Total retirements & redemptions					$	75,420

The following long-term debt was issued in 2010:

Company	Type	Interest Rate	Maturity			Amount (in thousands)
American Water Capital Corp.	Private activity bonds and government funded debt—fixed rate	5.38%		2040	a	$	26,000
American Water Capital Corp.	Private activity bonds and government funded debt—fixed rate	5.25%		2040	b		25,000
American Water Capital Corp.	Private activity bonds and government funded debt—fixed rate	5.25%		2040	c		35,000
American Water Capital Corp.	Private activity bonds and government funded debt—fixed rate	4.85%		2040	d		25,000
American Water Capital Corp.	Private activity bonds and government funded debt—fixed rate	5.25%		2028	e		10,635
American Water Capital Corp.	Senior notes—fixed rate	6.00%		2040	f		30,000
Other subsidiaries	Private activity—fixed rate	4.45%-5.60%		2023-2034	g		150,000
Other subsidiaries	Private activity—fixed rate	4.70%-4.88%		2025-2029	h		75,000
Other subsidiaries	Private activity—fixed rate	0.00%-2.56%		2021-2030	i		14,699
Total issuances						$	391,334

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Note: Private activity type defined as private activity bonds and government funded debt.

(a) On June 24, 2010, AWCC closed an offering of $26.0 million in tax-exempt water facility revenue bonds issued by Owen County, Kentucky. The bonds have a coupon of 5.38% with a maturity of 2040 and a 10-year call option. The proceeds from the bond offering will be used to repay short-term debt related to the construction of the water treatment and transmission facility located in Owen County, Kentucky, as well as to pay remaining costs of acquisition, construction, installation and equipping of the water treatment and transmission facility.

(b) On May 27, 2010, AWCC closed an offering of $25.0 million in tax-exempt water facility revenue bonds issued by the Illinois Finance Authority. The bonds have a coupon of 5.25% with a maturity of 2040 and a 10-year call option. The proceeds from the bond offering will be used to fund water facility projects in Champaign, Livingston, Logan, Madison, Peoria and St. Clair counties in Illinois.

(c) On August 18, 2010, AWCC closed an offering of $35.0 million in tax-exempt bonds issued through the State of California Pollution Control Financing Authority. The bonds have a coupon of 5.25% with a 30-year maturity and a 10-year call option. The proceeds from bond offering will be used to fund specific CAWC projects.

(d) On September 16, 2010, AWCC closed an offering of $25.0 million in tax-exempt water facility revenue bonds issued through the Indiana Finance Authority. The bonds have a coupon rate 4.85% with a 30-year maturity and a 10-year call option. The proceeds from the bonds will be used to fund water facility projects in Indiana-American Water Company, Inc.’s service territory.

(e) Represents $10.6 million of variable rate debt that was held in the Company’s treasury at December 31, 2009 because no investors were willing to purchase the bonds. On July 27, 2010, this variable rate debt was remarketed as fixed rate bonds with a coupon rate of 5.25% and a maturity date of 2028.

(f) On December 1, 2010 AWCC closed on a 6.00% senior fixed rate note. Proceeds used to paydown short-term debt.

(g) On July 9, 2010, our operating subsidiary, NJAWC, closed on a refunding of four outstanding bonds issuances. To accomplish this refunding, the New Jersey Economic Development Authority issued three new series of bonds on behalf of NJAWC. The new bonds have coupon rates of 5.60%, 5.10% and 4.45% and maturities of 2034, 2023 and 2023, respectively.

(h) On November 1, 2010, NJAWC closed on refinancings of two outstanding bond issues and the New Jersey Economic Development Authority issued two new series of bonds on behalf of NJAWC.

(i) Proceeds received from various financing/development authorities. The proceeds will be used to fund certain projects.

The following long-term debt was retired through optional redemption or payment at maturity during 2010:

Company	Type	Interest Rate	Maturity		Amount (in thousands)
American Water Capital Corp.	Senior notes-fixed rate	6.00%-6.87%		2011-2039	$	28,157
Other subsidiaries	Private activity-fixed rate and government funded debt	0.00%-6.88%		2010-2036		233,476
Other subsidiaries	Mortgage bonds-fixed rate	7.86%-8.98%		2010-2011		10,275
Other subsidiaries	Mandatory redeemable preferred stock	4.60%-6.00%		2013-2019		218
Other	Capital leases and other					792
Total retirements & redemptions					$	272,918

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The following long-term debt was issued in 2009:

Company	Type	Interest Rate			Maturity			Amount (in thousands)
American Water Capital Corp.	Private activity-fixed rate		6.25	%		2039	a	$	45,390
American Water Capital Corp.	Private activity-fixed rate		6.00	%		2018	b		18,250
American Water Capital Corp.	Private activity-fixed rate		6.10	%		2019	b		17,950
American Water Capital Corp.	Private activity-fixed rate		6.75	%		2031	b		16,700
American Water Capital Corp.	Private activity-fixed rate		6.25	%		2032	c		24,860
American Water Capital Corp.	Private activity-fixed rate		5.63	%		2039	a		26,000
American Water Capital Corp.	Private activity-fixed rate		6.25	%		2032	d		23,325
American Water Capital Corp.	Private activity-fixed rate		5.25	%		2039	e		28,500
American Water Capital Corp.	Senior notes-fixed rate		8.27	%		2039	f		25,500
American Water Capital Corp.	Senior notes-fixed rate		7.21	%		2019	f		24,500
American Water Capital Corp.	Senior notes-fixed rate		8.25	%		2038	f		75,000
American Water Capital Corp.	Senior notes-fixed rate		6.00	%		2039	f		60,000
Other subsidiaries	Private activity-fixed rate		6.20	%		2039	g		80,000
Other subsidiaries	Private activity-fixed rate		1.27	%		2029	h		2,242
Other subsidiaries	Private activity-fixed rate		4.14	%		2029	i		1,315
Other subsidiaries	Private activity-fixed rate		5.00	%		2039	j		10,500
Other subsidiaries	Private activity-fixed rate		5.70	%		2039	j		134,224
Other subsidiaries	Private activity-floating rate		1.00	%		2015	d		8,560
Other subsidiaries	Mortgage bonds-fixed rate		5.48	%		2019	f		25,000
Other subsidiaries	Mortgage bonds-fixed rate		6.35	%		2039	f		75,000
Other	Capital lease		8.82	%		2011			41
Total issuances								$	722,857

(a) The proceeds from the bond offering were used to repay short-term debt related to the construction of a water treatment and transmission facility located in Owen County, Kentucky, as well as to pay the remaining costs of acquisition, construction, installation and equipping of the water treatment and transmission facility as the construction proceeds to completion.

(b) On May 21, 2009, AWCC remarketed $52.9 million of variable rate demand notes as fixed rate Tax Exempt Water Facility Revenue bonds. The net proceeds from this offering was used to repay short-term debt.

(c) On August 27, 2009, AWCC successfully remarketed $24.9 million of variable rate demand notes previously held in the Company’s treasury. The net proceeds from this offering were used to repay short-term debt.

(d) On May 21, 2009, AWCC successfully remarketed $31.9 million of variable rate demand notes previously held in the Company’s treasury. The new notes had an interest rate of 1.00%. The net proceeds from this offering were used to repay commercial paper. Subsequently, on August 27, 2009, AWCC remarketed the $23.3 million of the variable rate demand notes as fixed rate Tax Exempt Water Facility Revenue bonds with an interest rate of 6.25% and the remaining $8.6 million was remarketed at variable rates.

(e) On October 1, 2009 AWCC closed an offering of $28.5 million in tax-exempt water facility revenue bonds with a 10-year call option issued by the Illinois Finance Authority. The proceeds from this offering will be used to fund certain capital improvements.

(f) The proceeds were used to pay down short-term debt.

(g) On April 8, 2009, Pennsylvania-American Water Company (“PAWC”) closed an offering to issue $80.0 million in tax-exempt water facility revenue bonds through the Pennsylvania Economic Development Financing Authority (“PEDFA”). The proceeds from the offering will be used to fund certain capital improvement projects. As of December 31, 2009, we have drawn down $40.7 million of these funds.

(h) On August 26, 2009, PAWC received $2.2 million through the Pennsylvania Infrastructure Investment Authority for the installation of mains in the Hanover and Colliers Water System.

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(i) Ohio-American Water Company received proceeds from the Ohio Water Development Authority. The proceeds were used to fund line replacements in the Ashtabula service area.

(j) On October 20, 2009, NJAWC closed an offering of tax-exempt water facility revenue bonds. The proceeds were use to pay down short-term debt.

In connection with the Contract Operations’ Acquisition, we assumed $4.0 million of capital lease obligations. Also, in December 2009, we refunded and reissued $93.1 million of Pennsylvania-American Water Company private activity general mortgage bonds scheduled to mature in 2032 and 2033. The bond’s 3.60% fixed interest rate expired in December 2009, and the new bonds have a fixed interest rate of 5.50% with a maturity of 2039.

The following long-term debt was retired through optional redemption or payment at maturity during 2009:

Company	Type	Interest Rate	Maturity		Amount (in thousands)
American Water Capital Corp.	Floating rate	1.55%-2.20%		2018-2032	$	86,860
American Water Capital Corp.	Senior notes-fixed rate	6.87%-8.25%		2011-2038		28,147
Other subsidiaries	Floating rate	1.50%-10.00%		2015-2032		33,420
Other subsidiaries	Notes payable and other	5.76%-9.87%		2009-2013		171
Other subsidiaries	Mortgage bonds-fixed rate	6.90%-9.22%		2009-2011		20,847
Other subsidiaries	Private activity-fixed rate	0.00%-5.90%		2009-2034		8,505
Mandatory redeemable preferred stock		4.60%-6.00%		2013-2019		218
Other	Capital lease					181
Total retirements & redemptions					$	178,349

From time to time and as market conditions warrant, we may engage in long-term debt retirements via tender offers, open market repurchases or other viable alternatives to strengthen our balance sheets.

Credit Facilities and Short-Term Debt

The components of short-term debt were as follows:

	December 31, 2011		December 31, 2010
	(in thousands)
Revolving credit lines	$	—	$	2,734
Commercial paper, net of discount		481,048		175,290
Book-overdraft		34,002		50,881
Total short-term debt	$	515,050	$	228,905

On December 22, 2010, AWCC, our finance subsidiary, extended for an additional year a $10.0 million committed revolving line of credit with PNC Bank, N.A which was scheduled to terminate on December 31, 2010. AWCC chose not to extend this credit line and therefore it terminated on December 31, 2011. As such, there were no outstanding borrowings under this revolving line of credit at December 31, 2011. As of December 31, 2010, the outstanding borrowing against this credit line was $2.7 million. This line was used primarily for short-term working capital needs. Interest rates on advances under this line of credit were based on the one month LIBOR on the outstanding debt plus 175 basis points for 2010 and 2011. In addition, there was a fee of 25 basis points charged quarterly on the portion of the commitment that is undrawn.

AWCC has entered into an $840.0 million senior unsecured credit facility syndicated among a group of 10 banks. This revolving credit facility, which is scheduled to expire on September 15, 2012, is principally used to

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support the commercial paper program at AWCC and to provide up to $150.0 million in letters of credit. A majority of the banks agreed to further extend $685.0 million of commitments under this revolving credit facility to September 15, 2013. We closely monitor events in the financial markets and the financial institutions associated with this credit facility. No financial institution has more than 14% of the aggregate commitment through September 15, 2012 and from September 15, 2012 through the current expiration date of September 15, 2013 no institution will have more than 17% of the aggregate commitment. If any lender defaults in its obligation to fund advances, the Company may request the other lenders to assume the defaulting lender’s commitment or replace such defaulting lender by designating an assignee willing to assume the commitment. However, the remaining lenders have no obligation to assume a defaulting lender’s commitment and we can provide no assurances that we will be able to replace a defaulting lender. Prior to the credit facility expiration, we expect to renegotiate or replace it in order to provide sufficient liquidity to finance operations and capital expenditure. The availability of such facility, including the amounts for borrowing thereunder, and its terms and conditions, will depend on the credit markets at the time as well as the Company’s credit ratings and operating requirements.

On December 31, 2011 and 2010, AWCC had the following sub-limits and available capacity under the revolving credit facility and indicated amounts of outstanding commercial paper:

	Credit Facility Commitment		Available Credit Facility Capacity		Letter of Credit Sublimit		Available Letter of Credit Capacity		Outstanding Commercial Paper (Net of Discount)		Credit Line Borrowings
	(in thousands)
December 31, 2011	$	850,000	$	813,548	$	150,000	$	113,548	$	481,048	$	—
December 31, 2010	$	850,000	$	810,469	$	150,000	$	113,203	$	175,290	$	2,734

AWCC had no outstanding borrowings under the credit facilities and $32.0 million of outstanding letters of credit under this credit facility as of February 21, 2012. Also, as of February 21, 2012, AWCC had $94.7 million of commercial paper outstanding.

Interest rates on advances under the revolving credit facility are based on either prime or LIBOR plus an applicable margin based upon our credit ratings, as well as total outstanding amounts under the agreement at the time of the borrowing. The maximum LIBOR margin is 55 basis points.

The weighted average interest rate on short-term borrowings for the years ended December 31, 2011 and 2010 was approximately 0.41% and 0.42%, respectively.

Capital Structure

The following table indicates the percentage of our capitalization represented by the components of our capital structure as of December 31, 2011, 2010 and 2009:

	At December 31, 2011			At December 31, 2010			At December 31, 2009
Common stockholder equity and preferred stock without mandatory redemption rights		42	%		42	%		42	%
Long-term debt and redeemable preferred stock at redemption value		53	%		55	%		56	%
Short-term debt and current portion of long-term debt		5	%		3	%		2	%
		100	%		100	%		100	%

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The change in the 2011 capital structure compared to 2010 is mainly attributable to the increase in outstanding commercial paper in 2011 compared to 2010. We used the net proceeds from the sale of our Arizona and New Mexico subsidiaries to pay down commercial paper.

Debt Covenants

Our debt agreements contain financial and non-financial covenants. To the extent that we are not in compliance, we or our subsidiaries may be restricted in our ability to pay dividends, issue debt or access our revolving credit lines. We were in compliance with our covenants as of December 31, 2011. Long-term debt indentures contain a number of covenants that, among other things, limit the Company from issuing debt secured by the Company’s assets, subject to certain exceptions.

Certain long-term notes and the revolving credit facility requires us to maintain a ratio of consolidated total indebtedness to consolidated total capitalization of not more than 0.70 to 1.00. On December 31, 2011, our ratio was 0.58 to 1.00 and therefore we were in compliance with the ratio.

Security Ratings

Our access to the capital markets, including the commercial paper market, and respective financing costs in those markets, is directly affected by securities ratings of the entity that is accessing the capital markets. We primarily access the capital markets, including the commercial paper market, through AWCC. However, we also issue debt at our regulated subsidiaries, primarily in the form of tax exempt securities, to lower our overall cost of debt. On November 30, 2011, Moody’s Investors Service, which we refer to as Moody’s, reaffirmed its “Baa2” corporate credit rating on AWCC and American Water and AWCC’s “P2” short-term rating. The rating outlook for both American Water and AWCC is stable. On January 30, 2012, Standard & Poor’s Ratings Services, which we refer to as S&P, reaffirmed its “BBB+” corporate credit rating on AWCC and American Water and AWCC’s “A2” short-term rating. S&P’s rating outlook for both American Water and AWCC is stable

The following table shows the Company’s securities ratings as of December 31, 2011:

Securities	Moody’s Investors Service		Standard & Poor’s Ratings Service
Senior unsecured debt		Baa2		BBB+
Commercial paper		P2		A2

A security rating is not a recommendation to buy, sell or hold securities and may be subject to revision or withdrawal at any time by the assigning rating agency, and each rating should be evaluated independently of any other rating. Security ratings are highly dependent upon our ability to generate cash flows in an amount sufficient to service our debt and meet our investment plans. We can provide no assurances that our ability to generate cash flow is sufficient to maintain our existing ratings. None of our borrowings are subject to default or prepayment as a result of the downgrading of these security ratings, although such a downgrading could increase fees and interest charges under our credit facilities.

As part of the normal course of business, we routinely enter into contracts for the purchase and sale of water, energy, chemicals and other services. These contracts either contain express provisions or otherwise permit us and our counterparties to demand adequate assurance of future performance when there are reasonable grounds for doing so. In accordance with the contracts and applicable contract law, if we are downgraded by a credit rating agency, especially if such downgrade is to a level below investment grade, it is possible that a counterparty would attempt to rely on such a downgrade as a basis for making a demand for adequate assurance

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of future performance. Depending on the Company’s net position with a counterparty, the demand could be for the posting of collateral. In the absence of expressly agreed provisions that specify the collateral that must be provided, the obligation to supply the collateral requested will be a function of the facts and circumstances of the Company’s situation at the time of the demand. If we can reasonably claim that we are willing and financially able to perform our obligations, it may be possible to argue successfully that no collateral should be posted or that only an amount equal to two or three months of future payments should be sufficient. We do not expect to post any collateral which will have a material adverse impact on the Company’s results of operations, financial position or cash flows.

Dividends

Our board of directors has adopted a dividend policy to distribute to our stockholders a portion of our net cash provided by operating activities as regular quarterly dividends, rather than retaining that cash for other purposes. We expect that dividends will be paid quarterly to holders of record approximately 15 days prior to the distribution date. Since the dividends on our common stock will not be cumulative, only declared dividends will be paid.

During 2011, 2010 and 2009, we paid $157.9 million, $150.3 million and $137.3 million in dividends, respectively. For 2011, we paid a dividend of $0.23 per share on December 1 and September 1 and $0.22 per share on June 1 and March 1. For 2010, we paid a dividend of $0.22 per share on December 1 and September 1 and $0.21 per share on June 1 and March 1. For 2009, we paid a dividend of $0.21 per share on December 1 and September 1 and $0.20 per share on June 1 and March 2.

Subject to applicable law and the discretion of our board of directors, we will pay cash dividends of approximately $0.23 per share per quarter in 2012, to be paid approximately 60 days after the end of each fiscal quarter. The quarterly and annual average aggregate dividend amounts for the four quarters would be $40.4 million, and $161.6 million annually. The aggregate dividend amounts are based upon 175.7 million shares outstanding as of December 31, 2011. Under Delaware law, our board of directors may declare dividends only to the extent of our “surplus” (which is defined as total assets at fair market value minus total liabilities, minus statutory capital) or, if there is no surplus, out of our net profits for the then current and/or immediately preceding fiscal year. Although we believe we will have sufficient net profits or surplus to pay dividends at the anticipated levels during the next four quarters, our board of directors will seek periodically to assure itself of this before actually declaring any dividends. In future periods, our board of directors may seek opinions from outside valuation firms to the effect that our solvency or assets are sufficient to allow payment of dividends, and such opinions may not be forthcoming. If we sought and were not able to obtain such an opinion, we likely would not be able to pay dividends.

On December 9, 2011, our board of directors declared a quarterly cash dividend payment of $0.23 per share payable on March 1, 2012 to all shareholders of record as of February 3, 2012. Additionally, on February 24, 2012, our board of directors declared a quarterly cash dividend payment of $0.23 per share payable on June 1, 2012 to all shareholders of record as of April 20, 2012.

Regulatory Restrictions

The issuance by the Company or AWCC of long-term debt or equity securities does not require authorization of any state PUC if no guarantee or pledge of the regulated subsidiaries is utilized. However, state PUC authorization is required to issue long-term debt or equity securities at most of our regulated subsidiaries. Our regulated subsidiaries normally obtain the required approvals on a periodic basis to cover their anticipated financing needs for a period of time or in connection with a specific financing.

Under applicable law, our subsidiaries can pay dividends only from retained, undistributed or current earnings. A significant loss recorded at a subsidiary may limit the dividends that the subsidiary can distribute to us.

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Insurance Coverage

We carry various property, casualty and financial insurance policies with limits, deductibles and exclusions that we believe are consistent with industry standards. However, insurance coverage may not be adequate or available to cover unanticipated losses or claims. We are self-insured to the extent that losses are within the policy deductible or exceed the amount of insurance maintained. Such losses could have a material adverse effect on our short-term and long-term financial condition and our results of operations and cash flows.

Contractual Obligations and Commitments

We enter into obligations with third parties in the ordinary course of business. These financial obligations, as of December 31, 2011, are set forth in the table below:

Contractual obligation	Total		Less Than 1 Year		1-3 Years		3-5 Years		More Than 5 Years
	(in thousands)
Long-term debt obligations(a)	$	5,316,578	$	27,719	$	118,275	$	93,100	$	5,077,484
Interest on long-term debt(b)		5,313,845		325,398		641,553		632,397		3,714,497
Capital lease obligations(c)		1,264		237		157		78		792
Interest on capital lease obligations(d)		1,208		141		226		212		629
Operating lease obligations(e)		175,869		21,528		32,820		20,049		101,472
Purchase water obligations(f)		683,707		48,916		95,028		90,843		448,920
Other purchase obligations(g)		72,824		72,824		—		—		—
Postretirement benefit plans’ obligations(h)		165,883		29,983		56,400		53,400		26,100
Pension Plan’s obligations(h)		671,100		126,700		230,800		227,400		86,200
Preferred stocks with mandatory redemption requirements		22,101		899		3,578		3,562		14,062
Interest on preferred stocks with mandatory redemption requirements		17,786		1,849		3,297		2,700		9,940
Other obligations(i)		814,790		205,919		103,834		61,259		443,778
Total	$	13,256,955	$	862,113	$	1,285,968	$	1,185,000	$	9,923,874

Note: The above table reflects only financial obligations and commitments. Therefore, performance obligations associated with our Market-Based Operations are not included in the above amounts.

(a) Represents sinking fund obligations and debt maturities.

(b) Represents expected interest payments on outstanding long-term debt. Amounts reported may differ from actual due to future refinancing of debt.

(c) Represents future minimum payments under noncancelable capital leases.

(d) Represents expected interest payments on noncancelable capital leases.

(e) Represents future minimum payments under noncancelable operating leases, primarily for the lease of motor vehicles, buildings, land and other equipment including water facilities and systems constructed by partners under the Public-Private Partnerships described below.

(f) Represents future payments under water purchase agreements for minimum quantities of water.

(g) Represents the open purchase orders as of December 31, 2011, for goods and services purchased in the ordinary course of business.

(h) Represents contributions expected to be made to pension and post retirement benefit plans for the years 2012 through 2017.

(i) Includes an estimate of advances for construction to be refunded, capital expenditures estimated to be required under legal and binding contractual obligations, contracts entered into for energy purchases, a liability associated with a conservation agreement and service agreements.

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Public-Private Partnerships

West Virginia-American Water Company, which we refer to as WVAWC, has entered into a series of agreements with various public entities, which we refer to as the Partners, to establish certain joint ventures, commonly referred to as “public-private partnerships.” Under the public-private partnerships, WVAWC constructed utility plant, financed by WVAWC, and the Partners constructed utility plant (connected to WVAWC’s property), financed by the Partners. WVAWC agreed to transfer and convey some of its real and personal property to the Partners in exchange for an equal principal amount of Industrial Development Bonds, commonly referred to as IDBs, issued by the Partners under a state Industrial Development Bond and Commercial Development Act. WVAWC leased back the total facilities, including portions funded by both WVAWC and the Partners, under leases for a period of 40 years.

WVAWC leased back the transferred facilities under capital leases for a period of 40 years. The leases have payments that approximate the payments required by the terms of the IDBs. We have presented the transaction on a net basis in the consolidated financial statements. The carrying value of the transferred facilities was approximately $159.2 million at December 31, 2011.

Performance Obligations

We have entered into agreements for the provision of services to water and wastewater facilities for the United States military, municipalities and other customers. These military services agreements expire between 2051 and 2060 and have remaining performance commitments as measured by estimated remaining contract revenues of $2,037.0 million at December 31, 2011. The Operations and Maintenance agreements with municipalities and other customers expire between 2012 and 2048 and have remaining performance commitments as measured by estimated remaining contract revenue of $1,076.0 million at December 31, 2011. Some of the Company’s long-term contracts to operate and maintain a municipality’s, federal government’s or other party’s water or wastewater treatment and delivery facilities include responsibility for certain major maintenance for some of the facilities, in exchange for an annual fee.

Critical Accounting Policies and Estimates

The application of critical accounting policies is particularly important to our financial condition and results of operations and provides a framework for management to make significant estimates, assumptions and other judgments. Although our management believes that these estimates, assumptions and other judgments are appropriate, they relate to matters that are inherently uncertain. Accordingly, changes in the estimates, assumptions and other judgments applied to these accounting policies could have a significant impact on our financial condition and results of operations as reflected in our consolidated financial statements.

Our financial condition, results of operations and cash flows are impacted by the methods, assumptions and estimates used in the application of critical accounting policies. Management believes that the areas described below require significant judgment in the application of accounting policy or in making estimates and assumptions in matters that are inherently uncertain and that may change in subsequent periods. Our management has reviewed these critical accounting policies, and the estimates and assumptions regarding them, with our audit committee. In addition, our management has also reviewed the following disclosures regarding the application of these critical accounting policies with the audit committee.

Regulatory Accounting

Our regulated utility subsidiaries are subject to regulation by state PUCs and the local governments of the states in which they operate. As such, we account for these regulated operations in accordance with authoritative guidance that requires us to reflect the effects of rate regulation in our financial statements. Use of the authoritative guidance is applicable to utility operations that meet the following criteria (1) third-party regulation of rates; (2) cost-based rates; and (3) a reasonable assumption that all costs will be recoverable from customers

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through rates. As of December 31, 2011, we had concluded that the operations of our regulated subsidiaries meet the criteria. If it is concluded in a future period that a separable portion of the business no longer meets the criteria, we are required to eliminate the financial statement effects of regulation for that part of the business, which would include the elimination of any or all regulatory assets and liabilities that had been recorded in the consolidated financial statements. Failure to meet the criteria of the authoritative guidance could materially impact our consolidated financial statements as a one-time extraordinary item and continued impacts on our operating activities.

Regulatory assets represent costs that have been deferred to future periods when it is probable that the regulator will allow for recovery through rates charged to customers. Regulatory liabilities represent revenues received from customers to fund expected costs that have not yet been incurred. As of December 31, 2011, we have recorded $1,079.7 million of net regulatory assets within our Consolidated Financial Statements. Also, at December 31, 2011, we had recorded $325.8 million of regulatory liabilities within our consolidated financial statements. See Note 7 of the Notes to Consolidated Financial Statements for further information regarding the significant regulatory assets and liabilities.

For each regulatory jurisdiction where we conduct business, we continually assess whether the regulatory assets and liabilities continue to meet the criteria for probable future recovery or settlement. This assessment includes consideration of factors such as changes in applicable regulatory environments, recent rate orders to other regulated entities in the same jurisdiction, the status of any pending or potential deregulation legislation and the ability to recover costs through regulated rates. If subsequent events indicate that the regulatory assets or liabilities no longer meet the criteria for probable future recovery or settlement, our statement of operations and financial position could be materially affected.

Goodwill

The Company’s annual impairment reviews are performed as of November 30 of each year, in conjunction with the timing of the completion of the Company’s annual strategic business plan. At December 31, 2011, the Company’s goodwill was $1,195.1 million. The Company also undertakes interim reviews when the Company determines that a triggering event that would more likely than not reduce the fair value of a reporting unit below its carrying value has occurred.

The Company uses a two-step impairment test to identify potential goodwill impairment and measures the amount of a goodwill impairment loss to be recognized (if any). The step 1 calculation used to identify potential impairment compares the calculated fair value for each of the Company’s reporting units to their respective net carrying values (book values), including goodwill, on the measurement date. If the fair value of any reporting unit is less than such reporting unit’s carrying value, then step 2 is performed to measure the amount of the impairment loss (if any) for such reporting unit.

The step 2 calculation of the impairment test compares, by reporting unit, the implied fair value of the goodwill to the carrying value of goodwill. The implied fair value of goodwill is equal to the excess of the fair value of each reporting unit above the fair value of such reporting unit’s identified assets and liabilities. If the carrying value of goodwill exceeds the implied fair value of goodwill for any reporting unit, an impairment loss is recognized in an amount equal to the excess (not to exceed the carrying value of goodwill) for that reporting unit.

The determination of the fair value of each reporting unit and the fair value of each reporting unit’s assets and liabilities is performed as of the measurement date using observable market data before and after the measurement date (if that subsequent information is relevant to the fair value on the measurement date).

For the November 30, 2011 impairment test, the estimated fair value of the each reporting unit for step 1 was based on a combination of the following valuation techniques:

• observable trading prices of comparable equity securities of publicly-traded water utilities considered by us to be the Company’s peers; and

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• discounted cash flow models developed from the Company’s internal forecasts.

The first valuation technique applies average peer multiples to each reporting unit’s historic and forecasted cash flows. The peer multiples are calculated using the average trading prices of comparable equity securities, their published cash flows and forecasts of market price and cash flows for those peers.

The second valuation technique forecasts each reporting unit’s five-year cash flows using an estimated long-term growth rate and discounts these cash flows at their respective estimated weighted average cost of capital.

The Company has completed its November 30, 2011 annual impairment review and based on this review the Company’s goodwill balance was not impaired. The Company’s fair value calculated in its 2011 impairment test period was greater than the aggregate carrying value of its reporting units.

However, there can be no assurances that the Company will not be required to recognize an impairment of goodwill in the future due to market conditions or other factors related to the Company’s performance. These market events could include a decline over a period of time of the Company’s stock price, a decline over a period of time in valuation multiples of comparable water utilities, the lack of an increase in the Company’s market price consistent with its peer companies, or decreases in control premiums. A decline in the forecasted results in our business plan, such as changes in rate case results or capital investment budgets or changes in our interest rates, could also result in an impairment charge.

We also made certain assumptions, which we believe to be appropriate, that support the fair value of our reporting units. We considered, in addition to the listed trading price of the Company’s shares, the applicability of a control premium to our shares and certain other factors we deemed appropriate. As a result, we concluded that the Company’s fair value exceeds what we might otherwise have concluded had we relied on market price alone.

The difference between our calculated market capitalization (which approximates carrying value) and the aggregate fair value of our reporting units resulted from an estimated control premium. The estimated control premium represents the incremental premium a buyer is willing to pay to acquire a controlling, majority interest in the Company. In estimating the control premium, management principally considered the current market conditions and historical premiums paid in utility acquisitions observed in the marketplace.

For the year ended December 31, 2011, no impairment charge was recorded for our continuing operations. In 2011, we recorded a charge to goodwill of $25.5 million relating to parent company goodwill associated with businesses classified as discontinued operations. For the year ended December 31, 2010, no impairment charge was recorded. For the year ended December 31, 2009 we recorded impairment charges for goodwill in the amounts of $428.0 million and $22.0 million, for our continuing and discontinued operations, respectively.

Impairment of Long-Lived Assets

Long-lived assets include land, buildings, equipment and long-term investments. Long-lived assets, other than investments and land are depreciated over their estimated useful lives, and are reviewed for impairment whenever changes in circumstances indicate the carrying value of the asset may not be recoverable. Such circumstances would include items such as a significant decrease in the market value of a long-lived asset, a significant adverse change in the manner in which the asset is being used or planned to be used or in its physical condition, or a history of operating or cash flow losses associated with the use of the asset. In addition, changes in the expected useful life of these long-lived assets may also be an impairment indicator. When such events or changes occur, we estimate the fair value of the asset from future cash flows expected to result from the use and, if applicable, the eventual disposition of the assets, and compare that to the carrying value of the asset. If the carrying value is greater than the fair value, an impairment loss is recognized equal to the amount by which the asset’s carrying value exceeds its fair value. The key variables that must be estimated include assumptions

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regarding sales volume, rates, operating costs, labor and other benefit costs, capital additions, assumed discount rates and other economic factors. These variables require significant management judgment and include inherent uncertainties since they are forecasting future events. A variation in the assumptions used could lead to a different conclusion regarding the realizability of an asset and, thus, could have a significant effect on the consolidated financial statements.

The long-lived assets of the regulated utility subsidiaries are grouped on a separate entity basis for impairment testing as they are integrated state-wide operations that do not have the option to curtail service and generally have uniform tariffs. A regulatory asset is charged to earnings if and when future recovery in rates of that asset is no longer probable.

The fair values of long-term investments are dependent on the financial performance and solvency of the entities in which we invest, as well as volatility inherent in the external markets. In assessing potential impairment for these investments, we consider these factors. If such assets are considered impaired, an impairment loss is recognized equal to the amount by which the asset’s carrying value exceeds its fair value.

Revenue Recognition

Revenues of the regulated utility subsidiaries are recognized as water and wastewater services are delivered to customers and include amounts billed to customers on a cycle basis and unbilled amounts based on estimated usage from the date of the latest meter reading to the end of the accounting period. Unbilled utility revenues as of December 31, 2011 and 2010 were $134.9 million and $132.9 million, respectively. Increases in volumes delivered to the utilities’ customers and favorable rate mix due to changes in usage patterns in customer classes in the period could be significant to the calculation of unbilled revenue. Changes in the timing of meter reading schedules and the number and type of customers scheduled for each meter reading date would also have an effect on the estimated unbilled revenue; however, since the majority of our customers are billed on a monthly basis, total operating revenues would remain materially unchanged.

Revenue from Market-Based Operations is recognized as services are rendered. Revenues from certain construction projects are recognized over the contract term based on the estimated percentage of completion during the period compared to the total estimated services to be provided over the entire contract. Losses on contracts are recognized during the period in which the loss first becomes probable and estimable. Revenues recognized during the period in excess of billings on construction contracts are recorded as unbilled revenue. Billings in excess of revenues recognized on construction contracts are recorded as other current liabilities on the balance sheet until the recognition criteria are met. Changes in contract performance and related estimated contract profitability may result in revisions to costs and revenues and are recognized in the period in which revisions are determined.

Accounting for Income Taxes

The parent company and its subsidiaries participate in a consolidated federal income tax return for United States tax purposes. Members of the consolidated group are charged with the amount of federal income tax expense determined as if they filed separate returns.

Certain income and expense items are accounted for in different time periods for financial reporting than for income tax reporting purposes. The Company provides deferred income taxes on the difference between the tax basis of assets and liabilities and the amounts at which they are carried in the financial statements. These deferred income taxes are based on the enacted tax rates expected to be in effect when these temporary differences are projected to reverse. In addition, the regulated utility subsidiaries recognize regulatory assets and liabilities for the effect on revenues expected to be realized as the tax effects of temporary differences, previously flowed through to customers, reverse.

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Accounting for Pension and Postretirement Benefits

We maintain noncontributory defined benefit pension plans covering eligible employees of our regulated utility and shared service operations. The pension plans have been closed for most employees hired on or after January 1, 2006. Union employees hired on or after January 1, 2001 and non-union employees hired on or after January 1, 2006 will be provided with a 5.25% of base pay defined contribution plan. We also maintain postretirement benefit plans for eligible retirees. The retiree welfare plans are closed for union employees hired on or after January 1, 2006. The plans had previously closed for non-union employees hired on or after January 1, 2002. See Note 15 of the Notes to Consolidated Financial Statements for further information regarding the accounting for the defined benefit pension plans and postretirement benefit plans.

The Company’s pension and postretirement benefit costs are developed from actuarial valuations. Inherent in these valuations are key assumptions provided by the Company to its actuaries, including the discount rate and expected long-term rate of return on plan assets. Material changes in the Company’s pension and postretirement benefit costs may occur in the future due to changes in these assumptions as well as fluctuations in plan assets. The assumptions are selected to represent the average expected experience over time and may differ in any one year from actual experience due to changes in capital markets and the overall economy. These differences will impact the amount of pension and other postretirement benefit expense that the Company recognizes. The primary assumptions are:

• Discount Rate—The discount rate is used in calculating the present value of benefits, which are based on projections of benefit payments to be made in the future. The objective in selecting the discount rate is to measure the single amount that, if invested at the measurement date in a portfolio of high-quality debt instruments, would provide the necessary future cash flows to pay the accumulated benefits when due;

• Expected Return on Plan Assets (“EROA”)—Management projects the future return on plan assets considering prior performance, but primarily based upon the plans’ mix of assets and expectations for the long-term returns on those asset classes. These projected returns reduce the net benefit costs we record currently;

• Rate of Compensation Increase—Management projects employees’ pay increases, which are used to project employees’ pension benefits at retirement; and

• Health Care Cost Trend Rate—Management projects the expected increases in the cost of health care.

The discount rate assumption, which is determined for the pension and postretirement benefit plans independently, is subject to change each year, consistent with changes in applicable high-quality, long-term corporate bond indices. At year end 2011, we began using an approach that approximate the process of settlement obligations tailored to the plans’ expected cash flows to the coupons and expected maturity values of individually selected bonds. The yield curve was developed for a portfolio containing the majority of United States-issued Aa-graded non-callable (or callable with make-whole provisions) corporate bonds. For each plan, the discount rate was developed as the level equivalent rate that would yield the same present value as using spot rates aligned with the projected benefit payments. The discount rate for determining pension benefit obligations was 5.02%, 5.32% and 5.93% at December 31, 2011, 2010 and 2009, respectively. The discount rate for determining other post-retirement benefit obligations was 5.05%, 5.27% and 5.82% at December 31, 2011, 2010 and 2009, respectively.

In selecting an expected return on plan assets, we considered tax implications, past performance and economic forecasts for the types of investments held by the plans. The long-term EROA assumption used in calculating pension cost was 7.90% for 2011, 2010, and 2009. The weighted average EROA assumption used in calculating other postretirement benefit costs was 7.60% for 2011, 2010 and 2009.

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The asset allocations for the Company’s U.S. pension plan at December 31, 2011 and 2010, by asset category, are as follows:

	Target Allocation 2011			Percentage of Plan Assets At December 31,
Asset category				2011			2010
Equity securities		70	%		70	%		70	%
Fixed income		30	%		30	%		30	%
Total		100	%		100	%		100	%

The investment policy guidelines of the pension plan require that the fixed income portfolio has an overall weighted average credit rating of AA or better by Standard & Poor’s and the minimum credit quality for fixed income securities must be BBB- or better. Up to 20% of the portfolio may be invested in collateralized mortgage obligations backed by the United States Government.

The Company’s other postretirement benefit plans are partially funded. The asset allocations for the Company’s other postretirement benefit plans at December 31, 2011 and 2010, by asset category, are as follows:

Asset category	Target Allocation 2011			Percentage of Plan Assets At December 31,
				2011			2010
Equity securities		70	%		70	%		70	%
Fixed income		30	%		30	%		30	%
Total		100	%		100	%		100	%

The Company’s investment policy, and related target asset allocation, is evaluated periodically through asset liability studies. The studies consider projected cash flows of maturity liabilities, projected asset class return risk, and correlation and risk tolerance.

The pension and postretirement welfare plan trusts investments include debt and equity securities held directly and through commingled funds. The trustee for the Company’s defined benefit pension and post retirement welfare plans uses independent valuation firms to calculate the fair value of plan assets. Additionally, the company independently verifies the assets values. Approximately 59.0% of the assets are valued using the quoted market price for the assets in an active market at the measurement date, while 41.0% of the assets are valued using other inputs.

In selecting a rate of compensation increase, we consider past experience in light of movements in inflation rates. Our rate of compensation increase was 3.25% for 2011, 3.50% for 2010 and 4.00% for 2009.

In selecting health care cost trend rates, we consider past performance and forecasts of increases in health care costs. Our health care cost trend rate used to calculate the periodic cost was 8.00% in 2011 gradually declining to 5.00% in 2017 and thereafter.

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Assumed health care cost trend rates have a significant effect on the amounts reported for the other postretirement benefit plans. The health care cost trend rate is based on historical rates and expected market conditions. A one-percentage-point change in assumed health care cost trend rates would have the following effects:

Change in Actuarial Assumption	Impact on Other Postretirement Benefit Obligation at December 31, 2011		Impact on 2011 Total Service and Interest Cost Components
	(in thousands)
Increase assumed health care cost trend by 1%	$	83,456	$	7,145
Decrease assumed health care cost trend by 1%	$	69,318	$	5,838

We will use a discount rate and EROA of 5.02% and 7.75%, respectively, for estimating our 2012 pension costs. Additionally, we will use a discount rate and EROA of 5.05% and 7.41%, respectively, for estimating our 2012 other postretirement benefit costs. A decrease in the discount rate or the EROA would increase our pension expense. Our 2011 and 2010 pension and postretirement costs, including such expenses charged to our discontinued operations, were $87.3 million and $80.0 million, respectively. The Company currently expects to make pension and postretirement benefit contributions to the plan trusts of $156.7 million, $132.1 million, $155.1 million, $148.8 million and $132.0 million in 2012, 2013, 2014, 2015 and 2016 respectively. Actual amounts contributed could change significantly from these estimates.

The assumptions are reviewed annually and at any interim re-measurement of the plan obligations. The impact of assumption changes is reflected in the recorded pension and postretirement benefit amounts as they occur, or over a period of time if allowed under applicable accounting standards. As these assumptions change from period to period, recorded pension and postretirement benefit amounts and funding requirements could also change.

New Accounting Standards

Fair Value Measurements

In May 2011, the FASB issued updated accounting guidance related to fair value measurements and disclosures that result in common fair value measurements and disclosures between U.S. GAAP and International Financial Reporting Standards. This new guidance amends current fair value measurement and disclosure guidance to increase transparency around valuation inputs and investment categorization. This guidance is effective for interim and annual periods beginning after December 15, 2011. The new guidance is to be adopted prospectively and early adoption is not permitted. The Company does not expect the adoption of this guidance to have a significant impact on the Company’s results of operations, financial position or cash flows.

Comprehensive Income

In June 2011, the FASB issued new guidance on the presentation of comprehensive income. The new guidance allows an entity to present components of net income and other comprehensive income in one continuous statement or in two separate, but consecutive statements. The new guidance eliminates the current option to report other comprehensive income and its components in the statement of changes in equity. While the new guidance changes the presentation of comprehensive income, there are no changes to the components that are recognized in net income or other comprehensive income under current accounting guidance. On October 21, 2011, the FASB tentatively decided to propose delaying the effective date of the presentation requirements for reclassification adjustments in the new guidance. This new guidance on the presentation of comprehensive income is effective for fiscal years and interim periods beginning after December 15, 2011. As the Company already presents the components of net income and other comprehensive income in one continuous statement, the adoption of the new guidance will not have an impact on its results of operations, financial position or cash flows.

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Testing Goodwill for Impairment

In September 2011, the FASB updated the accounting guidance related to testing goodwill for impairment. This update permits an entity to first assess qualitative factors to determine whether it is necessary to perform the two-step quantitative goodwill impairment test that is currently in place. Under the new guidance, an entity will not be required to calculate the fair value of a reporting unit unless the entity determines, based on the qualitative assessment, that it is more likely than not that its fair value is less than its carrying amount. This update is effective for annual and interim goodwill impairment tests performed in fiscal years beginning after December 15, 2011; however, early adoption is permitted. The Company is evaluating the specific provisions of the updated guidance, but does not expect the adoption of this guidance to have a significant impact on the Company’s results of operations, financial position or cash flows.

Revenue Arrangements with Multiple Deliverables

In October 2009, the Financial Accounting Standards Board (“FASB”) issued authoritative guidance that amends existing guidance for identifying separate deliverables in a revenue-generating transaction where multiple deliverables exist, and provides guidance for allocating and recognizing revenue based on those separate deliverables. The guidance is expected to result in more multiple-deliverable arrangements being separable than under current guidance. This guidance was effective for the Company beginning on January 1, 2011 and is required to be applied prospectively to new or significantly modified revenue arrangements. The adoption of this guidance did not have a significant impact on the Company’s results of operations, financial position or cash flows.

Business Combinations

In December 2010, the FASB clarified the requirements for reporting of pro forma revenue and earnings disclosures for business combinations. The accounting update specified that if a public entity presents comparative financial statements, the entity should disclose revenue and earnings of the combined entity as though the business combination(s) that occurred during the current year had occurred as of the beginning of the comparable prior annual reporting period only. The amendments also expanded the supplemental pro forma disclosures to include a description of the nature and amount of material, nonrecurring pro forma adjustments directly attributable to the business combination included in the reported pro forma revenue and earnings. The amendments are effective prospectively for business combinations finalized after January 1, 2011. As this guidance clarifies and provides for additional disclosure requirements only, the adoption of this guidance has not had a material impact on the Company’s results of operations, financial position or cash flows.

Intangibles—Goodwill

In December 2010, the FASB issued authoritative guidance that modifies step 1 of the goodwill impairment test for reporting units with zero or negative carrying amounts. The update requires that for those reporting units, an entity is required to perform step 2 of the goodwill impairment test if it is more likely than not that a goodwill impairment exists. In determining whether it is more likely than not that a goodwill impairment exists, an entity should consider whether there are any adverse qualitative factors indicating that an impairment may exist. The qualitative factors are consistent with existing authoritative guidance, which requires that goodwill of a reporting unit be tested for impairment between annual tests if an event occurs or circumstances change that would more likely than not reduce the fair value of a reporting unit below its carrying amount. This guidance was effective for the Company beginning on January 1, 2011. The adoption of this update did not have a significant impact on the Company’s results of operations, financial position or cash flows.

See Note 2—Significant Accounting Policies in the notes to the audited consolidated financial statements for a discussion of new accounting standards recently adopted or pending adoption.

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ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

We are exposed to market risk associated with changes in commodity prices, equity prices and interest rates. We are exposed to risks from changes in interest rates as a result of our issuance of variable and fixed rate debt and commercial paper. We manage our interest rate exposure by limiting our variable rate exposure and by monitoring the effects of market changes in interest rates. We also have the ability to enter into financial derivative instruments, which could include instruments such as, but not limited to, interest rate swaps, swaptions and U.S. Treasury lock agreements to manage and mitigate interest rate risk exposure. As of December 31, 2011, a hypothetical increase of interest rates by 1% associated with our short-term borrowings would result in a $4.8 million decrease in our pre-tax earnings.

In July 2010, we entered into an interest rate swap agreement with a notional amount of $100.0 million. This agreement effectively converted the interest on $100.0 million of outstanding 6.085% fixed rate debt maturing 2017 to a variable rate of six-month LIBOR plus 3.422%. We entered into this interest rate swap to mitigate interest cost at the parent company relating to debt that was incurred by our prior owners and was not used in any manner to finance the cash needs of our subsidiaries. For the year ended December 31, 2011 and 2010, the interest rate swap reduced interest expense by $2.4 million and $0.4 million, respectively. As the swap interest rates are fixed through April 2012, a hypothetical 1% increase in the interest rates associated with the interest swap agreement would result in a $0.3 million decrease on our pre-tax earnings for the year ended December 31, 2012. This calculation holds all other variables constant and assumes only the discussed changes in interest rates.

Our risks associated with price increases for chemicals, electricity and other commodities are reduced through contractual arrangements and the ability to recover price increases through rates. Non-performance by these commodity suppliers could have a material adverse impact on our results of operations, financial position and cash flows.

The market price of our common stock may experience fluctuations, many of which are unrelated to our operating performance. In particular, our stock price may be affected by general market movements as well as developments specifically related to the water and wastewater industry. These could include, among other things, interest rate movements, quarterly variations or changes in financial estimates by securities analysts and governmental or regulatory actions. This volatility may make it difficult for us to access the capital markets in the future through additional offerings of our common stock, regardless of our financial performance, and such difficulty may preclude us from being able to take advantage of certain business opportunities or meet business obligations.

We are exposed to credit risk through our water, wastewater and other water-related activities for both our Regulated Businesses and Market-Based Operations. Our Regulated Businesses serve residential, commercial, industrial and municipal customers while our Market-Based Operations engage in business activities with developers, government entities and other customers. Our primary credit risk is exposure to customer default on contractual obligations and the associated loss that may be incurred due to the non-payment of customer accounts receivable balances. Our credit risk is managed through established credit and collection policies which are in compliance with applicable regulatory requirements and involve monitoring of customer exposure and the use of credit risk mitigation measures such as letters of credit or prepayment arrangements. Our credit portfolio is diversified with no significant customer or industry concentrations. In addition, our Regulated Businesses are generally able to recover all prudently incurred costs including uncollectible customer accounts receivable expenses and collection costs through rates.

The Company’s retirement trust assets are exposed to the market prices of debt and equity securities. Changes to the retirement trust asset value can impact the Company’s pension and other benefits expense, funded status and future minimum funding requirements. Our risk is reduced through our ability to recover pension and other benefit costs through rates. In addition, pension and other benefits liabilities decrease as fixed income asset values decrease (fixed income yields rise) since the rate at which we discount pension and other retirement trust asset future obligations is highly correlated to fixed income yields.

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We are also exposed to a potential national economic recession or further deterioration in local economic conditions in the markets in which we operate. The credit quality of our customer accounts receivable is dependent on the economy and the ability of our customers to manage through unfavorable economic cycles and other market changes. In addition, as a result of the downturn in the economy and heightened sensitivity of the impact of additional rate increases on certain customers, there can be no assurances that regulators will grant sufficient rate authorizations. Therefore our ability to fully recover operating expense, recover our investment and provide an appropriate return on invested capital made in our Regulated Businesses may be adversely impacted.

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA

INDEX TO CONSOLIDATED FINANCIAL STATEMENTS

	Page Number
Audited Consolidated Financial Statements
Report of Independent Registered Public Accounting Firm		87
Consolidated Balance Sheets as of December 31, 2011 and 2010		88
Consolidated Statements of Operations and Comprehensive Income (Loss) for the years ended December  31, 2011, 2010 and 2009		90
Consolidated Statements of Cash Flows for the years ended December 31, 2011, 2010 and 2009		91
Consolidated Statements of Changes in Common Stockholders’ Equity for the years ended December  31, 2011, 2010 and 2009		92
Notes to Consolidated Financial Statements		93

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Report of Independent Registered Public Accounting Firm

To the Board of Directors and Shareholders of

American Water Works Company, Inc.

In our opinion, the accompanying consolidated balance sheets and the related consolidated statements of operations and comprehensive income (loss), of cash flows, and of changes in common stockholders’ equity, present fairly, in all material respects, the financial position of American Water Works Company, Inc. and Subsidiary Companies at December 31, 2011 and December 31, 2010, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 2011 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, 2011, based on criteria established in Internal Control—Integrated Framework 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 Management’s Report on Internal Control over Financial Reporting appearing under Item 9A. Our responsibility is to express opinions on these financial statements and on the Company’s internal control over financial reporting based on our audits. We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the 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

Philadelphia, Pennsylvania

February 28, 2012

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American Water Works Company, Inc. and Subsidiary Companies

Consolidated Balance Sheets

(In thousands, except per share data)

	December 31,
	2011			2010
ASSETS
Property, plant and equipment
Utility plant—at original cost, net of accumulated depreciation of $3,360,005 in 2011 and $3,134,094 in 2010	$	10,872,042		$	10,241,342
Nonutility property, net of accumulated depreciation of $164,417 in 2011 and $137,483 in 2010		149,056			140,298
Total property, plant and equipment		11,021,098			10,381,640
Current assets
Cash and cash equivalents		14,207			13,112
Restricted funds		32,438			94,066
Utility customer accounts receivable		150,720			145,747
Allowance for uncollectible accounts		(15,319	)		(17,474	)
Unbilled utility revenues		134,938			132,876
Other receivables, net		60,413			71,589
Income taxes receivable		7,672			6,473
Materials and supplies		28,598			27,743
Assets of discontinued operations		929,858			937,705
Other		54,134			45,938
Total current assets		1,397,659			1,457,775
Regulatory and other long-term assets
Regulatory assets		1,079,661			976,174
Restricted funds		25,503			26,718
Goodwill		1,195,069			1,195,585
Other		57,401			48,354
Total regulatory and other long-term assets		2,357,634			2,246,831
TOTAL ASSETS	$	14,776,391		$	14,086,246

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

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American Water Works Company, Inc. and Subsidiary Companies

Consolidated Balance Sheets—(Continued)

(In thousands, except per share data)

	December 31,
	2011			2010
CAPITALIZATION AND LIABILITIES
Capitalization
Common stock ($.01 par value, 500,000 shares authorized, 175,664 shares outstanding in 2011 and 174,996 in 2010)	$	1,757		$	1,750
Paid-in capital		6,180,558			6,156,675
Accumulated deficit		(1,848,801	)		(1,959,235	)
Accumulated other comprehensive loss		(97,677	)		(71,446	)
Treasury stock		0			(19	)
Common stockholders’ equity		4,235,837			4,127,725
Preferred stock without mandatory redemption requirements		4,547			4,547
Total stockholders’ equity		4,240,384			4,132,272
Long-term debt
Long-term debt		5,339,947			5,394,135
Redeemable preferred stock at redemption value		21,137			22,135
Total capitalization		9,601,468			9,548,542
Current liabilities
Short-term debt		515,050			228,905
Current portion of long-term debt		28,858			36,092
Accounts payable		243,709			188,343
Taxes accrued		36,606			36,939
Interest accrued		59,067			60,465
Liabilities of discontinued operations		382,218			373,960
Other		223,597			182,060
Total current liabilities		1,489,105			1,106,764
Regulatory and other long-term liabilities
Advances for construction		386,970			397,164
Deferred income taxes		1,288,797			1,110,250
Deferred investment tax credits		29,427			30,969
Regulatory liabilities		325,829			296,121
Accrued pension expense		411,998			413,513
Accrued postretirement benefit expense		237,086			215,217
Other		38,963			42,150
Total regulatory and other long-term liabilities		2,719,070			2,505,384
Contributions in aid of construction		966,748			925,556
Commitments and contingencies (See Note 16)		—			—
TOTAL CAPITALIZATION AND LIABILITIES	$	14,776,391		$	14,086,246

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

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American Water Works Company, Inc. and Subsidiary Companies

Consolidated Statements of Operations and Comprehensive Income (Loss)

(In thousands, except per share data)

	Years Ended December 31,
	2011			2010			2009
Operating revenues	$	2,666,236		$	2,555,035		$	2,290,446
Operating expenses
Operation and maintenance		1,301,794			1,290,941			1,182,376
Depreciation and amortization		351,821			330,264			309,874
General taxes		210,478			205,597			186,620
(Gain) loss on asset dispositions and purchases		(993	)		111			(295	)
Impairment charge		0			0			428,036
Total operating expenses, net		1,863,100			1,826,913			2,106,611
Operating income		803,136			728,122			183,835
Other income (expenses)
Interest, net		(312,415	)		(313,765	)		(296,623	)
Allowance for other funds used during construction		13,131			9,644			8,342
Allowance for borrowed funds used during construction		5,923			5,225			5,529
Amortization of debt expense		(5,055	)		(4,516	)		(6,609	)
Other, net		(1,040	)		4,714			(680	)
Total other income (expenses)		(299,456	)		(298,698	)		(290,041	)
Income (loss) from continuing operations before income taxes		503,680			429,424			(106,206	)
Provision for income taxes		198,751			174,352			113,792
Income (loss) from continuing operations		304,929			255,072			(219,998	)
Income (loss) from discontinued operations, net of tax		4,684			12,755			(13,085	)
Net income (loss)	$	309,613		$	267,827		$	(233,083	)
Other comprehensive income, net of tax:
Change in employee benefit plan funded status, net of tax of $(19,498), $(7,567) and $6,381, respectively		(30,497	)		(11,836	)		9,981
Pension plan amortized to periodic benefit cost:
Prior service cost, net of tax of $112, $50 and $29, respectively		175			79			46
Actuarial loss, net of tax of $2,879, $2,793 and $3,832, respectively		4,504			4,368			5,994
Foreign currency translation adjustment		(413	)		620			1,553
Other comprehensive income		(26,231	)		(6,769	)		17,574
Comprehensive income (loss)	$	283,382		$	261,058		$	(215,509	)
Basic earnings per common share: (a)
Income (loss) from continuing operations	$	1.74		$	1.46		$	(1.31	)
Income (loss) from discontinued operations, net of tax	$	0.03		$	0.07		$	(0.08	)
Net income (loss)	$	1.76		$	1.53		$	(1.39	)
Diluted earnings per common share: (a)
Income (loss) from continuing operations	$	1.73		$	1.46		$	(1.31	)
Income (loss) from discontinued operations, net of tax	$	0.03		$	0.07		$	(0.08	)
Net income (loss)	$	1.75		$	1.53		$	(1.39	)
Average common shares outstanding during the period:
Basic		175,484			174,833			168,164
Diluted		176,531			175,124			168,164
Dividends per common share	$	1.13		$	0.86		$	0.82

(a) Amounts may not sum due to rounding.

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

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American Water Works Company, Inc. and Subsidiary Companies

Consolidated Statements of Cash Flows

(In thousands, except per share data)

	Years Ended December 31,
	2011			2010			2009
CASH FLOWS FROM OPERATING ACTIVITIES
Net income (loss)	$	309,613		$	267,827		$	(233,083	)
Adjustments
Depreciation and amortization		351,821			330,264			309,874
Impairment charge		0			0			428,036
Provision for deferred income taxes		195,494			152,760			134,232
Amortization of deferred investment tax credits		(1,542	)		(1,561	)		(1,413	)
Provision for losses on utility accounts receivable		16,178			17,973			20,999
Allowance for other funds used during construction		(13,131	)		(9,644	)		(8,342	)
(Gain) loss on asset dispositions and purchases		(993	)		111			(295	)
Pension and non-pension post retirement benefits		71,439			89,342			105,133
Stock-based compensation expense		10,008			10,334			7,602
Other, net		44,521			9,033			21,000
Changes in assets and liabilities
Receivables and unbilled utility revenues		(17,433	)		(33,044	)		(18,751	)
Taxes receivable, including income taxes		(1,199	)		17,920			(17,920	)
Other current assets		(14,917	)		5,149			(6,737	)
Pension and non-pension post retirement benefit contributions		(186,730	)		(137,257	)		(127,446	)
Accounts payable		37,824			6,487			52
Taxes accrued, including income taxes		4,274			39,577			(13,321	)
Interest accrued		(1,417	)		746			6,499
Other current liabilities		4,547			8,916			(9,963	)
Net cash provided by operating activities		808,357			774,933			596,156
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures		(924,858	)		(765,636	)		(785,265	)
Acquisitions		(7,220	)		(1,642	)		(18,144	)
Proceeds from sale of assets and securities		9,972			239			1,237
Removal costs from property, plant and equipment retirements, net		(53,134	)		(43,695	)		(29,900	)
Net funds released		62,843			63,991			129,711
Other		0			0			(1,250	)
Net cash used in investing activities		(912,397	)		(746,743	)		(703,611	)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from long-term debt		12,510			268,559			542,926
Repayment of long-term debt		(70,045	)		(272,700	)		(178,131	)
Proceeds from issuance of common stock (net of 2009 expenses of $7,824)		0			0			242,301
Net borrowings (repayments) under short-term debt agreements		303,024			93,029			(352,005	)
Proceeds from issuances of employee stock plans and DRIP		13,866			6,711			2,089
Advances and contributions for construction, net of refunds of $21,061 in 2011, $35,830 in 2010 and $27,481 in 2009		22,298			7,042			21,211
Change in cash overdraft position		(16,862	)		17,173			(7,508	)
Debt issuance costs		(552	)		(6,619	)		(13,165	)
Redemption of preferred stocks		(1,888	)		(228	)		(218	)
Dividends paid		(157,855	)		(150,301	)		(137,331	)
Other		639			0			0
Net cash provided by (used in) financing activities		105,135			(37,334	)		120,169
Net increase (decrease) in cash and cash equivalents		1,095			(9,144	)		12,714
Cash and cash equivalents at beginning of period		13,112			22,256			9,542
Cash and cash equivalents at end of period	$	14,207		$	13,112		$	22,256
Cash paid during the year for:
Interest, net of capitalized amount	$	331,944		$	329,417		$	303,958
Income taxes, net of refunds of $812 in 2011, $37,790 in 2010 and $2,754 in 2009	$	14,269		$	(30,108	)	$	11,205
Non-cash investing activity
Capital expenditures acquired on account but unpaid as of year end	$	104,816		$	112,313		$	59,219
Non-cash financing activity
Advances and contributions	$	23,504		$	27,566		$	77,094
Long-term debt	$	0		$	122,775		$	179,931

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

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American Water Works Company, Inc. and Subsidiary Companies

Consolidated Statements of Changes in Stockholders’ Equity

(In thousands, except per share data)

					Paid-in Capital		Accumulated Deficit			Accumulated Other Comprehensive Loss									Preferred Stock of Subsidiary Companies Without Mandatory Redemption Requirements			Total Stockholders’ Equity
	Common Stock												Treasury Stock
	Shares		Par Value
													Shares			At Cost
Balance at December 31, 2008		160,000	$	1,600	$	5,888,253	$	(1,705,594	)	$	(82,251	)		0		$	(7	)	$	4,557		$	4,106,558
Net loss		—		—		—		(233,083	)		—			—			—			—			(233,083	)
Common stock offering, net of expenses of $7,824		14,500		145		242,156		—			—			—			—			—			242,301
Employee stock purchase plan		128		1		2,453		—			—			1			23			—			2,477
Stock-based compensation activity		2		—		7,215		(279	)		—			(1	)		(16	)		—			6,920
Other comprehensive income, net of tax of $10,242		—		—		—		—			17,574			—			—			—			17,574
Dividends		—		—		—		(137,331	)		—			—			—			—			(137,331	)
Balance at December 31, 2009		174,630	$	1,746	$	6,140,077	$	(2,076,287	)	$	(64,677	)		0		$	0		$	4,557		$	4,005,416
Net income		—		—		—		267,827			—			—			—			—			267,827
Direct stock reinvestment and purchase plan, net of expense of $96		63		1		1,328		—			—			—			—			—			1,329
Employee stock purchase plan		112		1		2,502		—			—			7			127			—			2,630
Stock-based compensation activity		191		2		12,768		(474	)		—			(8	)		(146	)		—			12,150
Subsidiary preferred stock redemption		—		—		—		—			—			—			—			(10	)		(10	)
Other comprehensive loss, net of tax of ($4,724)		—		—		—		—			(6,769	)		—			—			—			(6,769	)
Dividends		—		—		—		(150,301	)		—			—			—			—			(150,301	)
Balance at December 31, 2010		174,996	$	1,750	$	6,156,675	$	(1,959,235	)	$	(71,446	)		(1	)	$	(19	)	$	4,547		$	4,132,272
Net income		—		—		—		309,613			—			—			—			—			309,613
Direct stock reinvestment and purchase plan, net of expense of $19		64		1		1,807		—			—			—			—			—			1,808
Employee stock purchase plan		121		1		3,533		—			—			—			—			—			3,534
Stock-based compensation activity		483		5		18,543		(921	)		—			1			19			—			17,646
Other comprehensive income (loss), net of tax of $(16,507)		—		—		—		—			(26,231	)		—			—			—			(26,231	)
Dividends		—		—		—		(198,258	)		—			—			—			—			(198,258	)
Balance at December 31, 2011		175,664	$	1,757	$	6,180,558	$	(1,848,801	)	$	(97,677	)		0		$	0		$	4,547		$	4,240,384

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

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American Water Works Company, Inc. and Subsidiary Companies

Notes to Consolidated Financial Statements

(In thousands, except per share data)

Note 1: Organization and Operation

American Water Works Company, Inc. (“AWW”) and its subsidiaries (collectively referred to herein as the “Company”) is the holding company for regulated and market-based subsidiaries throughout the United States of America and two Canadian provinces. The regulated subsidiaries included in continuing operations provide water and wastewater services as public utilities. These regulated subsidiaries are operationally segregated into 16 U.S. states in which the Company operates regulated utilities. The market-based subsidiaries include various lines of business including Homeowner Services, which provides water and sewer line protection plans for homeowners, and the Contract Operations group, which conducts operation and maintenance of water and wastewater facilities for the U.S. Military, municipalities and the food and beverage industry.

Note 2: Significant Accounting Policies

Principles of Consolidation

The accompanying consolidated financial statements include the accounts of AWW and its subsidiaries. Intercompany balances and transactions between subsidiaries have been eliminated. The Company uses the equity method to report its investments in two joint venture investments in each of which the Company holds a 50% voting interest and cannot exercise control over the operations and policies of the investments. Under the equity method, the Company records its interests as an investment and its percentage share of earnings as earnings or losses of investee.

Use of Estimates

The preparation of consolidated financial statements in conformity with accounting principles generally accepted in the United States requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosures of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from these estimates. The Company considers benefit plan assumptions; the carrying values of goodwill and other long-lived assets, including regulatory assets; revenue recognition; and accounting for income taxes to be its critical accounting estimates. The Company’s significant estimates that are particularly sensitive to change in the near term are amounts reported for pension and other postemployment benefits, contingency-related obligations and goodwill.

Regulation

The Company’s regulated utilities are subject to economic regulation by the public utility commissions and the local governments of the states in which they operate (the “Regulators”). These Regulators have allowed recovery of costs and credits which the Company has recorded as regulatory assets and liabilities. Accounting for future recovery of costs and credits as regulatory assets and liabilities is in accordance with authoritative guidance applicable to those companies whose rates are established by or are subject to approval by an independent third-party regulator. Regulated utilities defer costs and credits on the balance sheet as regulatory assets and liabilities when it is probable that those costs and credits will be recognized in the rate making process in a period different from the period in which they would have been reflected in operations by a market-based company. These deferred regulatory assets and liabilities are then reflected in the statement of operations in the period in which the costs and credits are reflected in the rates charged for service. (See Note 7)

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Property, Plant and Equipment

Property, plant and equipment consist primarily of utility plant. Additions to utility plant and replacements of retirement units of property are capitalized. Costs include material, direct labor and such indirect items as engineering and supervision, payroll taxes and benefits, transportation and an allowance for funds used during construction. The costs incurred to acquire and internally develop computer software for internal use are capitalized as a unit of property. The carrying value of these costs amounted to $49,241 and $60,408 at December 31, 2011 and 2010, respectively. The cost of repairs; maintenance, including planned major maintenance activities; and minor replacements of property is charged to maintenance expense as incurred.

When units of property are replaced, retired or abandoned, the recorded value thereof is credited to the asset account and charged to accumulated depreciation. To the extent the Company recovers cost of removal or other retirement costs through rates after the retirement costs are incurred, a regulatory asset is recorded. In some cases, the Company recovers retirement costs through rates during the life of the associated asset and before the costs are incurred. These amounts result in a regulatory liability being reported based on the amounts previously recovered through customer rates, until the costs to retire those assets are incurred.

The cost of property, plant and equipment is depreciated using the straight-line average remaining life method.

Nonutility property consists primarily of buildings and equipment utilized by the Company for internal operations. This property is stated at cost, net of accumulated depreciation calculated using the straight-line method over the estimated useful lives of the assets, ranging from three to 50 years.

Cash and Cash Equivalents

Substantially all cash is invested in interest-bearing accounts. All highly liquid investments with a maturity of three months or less when purchased are considered to be cash equivalents.

The Company had book overdrafts for certain of its disbursement accounts of $34,002 and $50,881 at December 31, 2011 and 2010, respectively. A book overdraft represents transactions that have not cleared the bank accounts at the end of the period. The Company transfers cash on an as-needed basis to fund these items as they clear the bank. The balance of the book overdraft is reported as short-term debt and the change in the book overdraft balance is reported as cash flows from financing activities.

Restricted Funds

Restricted funds primarily represent proceeds from financings for the construction and capital improvement of facilities and deposits for future services under operation and maintenance projects. The proceeds of these financings are held in escrow until the designated expenditures are incurred. Restricted funds expected to be released within 12 months subsequent to year end are classified as current.

Utility Customer Accounts Receivable

Regulated utility customer accounts receivable represent amounts billed to water and wastewater customers on a cycle basis. Credit is extended based on the guidelines of the applicable Regulators and collateral is generally not required.

Allowance for Uncollectible Accounts

Allowances for uncollectible accounts are maintained for estimated probable losses resulting from the Company’s inability to collect receivables from customers. Accounts that are outstanding longer than the payment terms are considered past due. A number of factors are considered in determining the allowance for uncollectible accounts, including the length of time receivables are past due and previous loss history. The Company writes off accounts when they become uncollectible. (See Note 5)

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Other Receivables, Net

Other receivables, net consists of market-based trade accounts receivable and market-based unbilled revenues, net of a reserve for doubtful accounts, and non-utility customer receivables of the regulated subsidiaries. In determining the reserve for uncollectible market-based accounts, the Company considers the length of time the trade accounts receivable are past due and the customers’ current ability to pay their obligations. Unbilled receivables are accrued when service has been provided but has not been billed to customers. (See Note 6)

Materials and Supplies

Materials and supplies are stated at the lower of cost or net realizable value. Cost is determined using the average cost method.

Goodwill

Goodwill is primarily associated with the acquisitions of AWW in 2003 and E’town Corporation in 2001 (the “Acquisitions”) and has been assigned to reporting units based on the fair values at the date of the Acquisitions. The Regulated Businesses segment is a single reporting unit. In the Market-Based Operations segment, the business is organized into seven reporting units for its market-based services. Goodwill is reviewed annually, or more frequently if changes in circumstances indicate the carrying value may not be recoverable. Annual impairment reviews are performed in the fourth quarter of the calendar year, in conjunction with the timing of the completion of the Company’s annual strategic business plan.

The Company considers the carrying value of goodwill to be one of its critical accounting estimates. The Company believes the assumptions and other considerations used to value goodwill to be appropriate. However, if experience differs from the assumptions and considerations used in its analysis, the resulting change could have a material adverse impact on the consolidated financial statements.

No impairment charge was recorded in the Company’s continuing operations for the years ended December 31, 2011 and 2010, respectively. For the year ended December 31, 2009, the Company recorded goodwill impairment charges to continuing operations of $428,036. (See Note 8)

Long-Lived Assets

Long-lived assets include land, buildings, equipment and long-term investments. Long-lived assets, other than investments and land, are depreciated over their estimated useful lives, and are reviewed for impairment whenever changes in circumstances indicate the carrying value of the asset may not be recoverable. Such circumstances would include items such as a significant decrease in the market value of a long-lived asset, a significant adverse change in the manner the asset is being used or planned to be used or in its physical condition, or a history of operating or cash flow losses associated with the use of the asset. In addition, changes in the expected useful life of these long-lived assets may also be an impairment indicator. When such events or changes occur, the Company estimates the fair value of the asset from future cash flows expected to result from the use and, if applicable, the eventual disposition of the assets and compares that to the carrying value of the asset. If the carrying value is greater than the fair value, an impairment loss is recorded.

The Company considers the carrying value of long-lived assets to be one of its critical accounting estimates. The Company believes the assumptions and other considerations used to evaluate the carrying value of long-lived assets to be appropriate. However, if actual experience differs from the assumptions and considerations used in its estimates, the resulting change could have a material adverse impact on the consolidated financial statements.

The key variables to determine value include assumptions regarding sales volume, rates, operating costs, labor and other benefit costs, capital additions, assumed discount rates and other economic factors. These

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variables require significant management judgment and include inherent uncertainties since they are forecasting future events. If such assets are considered impaired, an impairment loss is recognized equal to the amount by which the asset’s carrying value exceeds its fair value.

The long-lived assets of the regulated utility subsidiaries are grouped on a separate entity basis for impairment testing as they are integrated state-wide operations that do not have the option to curtail service and generally have uniform tariffs. A regulatory asset is charged to earnings if and when future recovery in rates of that asset is no longer probable.

The Company holds other investments including investments in privately held companies and investments in joint ventures accounted for using the equity method. The Company’s investments in privately held companies and joint ventures are classified as other long-term assets.

The fair values of long-term investments are dependent on the financial performance and solvency of the entities in which the Company invests, as well as volatility inherent in the external markets. If such assets are considered impaired, an impairment loss is recognized equal to the amount by which the asset’s carrying value exceeds its fair value.

Advances and Contributions in Aid of Construction

Regulated utility subsidiaries may receive advances and contributions from customers, home builders and real estate developers to fund construction necessary to extend service to new areas. Advances for construction are refundable for limited periods of time as new customers begin to receive service or other contractual obligations are fulfilled. Included in other current liabilities at December 31, 2011 and 2010 in the accompanying Consolidated Balance Sheets are estimated refunds of $18,681 and $22,451, respectively. Those amounts represent expected refunds during the next 12-month period. Advances that are no longer refundable are reclassified to contributions in aid of construction. Contributions in aid of construction are permanent collections of plant assets or cash for a particular construction project. For ratemaking purposes, the amount of such contributions generally serves as a rate base reduction since the contributions represent non-investor supplied funds.

Generally, the Company depreciates utility plant funded by contributions and amortizes its contributions balance as a reduction to depreciation expense, producing a result which is functionally equivalent to reducing the original cost of the utility plant for the contributions. Certain of the Company’s subsidiaries do not depreciate contributed property, based on regulatory guidelines. Amortization of contributions in aid of construction was $18,327, $17,423 and $16,371 for the years ended December 31, 2011, 2010 and 2009, respectively.

Recognition of Revenues

Revenues of the regulated utility subsidiaries are recognized as water and wastewater services are provided and include amounts billed to customers on a cycle basis and unbilled amounts based on estimated usage from the date of the latest meter reading to the end of the accounting period.

The Company has agreements with the United States Government to operate and maintain water and wastewater systems at various military bases pursuant to 50-year contracts (“military agreements”). These contracts also include construction components that are accounted for separately from the operations and management components. The military agreements are subject to periodic price redetermination adjustments and modifications for changes in circumstance. Additionally, the Company has agreements ranging in length from two to 40 years with various industries and municipalities to operate and maintain water and wastewater systems (“O&M agreements”). Revenue from operations and management services are recognized as services are provided. (See Note 16)

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Construction Contracts

Revenues from construction projects are recognized over the contract term based on the estimated percentage of completion during the period compared to the total estimated services to be provided over the entire contract. Losses on contracts are recognized during the period in which the loss first becomes probable and estimable. Revenues recognized during the period in excess of billings on construction contracts are recorded as unbilled revenue. Billings in excess of revenues recognized on construction contracts are recorded as other current liabilities until the recognition criteria are met. Changes in contract performance and related estimated contract profitability may result in revisions to costs and revenues and are recognized in the period in which revisions are determined.

Income Taxes

AWW and its subsidiaries participate in a consolidated federal income tax return for U.S. tax purposes. Members of the consolidated group are charged with the amount of federal income tax expense determined as if they filed separate returns.

Certain income and expense items are accounted for in different time periods for financial reporting than for income tax reporting purposes. The Company provides deferred income taxes on the difference between the tax basis of assets and liabilities and the amounts at which they are carried in the financial statements. These deferred income taxes are based on the enacted tax rates expected to be in effect when these temporary differences are projected to reverse. In addition, the regulated utility subsidiaries recognize regulatory assets and liabilities for the effect on revenues expected to be realized as the tax effects of temporary differences, previously flowed through to customers, reverse.

Investment tax credits have been deferred by the regulated utility subsidiaries and are being amortized to income over the average estimated service lives of the related assets.

The Company recognizes accrued interest and penalties related to tax positions as a component of income tax expense and accounts for sales tax collected from customers and remitted to taxing authorities on a net basis.

Allowance for Funds Used During Construction (“AFUDC”)

AFUDC is a non-cash credit to income with a corresponding charge to utility plant that represents the cost of borrowed funds or a return on equity funds devoted to plant under construction. The regulated utility subsidiaries record AFUDC to the extent permitted by the Regulators.

Environmental Costs

The Company’s water and wastewater operations are subject to federal, state, local and foreign requirements relating to environmental protection, and as such, the Company periodically becomes subject to environmental claims in the normal course of business. Environmental expenditures that relate to current operations or provide a future benefit are expensed or capitalized as appropriate. Remediation costs that relate to an existing condition caused by past operations are accrued, on an undiscounted basis, when it is probable that these costs will be incurred and can be reasonably estimated. Remediation costs accrued amounted to $5,500 and $6,630 at December 31, 2011 and 2010, respectively. At December 31, 2011, the entire accrual relates to a conservation agreement entered into by a subsidiary of the Company with the National Oceanic and Atmospheric Administration (“NOAA”) requiring the Company to, among other provisions, implement certain measures to protect the steelhead trout and its habitat in the Carmel River watershed in the state of California. The Company paid and expensed $3,500 related to this agreement during 2009, and has agreed to pay $1,100 annually from 2010 to 2016. The Company pursues recovery of incurred costs through all appropriate means, including regulatory recovery through customer rates. The Company’s regulatory assets at December 31, 2011 and 2010 include $9,187 and $10,642, respectively, related to the NOAA agreement, including an additional $3,500 granted in 2010 for recovery of the 2009 payment.

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Derivative Financial Instruments

The Company uses derivative financial instruments for purposes of hedging exposures to fluctuations in interest rates. These derivative contracts are entered into for periods consistent with the related underlying exposures and do not constitute positions independent of those exposures. The Company does not enter into derivative contracts for speculative purposes and does not use leveraged instruments.

All derivatives are recognized on the balance sheet at fair value. On the date the derivative contract is entered into, the Company may designate the derivative as a hedge of the fair value of a recognized asset or liability (fair-value hedge) or a hedge of a forecasted transaction or of the variability of cash flows to be received or paid related to a recognized asset or liability (cash-flow hedge).

Changes in the fair value of a fair-value hedge, along with the gain or loss on the underlying hedged item, are recorded in current-period earnings. The effective portion of gains and losses on cash-flow hedges are recorded in other comprehensive income (loss), until earnings are affected by the variability of cash flows. Any ineffective portion of designated hedges is recognized in current-period earnings.

Cash flows from derivative contracts are included in net cash provided by operating activities.

New Accounting Standards

The following recently announced accounting standards have been adopted by the Company and have been included in the consolidated results of operations, financial position or footnotes of the accompanying Consolidated Financial Statements:

Revenue Arrangements with Multiple Deliverables

In October 2009, the Financial Accounting Standards Board (“FASB”) issued authoritative guidance that amends existing guidance for identifying separate deliverables in a revenue-generating transaction where multiple deliverables exist, and provides guidance for allocating and recognizing revenue based on those separate deliverables. The guidance is expected to result in more multiple-deliverable arrangements being separable than under current guidance. This guidance is effective for the Company beginning on January 1, 2011 and is required to be applied prospectively to new or significantly modified revenue arrangements. The adoption of this guidance did not have a significant impact on the Company’s results of operations, financial position or cash flows.

Business Combinations

In December 2010, the FASB clarified the requirements for reporting of pro forma revenue and earnings disclosures for business combinations. The accounting update specifies that if a public entity presents comparative financial statements, the entity should disclose revenue and earnings of the combined entity as though the business combination(s) that occurred during the current year had occurred as of the beginning of the comparable prior annual reporting period only. The amendments also expand the supplemental pro forma disclosures to include a description of the nature and amount of material, nonrecurring pro forma adjustments directly attributable to the business combination included in the reported pro forma revenue and earnings. The amendments are effective for the Company for business combinations finalized after January 1, 2011. As this guidance clarifies and provides for additional disclosure requirements only, the adoption of this guidance has not had an impact on the Company’s results of operations, financial position or cash flows.

Intangibles—Goodwill

In December 2010, the FASB issued authoritative guidance that modifies step 1 of the goodwill impairment test for reporting units with zero or negative carrying amounts. The update requires that for those reporting units, an entity is required to perform step 2 of the goodwill impairment test if it is more likely than not that a goodwill

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impairment exists. In determining whether it is more likely than not that a goodwill impairment exists, an entity should consider whether there are any adverse qualitative factors indicating that impairment may exist. Existing authoritative guidance requires that goodwill of a reporting unit be tested for impairment between annual tests if an event occurs or circumstances change that would more likely than not reduce the fair value of a reporting unit below its carrying amount. This guidance is effective for the Company beginning on January 1, 2011. The adoption of this update did not have a significant impact on the Company’s results of operations, financial position or cash flows.

The following recently issued accounting standards are not yet required to be adopted by the Company or included in the consolidated results of operations or financial position of the Company:

Fair Value Measurements

In May 2011, the FASB issued updated accounting guidance related to fair value measurements and disclosures that result in common fair value measurements and disclosures between U.S. GAAP and International Financial Reporting Standards. This new guidance amends current fair value measurement and disclosure guidance to increase transparency around valuation inputs and investment categorization. This guidance is effective for interim and annual periods beginning after December 15, 2011. The new guidance is to be adopted prospectively and early adoption is not permitted. The Company does not expect the adoption of this guidance to have a significant impact on the Company’s results of operations, financial position or cash flows.

Comprehensive Income

In June 2011, the FASB issued guidance on the presentation of comprehensive income. The new guidance allows an entity to present components of net income and other comprehensive income in one continuous statement or in two separate, but consecutive statements. The new guidance eliminates the current option to report other comprehensive income and its components in the statement of changes in equity. While the new guidance changes the presentation of comprehensive income, there are no changes to the components that are recognized in net income or other comprehensive income under current accounting guidance. In December 2011, the FASB deferred the requirement to present reclassification adjustments of other comprehensive income on the face of the income statement. The new guidance is effective for fiscal years and interim periods beginning after December 15, 2011. As the Company already presents the components of net income and other comprehensive income in one continuous statement, the adoption of the new guidance will not have an impact on its results of operations, financial position or cash flows.

Testing Goodwill for Impairment

In September 2011, the FASB updated the accounting guidance related to testing goodwill for impairment. This update permits an entity to first assess qualitative factors to determine whether it is necessary to perform the two-step quantitative goodwill impairment test that is currently in place. Under the new guidance, an entity will not be required to calculate the fair value of a reporting unit unless the entity determines, based on the qualitative assessment, that it is more likely than not that its fair value is less than its carrying amount. This update is effective for annual and interim goodwill impairment tests performed in fiscal years beginning after December 15, 2011; however, early adoption is permitted. The Company is evaluating the specific provisions of the updated guidance, but does not expect the adoption of this guidance to have a significant impact on the Company’s results of operations, financial position or cash flows.

Reclassifications

Certain reclassifications for discontinued operations (see Note 3) have been made to conform previously reported data to the current presentation.

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Note 3: Acquisitions and Divestitures

Acquisitions

During 2011, the Company closed on nine acquisitions of regulated water and wastewater systems for an aggregate purchase price of $7,220. The purchase price for each acquisition was allocated to the net tangible and intangible assets based upon their estimated fair values at the acquisition date. Assets acquired totaled $12,919, of which $12,814 was utility plant. Liabilities assumed totaled $4,945, including contributions in aid of construction of $3,847. The Company recorded gains on acquisitions during 2011 totaling $754.

In July of 2011, the Company entered into an agreement to purchase seven regulated water systems in New York for approximately $71,000, adding approximately fifty thousand customers to its regulated operations. This transaction is subject to customary closing conditions including regulatory approval in New York and is expected to close in the first half of 2012.

During 2010, the Company closed on six acquisitions of regulated water and wastewater systems for an aggregate purchase price of $1,642. The purchase price for each acquisition was allocated to the net tangible and intangible assets based upon their estimated fair values at the acquisition date. Assets acquired consisted of plant and equipment of $3,064. Liabilities assumed totaled $1,422, including contributions in aid of construction of $1,109 and regulatory liabilities of $313.

During 2009, the Company closed on seven acquisitions (six regulated water and wastewater systems, and one in its Market-Based Operations segment) for an aggregate purchase price of $18,144. The purchase price for each acquisition was allocated to the net tangible and intangible assets based upon their estimated fair values at the acquisition date. Assets acquired totaled $29,462, including plant and equipment of $17,843, current assets of $5,857, goodwill of $606, and long-lived assets of $5,156. Liabilities assumed totaled $11,318, including debt of $3,990, current liabilities of $5,732, long-term liabilities of $970, and contributions in aid of construction of $626.

Divestitures

As part of the Company’s strategic review of its business investments, it has entered into agreements to sell assets or stock of certain subsidiaries.

In June 2011, the Company completed the sale of the assets of its Texas regulated subsidiary for proceeds of $6,245. A gain on the sale of the assets has been recognized for $142 ($87 after tax). In the first quarter of 2011, the Company recognized a pretax impairment charge of $561 for the goodwill associated with the Texas subsidiary.

In January of 2012, the Company received approximately $461,000 in proceeds as a result of completing the sale of its Arizona and New Mexico subsidiaries. The sale is subject to certain post-closing adjustments. In the first quarter of 2011, the Company evaluated the pending sale and recorded an impairment charge totaling $21,428 pretax and $21,099 after tax to reduce parent company goodwill associated with these subsidiaries to their net realizable value.

The Company has also entered into an agreement to sell the stock of its Ohio subsidiary. The sale price is currently estimated at approximately $89,000, plus assumed liabilities, for an estimated enterprise value of approximately $120,000. The sale is subject to certain closing adjustments. In February 2012, the Ohio public utility commission approved the sale. Closing of this sale is expected during the first half of 2012. In the second quarter of 2011, the Company updated its evaluation of the pending sale and recorded an impairment charge totaling $3,510 pretax and $3,456 after tax to reduce parent company goodwill associated with this subsidiary to its net realizable value.

In December 2011, the Company completed the sale of its Applied Water Management subsidiary, part of its Market-Based Operations segment. Proceeds from the sale totaled $2,923. The Company recorded a pre- and post-tax loss on sale of $3,126 and $2,032, respectively.

The Company plans to use the majority of the proceeds from the above sales to reduce debt financing.

Charges recorded in connection with the discontinued operations and disposals of businesses include estimates that are subject to subsequent adjustments.

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Operating results and the financial position of the five subsidiaries named above are included in the accompanying financial statements as discontinued operations.

A summary of discontinued operations presented in the Consolidated Statements of Operations and Comprehensive Income follows:

	Years Ended December 31,
	2011			2010		2009
Operating revenues	$	173,447		$	155,642	$	150,257
Total operating expenses, net		147,012			135,673		160,483
Operating income (loss)		26,435			19,969		(10,226	)
Other income (expense), net		(270	)		43		4,767
Income (loss) from discontinued operations before income taxes		26,165			20,012		(5,459	)
Provision for income taxes		21,481			7,257		7,626
Income (loss) from discontinued operations, net of tax	$	4,684		$	12,755	$	(13,085	)

Operating expenses were lower in 2011 due to the cessation of depreciation for assets held for sale totaling $24,807 for the year ended December 31, 2011. Operating expenses in 2009 include an allocated impairment charge of $21,964.

Assets and liabilities of discontinued operations in the accompanying Consolidated Balance Sheets include the following:

	December 31, 2011		December 31, 2010
Assets:
Total property, plant and equipment	$	833,023	$	819,977
Current assets		21,906		20,710
Regulatory assets		43,849		39,833
Goodwill		29,608		55,107
Other		1,472		2,078
Total assets of discontinued operations	$	929,858	$	937,705
Liabilities:
Long-term debt	$	11,697	$	17,272
Current portion of long-term debt		12,839		8,668
Other current liabilities		29,530		39,505
Advances for construction		205,034		214,045
Regulatory liabilities		4,617		7,622
Other		15,540		(4,058	)
Contributions in aid of construction		102,961		90,906
Total liabilities of discontinued operations	$	382,218	$	373,960

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Note 4: Utility Plant

The components of utility plant by category at December 31 are as follows:

	Range of Remaining Useful Lives		2011		2010
Water plant
Land and other non-depreciable assets			$	128,286	$	125,648
Sources of supply		20 to 127 Years		565,301		527,552
Treatment and pumping facilities		3 to 101 Years		2,665,525		2,524,241
Transmission and distribution facilities		9 to 127 Years		6,632,828		6,333,032
Services, meters and fire hydrants		6 to 96 Years		2,539,696		2,402,038
General structures and equipment		3 to 112 Years		693,880		643,973
Wastewater plant		4 to 86 Years		546,002		519,219
Construction work in progress				460,529		299,733
				14,232,047		13,375,436
Less accumulated depreciation				3,360,005		3,134,094
			$	10,872,042	$	10,241,342

Utility plant depreciation expense of continuing operations amounted to $268,987 in 2011, $250,107 in 2010 and $237,741 in 2009. The Company’s regulated utility subsidiaries record depreciation in conformity with amounts approved by state regulators after regulatory review of information the Company submits to support its estimates of the assets’ remaining useful lives.

The provision for depreciation expressed as a percentage of the aggregate average depreciable asset balances was 2.68% in 2011, and 2.62% in 2010 and 2009, respectively.

Note 5: Allowance for Uncollectible Accounts

The following table summarizes the changes in the Company’s allowances for uncollectible accounts:

	2011			2010			2009
Balance at January 1	$	(17,474	)	$	(18,148	)	$	(16,859	)
Amounts charged to expense		(16,178	)		(17,973	)		(20,999	)
Amounts written off		21,855			22,124			23,104
Recoveries of amounts written off		(3,522	)		(3,477	)		(3,394	)
Balance at December 31	$	(15,319	)	$	(17,474	)	$	(18,148	)

Note 6: Other Receivables, Net

Components of the Company’s other receivables, net at December 31 are as follows:

	2011			2010
Market-based trade accounts receivable	$	26,734		$	36,357
Allowance for doubtful accounts—market-based trade accounts receivable		(3,067	)		(3,015	)
Market-based unbilled revenue		14,367			14,273
Other		22,379			23,974
	$	60,413		$	71,589

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The following table summarizes the changes in the Company’s market-based allowances for uncollectible accounts:

	2011			2010			2009
Balance at January 1	$	(3,015	)	$	(3,520	)	$	(4,622	)
Amounts charged to (expense) income		(3,583	)		(223	)		796
Amounts written off		2,886			748			476
Recoveries of amounts written off		645			(20	)		(170	)
Balance at December 31	$	(3,067	)	$	(3,015	)	$	(3,520	)

Note 7: Regulatory Assets and Liabilities

The regulatory assets represent costs that are expected to be fully recovered from customers in future rates. Except for income taxes, regulatory assets are excluded from the Company’s rate base and generally do not earn a return. The components of regulatory assets at December 31 are as follows:

	2011		2010
Income taxes recoverable through rates	$	252,570	$	247,104
Debt and preferred stock expense		73,096		76,278
Deferred pension expense		256,858		207,633
Deferred other postretirement benefit expense		149,393		126,894
Deferred security costs		4,837		7,479
Deferred business services project expense		8,776		10,670
Deferred tank painting costs		29,500		26,924
Deferred rate case expense		14,553		9,322
Purchase premium recoverable through rates		60,635		60,647
Environmental remediation recoverable through rates		9,187		10,642
Coastal water project costs		24,419		27,084
San Clemente Dam project costs		22,890		18,723
Removal costs recoverable through rates		80,402		59,317
Other		92,545		87,457
	$	1,079,661	$	976,174

The Company has recorded a regulatory asset for the additional revenues expected to be realized as the tax effects of temporary differences previously flowed through to customers reverse. These temporary differences are primarily related to the difference between book and tax depreciation on property placed in service before the adoption by the regulatory authorities of full normalization for rate making purposes. Full normalization requires no flow through of tax benefits to customers. The regulatory asset for income taxes recoverable through rates is net of the reduction expected in future revenues as deferred taxes previously provided, attributable to the difference between the state and federal income tax rates under prior law and the current statutory rates, reverse over the average remaining service lives of the related assets.

Debt expense is amortized over the lives of the respective issues. Call premiums on the redemption of long-term debt, as well as unamortized debt expense, are deferred and amortized to the extent they will be recovered through future service rates. Expenses of preferred stock issues without sinking fund provisions are amortized over 30 years from date of issue; expenses of issues with sinking fund provisions are charged to operations as shares are retired.

Pension expense in excess of the amount contributed to the pension plans is deferred by certain subsidiaries. These costs will be recovered in future service rates as contributions are made to the pension plan. The Company

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also has regulatory assets of $243,926 and $180,200 at December 31, 2011 and 2010, respectively, which is the portion of the underfunded status that is probable of recovery through rates in future periods.

Postretirement benefit expense in excess of the amount recovered in rates through 1997 has been deferred by certain subsidiaries. These costs are recognized in the rates charged for water service and will be recovered as authorized by the Company’s regulatory authorities. The Company also has regulatory assets of $147,441 and $121,665 at December 31, 2011 and 2010, respectively, which is the portion of the underfunded status that is probable of recovery through rates in future periods.

The costs of additional security measures that were implemented to protect facilities after the terrorist attacks on September 11, 2001 have been deferred by certain subsidiaries. These costs are recognized in the rates charged for water service by certain subsidiaries. These costs are being recovered over periods ranging from five to ten years from the time of regulatory approval.

Business services project expenses consist of reengineering and start-up activities for consolidated customer and shared administrative service centers that began operations in 2001. These costs are recognized in the rates charged for water service by certain subsidiaries.

Tank painting costs are generally deferred and amortized to current operations on a straight-line basis over periods ranging from two to 15 years, as authorized by the regulatory authorities in their determination of rates charged for service.

The Company amortizes rate case expenditures over regulatory approved amortization periods, typically three years. Rate case proceeding expenditures probable of future recovery are deferred.

Purchase premium recoverable through rates is primarily the recovery of the acquisition premiums related to an asset acquisition by the Company’s California subsidiary during 2002, and acquisitions in 2007 by the Company’s New Jersey subsidiary. As authorized for recovery by the California and New Jersey Regulators, these costs are being amortized to operations through November 2048.

Environmental remediation recoverable through rates is the recovery of costs incurred by the Company’s California subsidiary under a settlement agreement entered into with NOAA to improve habitat conditions in the Carmel River Watershed.

Coastal water project costs include preliminary costs associated with the studying, testing and design of alternatives to help solve water supply shortages in Monterey, California. Coastal water project costs incurred through December 31, 2009 have been reviewed and approved for recovery through a surcharge. Costs deferred during 2011 and 2010 totaled $2,528 and $7,677, respectively. The Company believes it is probable that the costs incurred since the last rate review will also be recoverable.

San Clemente Dam project costs include deferred costs for the Company’s California subsidiary to investigate alternatives to strengthen or remove the San Clemente Dam due to potential earthquake or flood safety concerns. In November 2011, a Proposed Decision (“PD”) was issued by the Administrative Law Judge (“ALJ”) assigned to the matter. In the PD, the ALJ recommended that recovery of virtually all of the historical costs should be disallowed. The Company’s California subsidiary has filed comments with the California Public Utility Commission (“CPUC”) contending that the PD is unreasonable, unsupported by and contrary to the evidence, and contrary to law and policy. The PD is currently under review by the CPUC, which has delayed issuing a decision on several occasions and most recently has indicated that it will not vote on a decision until April 2012. The Company believes there are sound reasons for the CPUC to modify the PD to permit recovery of the historical costs. These costs are not yet in rates; however, the Company believes it is probable that the costs incurred will be recoverable.

Other regulatory assets include certain deferred employee benefit costs, deferred treatment facility costs, as well as various regulatory balancing accounts.

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The components of regulatory liabilities at December 31 are as follows:

	2011		2010
Removal costs recovered through rates	$	272,618	$	260,947
Other		53,211		35,174
	$	325,829	$	296,121

Removal costs recovered through rates are retirement costs recovered during the life of the associated assets. In December 2008, the Company’s subsidiary in New Jersey, at the direction of the New Jersey Regulator, began to amortize $48,000 of the total balance into operations via straight line amortization through November 2048.

Other regulatory liabilities include legal settlement proceeds, deferred gains, future customer refunds, and various regulatory balancing accounts. The Company’s increased pension contributions in 2011 resulted in increased pension balancing accounts.

Note 8: Goodwill

The Company’s annual impairment reviews are performed as of November 30 of each year, in conjunction with the completion of the Company’s annual strategic business plan. At November 30, 2011, the Company’s goodwill was $1,195,069. The Company also undertakes interim reviews when the Company determines that a triggering event that would more likely than not reduce the fair value of a reporting unit below its carrying value has occurred.

The Company uses a two-step impairment test to identify potential goodwill impairment and measure the amount of a goodwill impairment loss to be recognized (if any). The step 1 calculation used to identify potential impairment compares the calculated fair value for each of the Company’s reporting units to their respective net carrying values (book values), including goodwill, on the measurement date. If the fair value of any reporting unit is less than such reporting unit’s carrying value, then step 2 is performed to measure the amount of the impairment loss (if any) for such reporting unit.

The step 2 calculation of the impairment test compares, by reporting unit, the implied fair value of the goodwill to the carrying value of goodwill. The implied fair value of goodwill is equal to the excess of the fair value of each reporting unit above the fair value of such reporting unit’s identified assets and liabilities. If the carrying value of goodwill exceeds the implied fair value of goodwill for any reporting unit, an impairment loss is recognized in an amount equal to the excess (not to exceed the carrying value of goodwill) for that reporting unit.

The determination of the fair value of each reporting unit and the fair value of each reporting unit’s assets and liabilities is performed as of the measurement date using observable market data before and after the measurement date (if that subsequent information is relevant to the fair value on the measurement date).

For the November 30, 2011 impairment test, the estimated fair value of each reporting unit for step 1 was based on a combination of the following valuation techniques:

• observable trading prices of comparable equity securities considered to be the Company’s peers; and

• discounted cash flow models developed from the Company’s internal forecasts.

The first valuation technique applies average peer multiples to each reporting unit’s historic and forecasted cash flows. The peer multiples are calculated using the average trading prices of comparable equity securities, their published cash flows and forecasts of market prices and cash flows for those peers.

The second valuation technique forecasts each reporting unit’s five-year cash flows using an estimated long-term growth rate and discounts these cash flows at their respective estimated weighted average cost of capital.

The Company has completed its November 30, 2011 annual impairment review. Based on this review, the Company’s goodwill balance was not impaired. The Company’s fair value calculated in its 2011 impairment test period was greater than the aggregate carrying value of its reporting units.

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However, there can be no assurances that the Company will not be required to recognize an impairment of goodwill in the future due to market conditions or other factors related to the Company’s performance. These market events could include a decline over a period of time of the Company’s stock price, a decline over a period of time in valuation multiples of comparable water utilities, the lack of an increase in the Company’s market price consistent with its peer companies, or decreases in control premiums. A decline in the forecasted results in the Company’s business plan, such as changes in rate case results or capital investment budgets or changes in the Company’s interest rates, could also result in an impairment charge.

The Company also made certain assumptions, which it believes to be appropriate, that support the fair value of its reporting units. The Company considered, in addition to the listed trading price of the Company’s shares, the applicability of a control premium to the Company’s shares and certain other factors the Company deemed appropriate. As a result, the Company concluded that the Company’s fair value exceeds what the Company might otherwise have concluded had it relied on market price alone.

The difference between the Company’s calculated market capitalization (which approximates carrying value) and the aggregate fair value of reporting units resulted from an estimated control premium. The estimated control premium represents the incremental premium a buyer is willing to pay to acquire a controlling, majority interest in the Company. In estimating the control premium, management principally considered the current market conditions and historical premiums paid in utility acquisitions observed in the marketplace.

No impairment charge was recorded to the Company’s continuing operations for the years ended December 31, 2011 and 2010, respectively. For the year ended December 31, 2009, the Company recorded impairment charges for goodwill in the amount of $428,036.

The change in the Company’s goodwill assets, as allocated between the reporting units is as follows:

	Regulated Unit						Market-Based Units					Consolidated
	Cost			Accumulated Impairment			Cost		Accumulated Impairment			Cost			Accumulated Impairment			Total Net
Balance at January 1, 2010	$	3,399,848		$	(2,332,670	)	$	235,715	$	(107,619	)	$	3,635,563		$	(2,440,289	)	$	1,195,274
Reclassifications and other activity		36			0			275		0			311			0			311
Balance at December 31, 2010	$	3,399,884		$	(2,332,670	)	$	235,990	$	(107,619	)	$	3,635,874		$	(2,440,289	)	$	1,195,585
Reclassifications and other activity		(516	)		0			0		0			(516	)		0			(516	)
Balance at December 31, 2011	$	3,399,368		$	(2,332,670	)	$	235,990	$	(107,619	)	$	3,635,358		$	(2,440,289	)	$	1,195,069

Note 9: Stockholders’ Equity

Common Stock

In March 2010, the Company established American Water Stock Direct, a dividend reinvestment and direct stock purchase plan (the “DRIP”). Under the DRIP, stockholders may reinvest cash dividends and purchase

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additional Company common stock, up to certain limits, through a transfer agent without commission fees. The Company’s transfer agent may buy newly issued shares directly from the Company or shares held in the Company’s treasury. The transfer agent may also buy shares in the public markets or in privately negotiated transactions. Purchases generally are made and credited to DRIP accounts once each week. As of December 31, 2011, there were 4,873 shares available for future issuance under the DRIP. The following table summarizes information regarding issuances under the DRIP for the years ended December 31, 2011 and 2010:

	2011		2010
Shares of common stock issued		64		63
Cash proceeds received	$	1,827	$	1,425

Cash dividend payments made during 2011 and 2010 were as follows:

	2011		2010
Dividends per share, three months ended:
March 31	$	0.22	$	0.21
June 30		0.22		0.21
September 30		0.23		0.22
December 31		0.23		0.22
Total dividends paid, three months ended:
March 31	$	38,525	$	36,679
June 30		38,580		36,689
September 30		40,358		38,457
December 31		40,392		38,476

On December 9, 2011, the Company declared a quarterly cash dividend payment of $0.23 per share payable on March 1, 2012 to all shareholders of record as of February 3, 2012. As of December 31, 2011, the Company had accrued dividends totaling $40,403 included in Other current liabilities in the accompanying Consolidated Balance Sheets.

Accumulated Other Comprehensive Loss

The following table presents accumulated other comprehensive loss:

	2011			2010
Employee benefit plans funded status adjustments	$	(101,457	)	$	(75,639	)
Foreign currency translation		3,780			4,193
Balance at December 31	$	(97,677	)	$	(71,446	)

Stock Based Compensation

The Company has granted stock option and restricted stock unit awards to non-employee directors, officers and other key employees of the Company pursuant to the terms of its 2007 Omnibus Equity Compensation Plan (the “Plan”). The total aggregate number of shares of common stock that may be issued under the Plan is 15,500. As of December 31, 2011, a total of 10,948 shares are available for grant under the Plan. Shares issued under the Plan may be authorized but unissued shares of Company stock or reacquired shares of Company stock, including shares purchased by the Company on the open market for purposes of the Plan.

The Company recognizes compensation expense for stock awards over the vesting period of the award. The following table presents stock-based compensation expense recorded in operation and maintenance expense in

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the accompanying Consolidated Statements of Operations and Comprehensive Income (Loss) for the years ended December 31, 2011, 2010 and 2009:

	2011			2010			2009
Stock options	$	3,182		$	4,116		$	3,415
Restricted stock units		6,340			5,863			3,799
Employee stock purchase plan		486			355			388
Stock-based compensation in operation and maintenance expense		10,008			10,334			7,602
Income tax benefit		(3,903	)		(4,030	)		(2,965	)
After-tax stock-based compensation expense	$	6,105		$	6,304		$	4,637

There were no significant stock-based compensation costs capitalized during the years ended December 31, 2011, 2010 and 2009.

The cost of services received from employees in exchange for the issuance of stock options and restricted stock awards is measured based on the grant date fair value of the awards issued. The value of stock options and restricted stock unit awards at the date of the grant is amortized through expense over the three-year service period. All awards granted in 2011, 2010 and 2009 are classified as equity.

The Company receives a tax deduction based on the intrinsic value of the award at the exercise date for stock options and the distribution date for restricted stock units. For each award, throughout the requisite service period, the Company recognizes the tax benefit related to compensation costs, which have been included in deferred tax assets. The tax deductions in excess of the benefits recorded throughout the requisite service period are recorded to shareholders’ equity or the income statement and are included in the financing section of the statement of cash flows.

The Company stratified its grant populations and used historic employee turnover rates to estimate employee forfeitures. The estimated rate is compared to the actual forfeitures at the end of the period and adjusted as necessary.

Stock Options

In the first quarters of 2011, 2010 and 2009, the Company granted non-qualified stock options to certain employees under the Plan. The stock options vest ratably over the three-year service period beginning on January 1 of the year of grant. These awards have no performance vesting conditions and the grant date fair value is amortized through expense over the requisite service period using the straight-line method.

On August 15, 2010, the Company’s board of directors elected a new President and Chief Executive Officer (“CEO”) of the Company. In connection with his election to these offices, the Company’s new CEO was granted non-qualified stock options that cliff vest two years from the date of grant. Additionally, the CEO was granted non-qualified stock options that vest ratably over a three-year period beginning January 1, 2010. These awards have no performance vesting conditions.

Also on August 15, 2010, the Company’s former President and Chief Executive Officer resigned as an officer and director of the Company. Pursuant to his resignation, the Company cancelled options to purchase 33 shares of Company stock, accelerated the vesting of 247 options, extended the termination dates of vested options and recognized $315 additional expense related to the modifications that is recorded in operation and maintenance expense in the accompanying Consolidated Statements of Operations and Comprehensive Income (Loss) for the year ended December 31, 2010.

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The following table presents the weighted average assumptions used in the pricing model for grants and the resulting weighted average grant date fair value of stock options granted in the years ended December 31, 2011, 2010 and 2009:

	2011			2010			2009
Dividend yield		3.25	%		3.83	%		3.86	%
Expected volatility		29.32	%		31.77	%		31.67	%
Risk-free interest rate		1.93	%		2.14	%		1.79	%
Expected life (years)		4.35			4.29			4.36
Exercise price	$	27.08		$	22.01		$	20.70
Grant date fair value per share	$	5.14		$	4.33		$	3.96

The Company utilized the “simplified method” to determine the expected stock option life due to insufficient historical experience to estimate the exercise patterns of the stock options granted. The Company began granting stock options at the time of the IPO in April 2008. Expected volatility is based on a weighted average of historic volatilities of traded common stock of peer companies (regulated water companies) over the expected term of the stock options and historic volatilities of the Company’s common stock during the period it has been publicly traded. The dividend yield is based on the Company’s expected dividend payments and the stock price on the date of grant. The risk-free interest rate is the market yield on U.S. Treasury strips with maturities similar to the expected term of the stock options. The exercise price of the stock options is equal to the fair market value of the underlying stock on the date of option grant. Stock options granted vest over periods ranging from one to three years and expire seven years from the effective date of the grant. The fair value of each option is estimated on the date of grant using the Black-Scholes option-pricing model.

The value of stock options at the date of the grant is amortized through expense over the requisite service period using the straight-line method. As of December 31, 2011, $3,389 of total unrecognized compensation costs related to the nonvested stock options is expected to be recognized over the remaining weighted-average period of 1.6 years. The total grant date fair value of stock options vested during the years ended December 31, 2011, 2010 and 2009 was $4,578, $4,505 and $92, respectively.

The table below summarizes stock option activity for the year ended December 31, 2011:

	Shares			Weighted Average Exercise Price (per share)		Weighted Average Remaining Life (years)		Aggregate Intrinsic Value
Options outstanding at January 1, 2011		2,870		$	21.38
Granted		736			27.08
Forfeited or expired		(71	)		23.27
Exercised		(423	)		21.27
Options outstanding at December 31, 2011		3,112		$	22.70		4.3	$	28,493
Exercisable at December 31, 2011		1,686		$	21.34		3.5	$	17,738

The following table summarizes additional information regarding stock options exercised during the years ended December 31, 2011, 2010 and 2009:

	2011		2010			2009
Intrinsic value	$	3,026	$	333		$	0
Exercise proceeds		8,991		3,010			0
Income tax benefit (shortfall)		511		(89	)		0

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Restricted Stock Units

In the first quarters of 2011 and 2010 and August 2010, the Company granted restricted stock units to certain employees under the Plan. The restricted stock units vest ratably over the three-year performance period beginning January 1 of the year of grant (the “Performance Period”); however, distribution of the shares is contingent upon the achievement of internal performance measures and, separately, certain market thresholds over the Performance Period. In February 2009, the Company granted restricted stock units that vest ratably over the three year performance period beginning January 1, 2009 (the “2009 Performance Period”); however, distribution of the shares is contingent upon the achievement of certain market thresholds over the 2009 Performance Period.

During 2011, 2010 and 2009, the Company granted restricted stock units to certain non-employee directors under the Plan. The restricted stock units vested on the date of grant; however, distribution of the shares will be made within 30 days of the earlier of (a) 15 months after grant date or (b) the participant’s separation from service. Because these restricted stock units vested on grant date, the total grant date fair value was recorded in operation and maintenance expense included in the expense table above on the grant date.

In August 2010, the Company accelerated the vesting of 12 restricted stock units granted in 2008 to the Company’s former CEO. Additionally the Company cancelled 9 restricted stock units granted in 2009 and 2010; the remaining outstanding awards will be subject to the Company’s achievement of internal performance measures and certain market thresholds over the applicable three-year performance periods as if he had remained in the employ of the Company during the entire performance periods. The net impact associated with these modifications was a reduction to operation and maintenance expense of $12 for the year ended December 31, 2010.

Restricted stock units generally vest over periods ranging from one to three years. Restricted stock units granted without market conditions are valued at the market value of the Company’s common stock on the date of grant. Restricted stock units granted with market conditions are valued using a Monte Carlo model. Expected volatility is based on historical volatilities of traded common stock of the Company and comparative companies using daily stock prices over the past three years. The Company’s volatility was calculated using a weighted average of eight companies for the 2011 and 2010 periods and nine companies for 2009, respectively, before the Company’s stock was publicly traded. The expected term is three years and the risk-free interest rate is based on the three-year U.S. Treasury rate in effect as of the measurement date. The following table presents the weighted average assumptions used in the Monte Carlo simulation and the weighted average grant date fair values of restricted stock units granted during the years ended December 31, 2011, 2010 and 2009:

	2011			2010			2009
Expected volatility		29.50	%		30.74	%		32.00	%
Risk-free interest rate		1.24	%		1.50	%		1.30	%
Expected life (years)		3			3			3
Grant date fair value per share	$	29.95		$	23.23		$	21.75

The value of restricted stock awards at the date of the grant is amortized through expense over the requisite service period using the straight-line method for restricted stock units with service and/or performance vesting. The grant date fair value of restricted stock awards that have (a) market and/or performance and service conditions and (b) vest ratably is amortized through expense over the requisite service period using the graded-vesting method. As of December 31, 2011, $3,172 of total unrecognized compensation cost related to the nonvested restricted stock units is expected to be recognized over the weighted-average remaining life of 1.3 years. The total grant date fair value of restricted stock units vested during the years ended December 31, 2011, 2010 and 2009 was $2,040, $2,204 and $438, respectively.

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The table below summarizes restricted stock unit activity for the year ended December 31, 2011:

	Shares			Weighted Average Grant Date Fair Value (per share)
Nonvested total at January 1, 2011		479		$	22.60
Granted		205			29.95
Vested		(89	)		22.88
Forfeited		(18	)		25.28
Nonvested total at December 31, 2011		577		$	25.09

The following table summarizes additional information regarding restricted stock units distributed during the years ended December 31, 2011, 2010 and 2009:

	2011		2010		2009
Intrinsic value	$	2,068	$	1,241	$	51
Income tax benefit (shortfall)		99		15		(2	)

If dividends are declared with respect to shares of the Company’s common stock before the restricted stock units are distributed, the Company credits a liability for the value of the dividends that would have been paid if the restricted stock units were shares of Company common stock. When the restricted stock units are distributed, the Company pays the employee a lump sum cash payment equal to the value of the dividend equivalents accrued. The Company accrued dividend equivalents totaling $921, $474 and $279 to retained earnings during the years ended December 31, 2011, 2010 and 2009, respectively.

Employee Stock Purchase Plan

The Company’s Nonqualified Employee Stock Purchase Plan (“ESPP”) was effective as of July 1, 2008. Under the ESPP, employees can use payroll deductions to acquire Company stock at the lesser of 90% of the fair market value of (a) the beginning or (b) the end of each three-month purchase period. As of December 31, 2011 there were 1,592 shares of common stock reserved for issuance under the ESPP. The Company’s ESPP is considered compensatory. Compensation costs of $486, $355 and $388 were recognized for the years ended December 31, 2011, 2010 and 2009, respectively. During the years ended December 31, 2011, 2010 and 2009, the Company issued 121, 119 and 129 shares, respectively, under the ESPP.

Note 10: Preferred Stock Without Mandatory Redemption Requirements

Certain preferred stock agreements do not require annual sinking fund payments or redemption except at the option of the subsidiaries and are as follows:

Dividend Yield	Balance at December 31,
	2011		2010
4.50%	$	1,720	$	1,720
5.00%		1,952		1,952
5.50%		486		486
5.75%		389		389
	$	4,547	$	4,547

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The Company reflects its subsidiaries’ preferred stock without mandatory redemption requirements, which represents the Company’s noncontrolling interest, in the total stockholders’ equity section of the accompanying Consolidated Balance Sheets. The dividends on these preferred shares have not been reflected as income attributable to noncontrolling interest in the Consolidated Statements of Operations and Comprehensive Income (Loss) as the total amount of these dividends is not considered material. The dividends issued were $224 for 2011 and 2010, respectively, and $225 for 2009. The amounts have been included as a component of other income (expenses) in the accompanying Consolidated Statements of Operations and Comprehensive Income (Loss).

Note 11: Long-Term Debt

The Company primarily incurs long-term debt to fund capital expenditures of the regulated subsidiaries. The components of long-term at December 31 are:

	Rate	Weighted Average Rate			Maturity Date	2011		2010
Long-term debt of American Water Capital Corp. (“AWCC”)(a)
Private activity bonds and government funded debt
Fixed rate	4.85%-6.75%		5.72	%	2018-2040	$	322,610	$	322,610
Senior notes
Fixed rate	5.39%-10.00%		6.25	%	2013-2040		3,089,409		3,117,696
Long-term debt of other subsidiaries
Private activity bonds and government funded debt
Fixed rate	0.00%-6.20%		5.07	%	2012-2039		1,206,332		1,201,723
Mortgage bonds
Fixed rate	5.48%-9.71%		7.40	%	2012-2039		697,800		730,991
Mandatory redeemable preferred stock	4.60%-9.75%		8.43	%	2013-2036		22,101		22,844
Notes payable and other(b)	9.49%-13.96%		12.12	%	2013-2026		1,691		5,689
Long-term debt							5,339,943		5,401,553
Unamortized debt discount, net(c)							43,888		51,154
Fair value adjustment to interest rate hedge							6,111		(345	)
Total long-term debt						$	5,389,942	$	5,452,362

(a) AWCC, which is a wholly-owned subsidiary of the Company, has a strong support agreement with its parent that, under certain circumstances, is the functional equivalent of a guarantee.

(b) Includes capital lease obligations of $1,264 and $5,076 at December 31, 2011 and 2010, respectively.

(c) Includes fair value adjustments previously recognized in acquisition purchase accounting.

All $697,800 of the subsidiaries’ mortgage bonds and $1,150,003 of the $1,206,332 total subsidiaries’ private activity bonds and government funded debt are collateralized by utility plant.

Long-term debt indentures contain a number of covenants that, among other things, limit, subject to certain exceptions, the Company from issuing debt secured by the Company’s assets. Certain long term notes require the Company to maintain a ratio of consolidated total indebtedness to consolidated total capitalization of not more than 0.70 to 1.00. The ratio at December 31, 2011 was 0.58 to 1.00. In addition, the Company has $1,701,322 of notes which include the right to redeem the notes in whole or in part from time to time subject to certain restrictions.

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The future sinking fund payments and maturities are as follows:

Year	Amount
2012	$	28,855
2013		112,594
2014		9,416
2015		49,568
2016		47,172
Thereafter		5,092,338

The following long-term debt was issued in 2011:

Company	Type	Interest Rate	Maturity		Amount
Other subsidiaries	Private activity bonds and government funded debt—fixed rate	0.00%-1.56%		2031	$	12,510
Total issuances					$	12,510

The following long-term debt was retired through optional redemption or payment at maturity during 2011:

Company	Type	Interest Rate	Maturity		Amount
American Water Capital Corp.	Senior notes—fixed rate	6.00%-8.25%		2011-2039	$	28,287
Other subsidiaries	Private activity bonds and government funded debt—fixed rate	0.00%-5.90%		2011-2034		7,976
Other subsidiaries	Mortgage bonds—fixed rate	8.21%-9.71%		2011-2022		33,191
Other subsidiaries	Mandatory redeemable preferred stock	4.60%-9.18%		2013-2019		1,888
Other	Capital leases and other					4,078
Total retirements and redemptions					$	75,420

Included in the capital lease redemptions above is a non-cash redemption of $3,487 associated with a cancelled sublease and a capital lease arrangement.

Interest, net includes interest income of approximately $10,942, $10,320 and $10,397 in 2011, 2010 and 2009, respectively.

One of the principal market risks to which the Company is exposed is changes in interest rates. In order to manage the exposure, the Company follows risk management policies and procedures, including the use of derivative contracts such as swaps. The Company uses a combination of fixed-rate and variable-rate debt to manage interest rate exposure. The Company does not enter into derivative contracts for speculative purposes and does not use leveraged instruments. The derivative contracts entered into are for periods consistent with the related underlying exposures. The Company is exposed to the risk that counterparties to derivative contracts will fail to meet their contractual obligations. The Company minimizes the counterparty credit risk on these transactions by dealing only with leading, credit-worthy financial institutions having long-term credit ratings of “A” or better.

On July 12, 2010, the Company entered into an interest rate swap to hedge $100,000 of its 6.085% fixed-rate debt maturing 2017. The Company will pay variable interest of six-month LIBOR plus 3.422%. The swap is

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accounted for as a fair-value hedge, and matures with the fixed-rate debt in 2017. The Company uses a combination of fixed-rate and variable-rate debt to manage interest rate exposure.

At December 31, 2011 and 2010, the Company had a $100,000 notional amount variable interest rate swap fair-value hedge outstanding, respectively. The following table provides a summary of the derivative fair value balance recorded by the Company as of December 31, 2011 and 2010 and the line item in the Consolidated Balance Sheet in which such amount is recorded:

Balance sheet classification	December 31, 2011		December 31, 2010
Regulatory and other long-term assets
Other	$	5,824	$	0
Regulatory and other long-term liabilities
Other		0		898
Long-term debt
Long-term debt		6,111		(345	)

For derivative instruments that are designated and qualify as fair-value hedges, the gain or loss on the hedge instrument as well as the offsetting loss or gain on the hedged item attributable to the hedged risk are recognized in current net income (loss). The Company includes the gain or loss on the derivative instrument and the offsetting loss or gain on the hedged item in interest expense as follows:

Income Statement Classification	December 31, 2011			December 31, 2010
Interest, net
Gain (loss) on swap	$	6,722		$	(898	)
(Loss) gain on borrowing		(6,455	)		345
Hedge ineffectiveness		267			(553	)

Note 12: Short-Term Debt

The components of short-term debt at December 31 are as follows:

	2011		2010
Revolving credit lines	$	0	$	2,734
Commercial paper, net of $52 and $10 discount at 2011 and 2010, respectively		481,048		175,290
Book overdraft		34,002		50,881
Total short-term debt	$	515,050	$	228,905

AWCC had the following available capacity under its commercial paper program at December 31:

	2011		2010
Commercial paper program	$	700,000	$	700,000
Commercial paper program available capacity		218,900		524,700

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AWCC has entered into an $840,000 senior unsecured credit facility syndicated among a group of 10 banks with JPMorgan Chase Bank, N.A. acting as administrative agent.

This revolving credit facility is principally used to support the commercial paper program at AWCC and to provide up to $150,000 in letters of credit. On September 15, 2008, a majority of the banks agreed to further extend $685,000 of commitments under this revolving credit facility to September 15, 2013. On December 18, 2008, The Bank of New York Mellon joined the credit facility syndicate with a commitment amount of $40,000 through September 15, 2012. If any lender defaults in its obligation to fund advances, the Company may request the other lenders to assume the default lender’s commitment or replace such defaulting lender by designating an assignee willing to assume the commitment, however the remaining lenders have no obligation to assume a defaulting lender’s commitment and we can provide no assurances that we will replace a defaulting lender.

At December 31, AWCC had the following sub-limits and available capacity under the credit facility.

	2011		2010
Letter of credit sublimit	$	150,000	$	150,000
Letter of credit available capacity		113,548		113,203

At December 31, 2011, the Company had $36,830 of outstanding letters of credit, $36,452 of which was issued under the revolving credit facility noted above.

The following table presents the short-term borrowing activity for AWCC for the years ended December 31, 2011 and 2010:

	2011			2010
Average borrowings	$	362,615		$	164,782
Maximum borrowings outstanding		494,900			263,500
Weighted average interest rates, computed on a daily basis		0.41	%		0.42	%
Weighted average interest rates, at December 31		0.56	%		0.46	%

Interest rates on advances under the credit facility are based on either prime or the London Interbank Offering Rate (“LIBOR”) plus an applicable margin based upon credit ratings of the Company, as well as total outstanding amounts under the agreement at the time of the borrowing. The maximum LIBOR margin is 55 basis points.

The credit facility requires the Company to maintain a ratio of consolidated debt to consolidated capitalization of not more than 0.70 to 1.00. The ratio at December 31, 2011 was 0.58 to 1.00.

None of the Company’s borrowings are subject to default or prepayment as a result of a downgrading of securities, although such a downgrading could increase fees and interest charges under the Company’s credit facilities.

As part of the normal course of business, the Company routinely enters contracts for the purchase and sale of water, energy, fuels and other services. These contracts either contain express provisions or otherwise permit the Company and its counterparties to demand adequate assurance of future performance when there are reasonable grounds for doing so. In accordance with the contracts and applicable contract law, if the Company is downgraded by a credit rating agency, especially if such downgrade is to a level below investment grade, it is possible that a counterparty would attempt to rely on such a downgrade as a basis for making a demand for adequate assurance of future performance. Depending on the Company’s net position with a counterparty, the demand could be for the posting of collateral. In the absence of expressly agreed provisions that specify the collateral that must be provided, the obligation to supply the collateral requested will be a function of the facts and circumstances of the Company’s situation at the time of the demand. If the Company can reasonably claim that it is willing and financially able to perform its obligations, it may be possible to successfully argue that no collateral should be posted or that only an amount equal to two or three months of future payments should be sufficient. The Company does not expect to post any collateral which will have a material adverse impact on the Company’s results of operations, financial position or cash flows.

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AWCC had entered into a one year $10,000 committed revolving line of credit with PNC Bank, N.A. Outstanding borrowings against this line totaled $0 and $2,734 at December 31, 2011 and 2010, respectively. This line of credit was terminated without renewal on December 31, 2011.

Note 13: General Taxes

Components of general tax expense from continuing operations for the years ended December 31 are as follows:

	2011		2010		2009
Gross receipts and franchise	$	90,674	$	86,063	$	79,410
Property and capital stock		77,330		78,184		70,907
Payroll		31,705		31,089		27,834
Other general		10,769		10,261		8,469
	$	210,478	$	205,597	$	186,620

Note 14: Income Taxes

Components of income tax expense from continuing operations for the years ended December 31 are as follows:

	2011			2010			2009
State income taxes
Current	$	(7,440	)	$	24,653		$	(19,582	)
Deferred
Current		(171	)		78			(1,661	)
Non-current		44,576			11,024			38,908
		36,965			35,755			17,665
Federal income taxes
Current		12,239			(1,500	)		555
Deferred
Current		(314	)		69			(16,189	)
Non-current		151,403			141,589			113,174
Amortization of deferred investment tax credits		(1,542	)		(1,561	)		(1,413	)
		161,786			138,597			96,127
	$	198,751		$	174,352		$	113,792

A reconciliation of income tax expense from continuing operations at the statutory federal income tax rate to actual income tax expense for the years ended December 31 is as follows:

	2011			2010			2009
Income tax at statutory rate	$	176,288		$	150,298		$	(37,172	)
Increases (decreases) resulting from:
State taxes, net of federal taxes		24,027			23,241			11,482
Change in valuation allowance		(160	)		(533	)		(6,578	)
Flow through differences		2,895			2,807			2,760
Amortization of deferred investment tax credits		(1,542	)		(1,561	)		(1,413	)
Subsidiary preferred dividends		668			675			680
Impairment charges		0			0			143,321
Other, net		(3,425	)		(575	)		712
Actual income tax expense	$	198,751		$	174,352		$	113,792

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The following table provides the components of the net deferred tax liability from continuing operations at December 31:

	2011			2010
Deferred tax assets:
Advances and contributions	$	475,280		$	463,694
Deferred investment tax credits		11,202			11,789
Other postretirement benefits		101,258			92,620
Tax losses and credits		284,636			327,128
Pension benefits		132,972			141,530
Unamortized debt discount, net		23,872			22,889
Other		13,308			8,429
		1,042,528			1,068,079
Valuation allowance		(20,701	)		(22,733	)
		1,021,827			1,045,346
Deferred tax liabilities:
Utility plant, principally due to depreciation differences		1,958,044			1,846,338
Income taxes recoverable through rates		94,331			93,495
Deferred security costs		1,982			3,065
Deferred business services project expenses		4,573			4,566
Deferred other postretirement benefits		58,238			48,155
Deferred pension benefits		97,899			78,972
Other		95,557			81,005
		2,310,624			2,155,596
	$	(1,288,797	)	$	(1,110,250	)

At December 31, 2011 and 2010, the Company recorded federal net operating loss (“NOL”) carryforwards of $1,187,427 and $1,185,337, respectively. The Company believes the federal NOL carryforwards are more likely than not to be recovered and require no valuation allowance. The Company evaluated its ability to fully utilize the existing federal NOL carryforwards in light of the RWE divestiture in November 2009. Under Internal Revenue Code (“I.R.C.”) Section 382, an ownership change occurs if there is a greater than fifty percent (50%) change in equity ownership of a company over a three-year period determined by reference to the ownership of persons holding five percent (5%) or more of that company’s equity securities. If a company undergoes an ownership change as defined by I.R.C. Section 382, the company’s ability to utilize its pre-change NOL carryforwards to offset post-change income may be limited.

The Company believes that the limitation imposed by I.R.C. Section 382 generally should not preclude use of its federal NOL carryforwards, assuming the Company has sufficient taxable income in future carryforward periods to utilize those NOL carryforwards. The Company’s federal NOL carryforwards do not begin expiring until 2024.

At December 31, 2011 and 2010, the Company had state NOLs of $739,804 and $714,674, respectively, a portion of which are offset by a valuation allowance because the Company does not believe these NOLs are more likely than not to be realized. The state NOL carryforwards will expire between 2012 and 2031.

At December 31, 2011 and 2010, the Company had Canadian NOL carryforwards of $6,198 and $5,398, respectively. The majority of these carryforwards are offset by a valuation allowance because the Company does not believe these NOLs are more likely than not to be realized. The Canadian NOL carryforwards will expire between 2014 and 2030.

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At December 31, 2011 and 2010, the Company had capital loss carryforwards for federal income tax purposes of $4,357 and $0, respectively. The Company has recognized a full valuation allowance for the capital loss carryforwards because the Company does not believe these losses are more likely than not to be recovered.

The Company files income tax returns in the United States federal jurisdiction and various state and foreign jurisdictions. With few exceptions, the Company is no longer subject to U.S. federal, state or local or non-U.S income tax examinations by tax authorities for years before 2005.

In March 2010, the Company filed refund claims of $25,314. The refund claims are attributable to the carry back of Alternative Minimum Tax NOLs generated in 2008. These claims procedurally require approval by the Joint Committee of Taxation (“JCT”). The Company received the refund in April 2010. In August 2010, the IRS notified the Company that additional audit procedures were necessary to support the filing of the JCT report. The audit has not been concluded at December 31, 2011, and no adjustments have been proposed so far.

The Company has state income tax examinations in progress and does not expect material adjustments to result.

The Patient Protection and Affordable Care Act (the “PPACA”) became law on March 23, 2010, and the Health Care and Education Reconciliation Act of 2010 became law on March 30, 2010, which makes various amendments to certain aspects of the PPACA (together, the “Acts”). The PPACA effectively changes the tax treatment of federal subsidies paid to sponsors of retiree health benefit plans that provide a benefit that is at least actuarially equivalent to the benefits under Medicare Part D. As a result of the Acts, these subsidy payments will effectively become taxable in tax years beginning after December 31, 2012.

Although this change does not take effect immediately, companies are required to recognize the full accounting impact in their financial statements in the period in which the legislation was enacted. As a result, the Company followed its original accounting for the underfunded status of the other postretirement benefits for the Medicare Part D adjustment and recorded a reduction in deferred tax assets and an increase in its regulatory assets amounting to $16,979.

The following table summarizes the changes in the Company’s gross liability, excluding interest and penalties, for unrecognized tax benefits:

Balance at January 1, 2010	$	112,021
Increases in current period tax positions		7,434
Decreases due to lapse of statute of limitations		(1,141	)
Balance at December 31, 2010		118,314
Increases in current period tax positions		46,961
Decreases in prior period measurement of tax positions		(6,697	)
Balance at December 31, 2011	$	158,578

The liability balance as of December 31, 2011 and 2010 does not include interest and penalties of $214 and $80, respectively, which is recorded as a component of income tax expense. The majority of the increased tax position is attributable to temporary differences. The increase in 2011 current period tax positions relates primarily to the Company’s change in tax accounting method filed in 2008 for repair and maintenance costs on its utility assets. The Company does not anticipate material changes to its unrecognized tax benefits within the next year. If the Company sustains all of its positions at December 31, 2011 and 2010, an unrecognized tax benefit of $6,644 and $6,644, respectively, excluding interest and penalties, would impact the Company’s effective tax rate.

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The following table summarizes the changes in the Company’s valuation allowance:

Balance at January 1, 2009	$	28,862
Increases in current period tax positions		2,778
Decreases in current period tax positions		(5,698	)
Decreases in prior period tax positions		(321	)
Balance at December 31, 2009	$	25,621
Increases in current period tax positions		907
Decreases in current period tax positions		(2,740	)
Balance at December 31, 2010	$	23,788
Increases in current period tax positions		1,525
Decreases in current period tax positions		(3,734	)
Balance at December 31, 2011	$	21,579

Note 15: Employee Benefits

Pension and Other Postretirement Benefits

The Company maintains noncontributory defined benefit pension plans covering eligible non-union employees of its regulated utility and shared services operations. Benefits under the plans are based on the employee’s years of service and compensation. The pension plans have been closed for most employees hired on or after January 1, 2006. Union employees hired on or after January 1, 2001 had their accrued benefit frozen and will be able to receive this benefit as a lump sum upon termination or retirement. Union employees hired on or after January 1, 2001 and non-union employees hired on or after January 1, 2006 are provided with a 5.25% of base pay defined contribution plan.

The Company’s funding policy is to contribute at least the minimum amount required by the Employee Retirement Income Security Act of 1974 and also an additional contribution if needed to avoid “at risk” status and benefit restrictions under the Pension Protection Act of 2006. The Company may also increase its contributions, if appropriate, to its tax and cash position and the plan’s funded position. Pension plan assets are invested in a number of investments including equity and bond mutual funds, fixed income securities and guaranteed interest contracts with insurance companies.

Pension expense in excess of the amount contributed to the pension plans is deferred by certain regulated subsidiaries pending future recovery in rates charged for utility services as contributions are made to the plans. (See Note 7)

The Company also has several unfunded noncontributory supplemental non-qualified pension plans that provide additional retirement benefits to certain employees.

The Company maintains postretirement benefit plans providing varying levels of medical and life insurance to eligible retirees. The retiree welfare plans are closed for union employees hired on or after January 1, 2006. The plans had previously closed for non-union employees hired on or after January 1, 2002.

The Company’s policy is to fund postretirement benefit costs for rate-making purposes. Plan assets are invested in equity and bond mutual funds.

The obligations of the plans are dominated by obligations for active employees. Because the timing of expected benefit payments is so far in the future and the size of the plan assets are small relative to the Company’s assets, the investment strategy is to allocate a large portion of assets to equities, which the Company believes will provide the highest return over the long-term period. The fixed income assets are invested in long duration debt securities in order to better match the duration of the plan liability.

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The Company periodically conducts an asset liability modeling study to ensure the investment strategy is aligned with the profile of the obligations. The long-term goals are to maximize the plan funded status and minimize contributions and pension expense, while taking into account the potential volatility risks on each of these items.

None of the Company’s securities are included in pension or other postretirement benefit plan assets.

The investment policy guidelines of the pension plan require that the fixed income portfolio has an overall weighted average credit rating of AA or better by Standard & Poor’s and the minimum credit quality for fixed income securities must be BBB- or better. Up to 20% of the portfolio may be invested in collateralized mortgage obligations backed by the United States Government.

The fair values and asset allocations of pension plan assets at December 31, 2011, by asset category, follow:

Asset Category	Target Allocation 2012			Total		Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Percentage of Plan Assets at December 31, 2011
Cash		—		$	9,794	$	9,794		—		—		—
Equity securities:
U.S. large cap		36	%		364,025		364,025		—		—		37	%
U.S. small cap value		12	%		119,996		116,748	$	3,248		—		12	%
International		22	%		202,917		26		100,745	$	102,146		21	%
Fixed income securities:		30	%										30	%
U.S. Treasury and government bonds		—			61,278		61,278		—		—		—
Corporate bonds		—			48,564		2,487		46,077		—		—
Mortgage-backed securities		—			118,837		—		118,837		—		—
Guaranteed annuity contracts		—			55,657		—		9,229		46,428		—
Total		100	%	$	981,068	$	554,358	$	278,136	$	148,574		100	%

The following table presents a reconciliation of the beginning and ending balances of the fair value measurements using significant unobservable inputs (Level 3):

	Level 3
Balance, January 1, 2011	$	141,403
Actual return on assets		(3,425	)
Transfers in(out)		10,596
Balance, December 31, 2011	$	148,574

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The fair values and asset allocations of pension plan assets at December 31, 2010, by asset category, follow:

Asset Category	Target Allocation 2011			Total		Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Percentage of Plan Assets at December 31, 2010
Cash		—		$	6,467	$	6,467		—		—		—
Equity securities:
U.S. large cap		36	%		299,548		299,548		—		—		35	%
U.S. small cap value		12	%		113,356		113,356		—		—		13	%
International		22	%		190,330		682	$	94,363	$	95,285		22	%
Fixed income securities:		30	%										30	%
U.S. Treasury and government bonds		—			63,469		63,469		—		—		—
Corporate Bonds		—			33,118		—		33,118		—		—
Mortgage-backed securities		—			99,478		—		99,478		—		—
Guaranteed annuity contracts		—			55,207		—		9,089		46,118		—
Total		100	%	$	860,973	$	483,522	$	236,048	$	141,403		100	%

The following table presents a reconciliation of the beginning and ending balances of the fair value measurements using significant unobservable inputs (Level 3):

	Level 3
Balance, January 1, 2010	$	124,938
Actual return on assets		20,381
Transfers in (out)		(3,916	)
Balance, December 31, 2010	$	141,403

The Company’s other postretirement benefit plans are partially funded and plan assets are invested in a manner consistent with the pension plan investment policy.

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The fair values and asset allocations of postretirement benefit plan assets at December 31, 2011, by asset category, follow:

Asset Category	Target Allocation 2012			Total		Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Percentage of Plan Assets at December 31, 2011
Cash		—		$	10,196	$	10,196		—		—		—
Equity securities:
U.S. large cap		36	%		136,625		136,625		—		—		36	%
U.S. small cap value		12	%		52,092		50,720	$	1,372		—		14	%
International		22	%		78,294		45,537		32,757		—		20	%
Fixed income securities:		30	%										30	%
U.S. Treasury securities		—			12,897		12,897		—		—		—
Corporate bonds		—			46,953		—		46,953		—		—
Mortgage-backed securities		—			45,613		—		45,613		—		—
Total		100	%	$	382,670	$	255,975	$	126,695		—		100	%

The fair values and asset allocations of postretirement benefit plan assets at December 31, 2010, by asset category, follow:

Asset Category	Target Allocation 2011			Total		Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Percentage of Plan Assets at December 31, 2010
Cash		—		$	12,500	$	12,500		—		—		—
Equity securities:
U.S. large cap		36	%		131,775		131,775		—		—		35	%
U.S. small cap value		12	%		53,898		53,898		—		—		14	%
International		22	%		77,935		77,935		—		—		21	%
Fixed income securities:		30	%										30	%
U.S. Treasury securities		—			16,025		16,025		—		—		—
Corporate Bonds		—			34,746		—	$	34,746		—		—
Mortgage-backed securities		—			47,524		—		47,524		—		—
Total		100	%	$	374,403	$	292,133	$	82,270		—		100	%

Valuation Techniques Used to Determine Fair Value

Cash—Cash and investments with maturities of three months or less when purchased, including certain short-term fixed-income securities, are considered cash and are included in the recurring fair value measurements hierarchy as Level 1.

Equity securities—With respect to equity securities, the trustees obtain prices from pricing services, whose prices are obtained from direct feeds from market exchanges, which the Company is able to independently corroborate. Equity securities are valued based on quoted prices in active markets and categorized as Level 1.

Fixed-income securities—U.S. Treasury securities and government bonds have been categorized in Level 1 because they trade in highly-liquid and transparent markets that the Company can corroborate. The fair values of corporate bonds, mortgage backed securities and a certain guaranteed annuity contract are based on evaluated prices that reflect observable market information, such as actual trade information of similar securities and have

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been categorized as Level 2 because the valuations are calculated using models which utilize actively traded market data that the Company can corroborate. Certain other guaranteed annuity contracts are invested in a commingled fund and categorized as Level 3 because the investments are not publicly quoted. The fund administrator values the fund using the net asset value per fund share, derived from the quoted prices in active markets of the underlying securities. Since these valuation inputs are not highly observable, the commingled funds have been categorized as Level 3.

In 2011, after a review of the underlying pension investments, the Company began classifying certain international equity securities as Level 2 and Level 3 and reclassified the prior years’ presentations to conform to the 2011 presentation.

The following table provides a rollforward of the changes in the benefit obligation and plan assets for the most recent two years for all plans combined:

	Pension Benefits						Other Benefits
	2011			2010			2011			2010
Change in benefit obligation
Benefit obligation at January 1	$	1,285,456		$	1,128,162		$	590,187		$	548,139
Service cost		33,641			30,675			13,938			14,663
Interest cost		69,047			67,602			31,219			32,149
Plan participants’ contributions		—			—			2,241			2,307
Amendments		0			3,762			0			(8,195	)
Actuarial (gain) loss		55,743			93,399			4,826			23,764
Gross benefits paid		(41,933	)		(38,144	)		(23,824	)		(23,989	)
Federal subsidy		—			—			1,779			1,349
Benefit obligation at December 31	$	1,401,954		$	1,285,456		$	620,366		$	590,187
Change in Plan Assets
Fair value of plan assets at January 1	$	860,973		$	695,520		$	374,403		$	312,042
Actual return on plan assets		2,529			105,078			2,619			45,305
Employer contributions		159,499			98,519			27,231			38,738
Plan participants’ contributions		—			—			2,241			2,307
Benefits paid		(41,933	)		(38,144	)		(23,824	)		(23,989	)
Fair value of plan assets at December 31	$	981,068		$	860,973		$	382,670		$	374,403
Funded status at December 31	$	(420,886	)	$	(424,483	)	$	(237,696	)	$	(215,784	)
Amounts recognized in the balance sheet consist of:
Current liability	$	(1,909	)	$	(2,097	)	$	(33	)	$	(33	)
Noncurrent liability		(418,977	)		(422,386	)		(237,663	)		(215,751	)
Net amount recognized	$	(420,886	)	$	(424,483	)	$	(237,696	)	$	(215,784	)
Asset (liability) of discontinued operations included in net amount recognized above	$	(6,979	)	$	(8,873	)	$	(577	)	$	(534	)

The following table provides the components of the Company’s accumulated other comprehensive income and regulatory assets that have not been recognized as components of periodic benefit costs as of December 31:

	Pension Benefits				Other Benefits
	2011		2010		2011			2010
Net actuarial loss (gain)	$	409,129	$	302,357	$	164,305		$	140,453
Prior service cost (credit)		5,858		6,580		(16,864	)		(18,788	)
Net amount recognized	$	414,987	$	308,937	$	147,441		$	121,665
Regulatory assets	$	248,663	$	184,937	$	147,441		$	121,665
Accumulated other comprehensive income		166,324		124,000		—			—
	$	414,987	$	308,937	$	147,441		$	121,665

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At December 31, 2011 and 2010, the projected benefit obligation, accumulated benefit obligation and fair value of plan assets for pension plans with a projected obligation in excess of plan assets were as follows:

	Projected Benefit Obligation Exceeds the Fair Value of Plans’ Assets
	2011		2010
Projected benefit obligation	$	1,402,000	$	1,285,000
Fair value of plan assets		981,000		861,000

	Accumulated Benefit Obligation Exceeds the Fair Value of Plans’ Assets
	2011		2010
Accumulated benefit obligation	$	1,257,000	$	1,138,000
Fair value of plan assets		981,000		861,000

The accumulated postretirement benefit obligation exceeds plan assets for all of the Company’s other postretirement benefit plans.

In August 2006, the Pension Protection Act (“PPA”) was signed into law in the U.S. The PPA replaces the funding requirements for defined benefit pension plans by requiring that defined benefit plans contribute to 100% of the current liability funding target over seven years. Defined benefit plans with a funding status of less than 80% of the current liability are defined as being “at risk” and additional funding requirements and benefit restrictions may apply. The PPA was effective for the 2008 plan year with short-term phase-in provisions for both the funding target and at-risk determination. The Company’s qualified defined benefit plan is currently funded above the at-risk threshold, and therefore the Company expects that the plans will not be subject to the “at risk” funding requirements of the PPA. The Company is proactively monitoring the plan’s funded status and projected contributions under the new law to appropriately manage the potential impact on cash requirements.

Minimum funding requirements for the qualified defined benefit pension plan are determined by government regulations and not by accounting pronouncements. The Company plans to contribute amounts at least equal to the minimum required contributions in 2012 to the qualified pension plans. The Company plans to contribute its 2012 other postretirement benefit cost for rate-making purposes.

Information about the expected cash flows for the pension and postretirement benefit plans is as follows:

	Pension Benefits		Other Benefits
2012 expected employer contributions
To plan trusts	$	126,700	$	29,983
To plan participants		1,909		33

The Company made 2012 contributions to fund pension benefits and other benefits of $32,931 and $7,496, respectively, through February 2012.

The following table reflects the net benefits expected to be paid from the plan assets or the Company’s assets:

	Pension Benefits		Other Benefits
	Expected Benefit Payments		Expected Benefit Payments		Expected Federal Subsidy Payments
2012	$	47,139	$	26,188	$	1,814
2013		53,268		28,794		1,994
2014		59,412		31,641		2,161
2015		65,742		34,618		2,328
2016		72,373		37,581		2,515
2017—2021		458,798		228,379		15,770

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Because the above amounts are net benefits, plan participants’ contributions have been excluded from the expected benefits.

Accounting for pensions and other postretirement benefits requires an extensive use of assumptions about the discount rate, expected return on plan assets, the rate of future compensation increases received by the Company’s employees, mortality, turnover and medical costs. Each assumption is reviewed annually. The assumptions are selected to represent the average expected experience over time and may differ in any one year from actual experience due to changes in capital markets and the overall economy. These differences will impact the amount of pension and other postretirement benefit expense that the Company recognizes.

The significant assumptions related to the Company’s pension and other postretirement benefit plans are as follows:

	Pension Benefits									Other Benefits
	2011			2010			2009			2011			2010			2009
Weighted-average assumptions used to determine December 31 benefit obligations
Discount rate		5.02	%		5.32	%		5.93	%		5.05	%		5.27	%		5.82	%
Rate of compensation increase		3.25	%		3.50	%		4.00	%		N/A			N/A			N/A
Medical trend		N/A			N/A			N/A			graded from 7.5% in 2012 to 5% in 2019+			graded from 8% in 2011 to 5% in 2017+			graded from 8.5% in 2010 to 5% in 2017+
Weighted-average assumptions used to determine net periodic cost
Discount rate		5.32	%		5.93	%		6.12	%		5.27	%		5.82	%		6.09	%
Expected return on plan assets		7.90	%		7.90	%		7.90	%		7.60	%		7.60	%		7.60	%
Rate of compensation increase		3.50	%		4.00	%		4.00	%		N/A			N/A			N/A
Medical trend		N/A			N/A			N/A			graded from 8% in 2011 to 5% in 2017+			graded from 8.5% in 2010 to 5% in 2017+			graded from 8% in 2009 to 5% in 2015+

N/A—Assumption is not applicable.

The discount rate assumption was determined for the pension and postretirement benefit plans independently. At year end 2011, the Company began using an approach that approximates the process of settlement of obligations tailored to the plans’ expected cash flows by matching the plans’ cash flows to the coupons and expected maturity values of individually selected bonds. The yield curve was developed for a universe containing the majority of U.S.-issued Aa-graded corporate bonds, all of which were non callable (or callable with make-whole provisions). Historically, for each plan, the discount rate was developed as the level equivalent rate that would produce the same present value as that using spot rates aligned with the projected benefit payments.

The expected long-term rate of return on plan assets is based on historical and projected rates of return for current and planned asset classes in the plans’ investment portfolios. Assumed projected rates of return for each of the plans’ projected asset classes were selected after analyzing historical experience and future expectations of the returns and volatility of the various asset classes. Based on the target asset allocation for each asset class, the overall expected rate of return for the portfolio was developed, adjusted for historical and expected experience of active portfolio management results compared to the benchmark returns and for the effect of expenses paid from plan assets. The Company’s pension expense increases as the expected return on assets decreases.

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Assumed health care cost trend rates have a significant effect on the amounts reported for the other postretirement benefit plans. The health care cost trend rate is based on historical rates and expected market conditions. A one-percentage-point change in assumed health care cost trend rates would have the following effects:

	One- Percentage- Point Increase		One- Percentage- Point Decrease
Effect on total of service and interest cost components	$	7,145	$	5,838
Effect on other postretirement benefit obligation	$	83,456	$	69,318

The following table provides the components of net periodic benefit costs for the years ended December 31:

	2011			2010			2009
Components of net periodic pension benefit cost
Service cost	$	33,641		$	30,675		$	28,426
Interest cost		69,047			67,602			62,919
Expected return on plan assets		(72,109	)		(56,751	)		(42,224	)
Amortization of:
Prior service cost (credit)		722			322			182
Actuarial (gain) loss		18,551			17,902			23,968
Net periodic pension benefit cost	$	49,852		$	59,750		$	73,271
Other changes in plan assets and benefit obligations recognized in other comprehensive income, net of tax
Amortization of prior service credit (cost)	$	(175	)	$	(79	)	$	(46	)
Current year actuarial (gain) loss		30,497			11,836			(9,981	)
Amortization of actuarial gain (loss)		(4,504	)		(4,368	)		(5,994	)
Total recognized in other comprehensive income	$	25,818		$	7,389		$	(16,021	)
Total recognized in net periodic benefit cost and comprehensive income	$	75,670		$	67,139		$	57,250
Components of net periodic other postretirement benefit cost
Service cost	$	13,938		$	14,663		$	13,172
Interest cost		31,219			32,149			29,180
Expected return on plan assets		(28,779	)		(24,372	)		(18,638	)
Amortization of:
Transition obligation (asset)		0			173			173
Prior service cost (credit)		(1,924	)		(1,180	)		(1,180	)
Actuarial (gain) loss		7,133			8,159			9,155
Net periodic other postretirement benefit cost	$	21,587		$	29,592		$	31,862

The Company’s policy is to recognize curtailments when the total expected future service of plan participants is reduced by greater than 10% due to an event that results in terminations and/or retirements.

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The estimated amounts that will be amortized from accumulated other comprehensive income and regulatory assets into net periodic benefit cost in 2012 are as follows:

	Pension Benefits		Other Benefits
Actuarial (gain) loss	$	29,923	$	9,537
Prior service cost (credit)		722		(1,914	)
Total	$	30,645	$	7,623

Savings Plans for Employees

The Company maintains 401(k) savings plans that allow employees to save for retirement on a tax-deferred basis. Employees can make contributions that are invested at their direction in one or more funds. The Company makes matching contributions based on a percentage of an employee’s contribution, subject to certain limitations. Due to the Company’s discontinuing new entrants into the defined benefit pension plan, on January 1, 2006 the Company began providing an additional 5.25% of base pay defined contribution benefit for union employees hired on or after January 1, 2001 and non-union employees hired on or after January 1, 2006. The Company expensed contributions to the plans totaling $8,997 for 2011, $8,651 for 2010, and $8,082 for 2009, respectively. All of the Company’s contributions are invested in one or more funds at the direction of the employee.

Note 16: Commitments and Contingencies

The Company is also routinely involved in legal actions incident to the normal conduct of its business. At December 31, 2011, the Company has accrued approximately $2,900 as probable costs and it is reasonably possible that additional losses could range up to $9,700 for these matters. For certain matters, the Company is unable to estimate possible losses. The Company believes that damages or settlements, if any, recovered by plaintiffs in such claims or actions will not have a material adverse effect on the Company’s results of operations, financial position or cash flows.

The Company enters into agreements for the provision of services to water and wastewater facilities for the United States military, municipalities and other customers. The Company’s military services agreements expire between 2051 and 2060 and have remaining performance commitments as measured by estimated remaining contract revenue of $2,037,000 at December 31, 2011. The military contracts are subject to customary termination provisions held by the U.S. Federal Government prior to the agreed upon contract expiration. The Company’s Operations and Maintenance agreements with municipalities and other customers expire between 2012 and 2048 and have remaining performance commitments as measured by estimated remaining contract revenue of $1,076,000 at December 31, 2011. Some of the Company’s long-term contracts to operate and maintain a municipality’s, federal government’s or other party’s water or wastewater treatment and delivery facilities include responsibility for certain maintenance for some of those facilities, in exchange for an annual fee. Unless specifically required to perform certain maintenance activities, the maintenance costs are recognized when the maintenance is performed.

Commitments have been made in connection with certain construction programs. The estimated capital expenditures required under legal and binding contractual obligations amounted to $171,878 at December 31, 2011.

The Company’s regulated subsidiaries maintain agreements with other water purveyors for the purchase of water to supplement their water supply. The Company’s subsidiaries purchased water expense under these types of agreements amounted to approximately $104,384, $103,898 and $96,053 during the years ended December 31, 2011, 2010 and 2009, respectively. The estimated annual commitment related to the minimum quantities of water purchased is expected to approximate $48,916 in 2012, $47,576 in 2013, $47,452 in 2014, $47,404 in 2015, $43,439 in 2016 and $448,920 thereafter.

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Note 17: Earnings (Loss) per Common Share

Earnings per share is calculated using the two-class method. The two-class method is an earnings allocation formula that determines earnings per share for each class of common stock and participating security. The Company has participating securities related to restricted stock units, granted under the Company’s 2007 Omnibus Equity Compensation Plan, that earn dividend equivalents on an equal basis with common shares. In applying the two-class method, undistributed earnings are allocated to both common shares and participating securities. There were 21 participating securities that were not included in the basic net loss per common share calculation at December 31, 2009 because they were anti-dilutive. The following is a reconciliation of the Company’s income (loss) from continuing operations, income (loss) from discontinued operations and net income (loss) and weighted average common shares outstanding for calculating basic net earnings (loss) per share:

	Years Ended December 31,
	2011		2010		2009
Basic
Income (loss) from continuing operations	$	304,929	$	255,072	$	(219,998	)
Income (loss) from discontinued operations, net of tax		4,684		12,755		(13,085	)
Net income (loss)		309,613		267,827		(233,083	)
Less: Distributed earnings to common shareholders		158,708		150,724		137,597
Less: Distributed earnings to participating securities		68		51		0
Undistributed earnings		150,837		117,052		(370,680	)
Undistributed earnings allocated to common shareholders		150,772		117,014		(370,680	)
Undistributed earnings allocated to participating securities		65		38		0
Total income (loss) from continuing operations available to common shareholders, basic	$	304,796	$	254,983	$	(219,998	)
Total income (loss) available to common shareholders, basic	$	309,480	$	267,738	$	(233,083	)
Weighted average common shares outstanding, basic		175,484		174,833		168,164
Basic earnings (loss) per share: (a)
Income (loss) from continuing operations	$	1.74	$	1.46	$	(1.31	)
Income (loss) from discontinued operations, net of tax	$	0.03	$	0.07	$	(0.08	)
Net income (loss)	$	1.76	$	1.53	$	(1.39	)

(a) Amounts may not sum due to rounding.

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Diluted earnings (loss) per common share is based on the weighted average number of common shares outstanding adjusted for the dilutive effect of common stock equivalents related to the restricted stock units, stock options, and employee stock purchase plan. The dilutive effect of the common stock equivalents is calculated using the treasury stock method and expected proceeds on vesting of the restricted stock units, exercise of the stock options and purchases under the employee stock purchase plan. The following is a reconciliation of the Company’s income (loss) from continuing operations, income (loss) from discontinued operations and net income (loss) and weighted average common shares outstanding for calculating diluted earnings (loss) per share:

	Years Ended December 31,
	2011		2010		2009
Diluted
Total income (loss) from continuing operations available to common shareholders, basic	$	304,796	$	254,983	$	(219,998	)
Income (loss) from discontinued operations, net of tax		4,684		12,755		(13,085	)
Total income (loss) available to common shareholders, basic		309,480		267,738		(233,083	)
Undistributed earnings allocated to participating securities		65		38		0
Total income (loss) from continuing operations available to common shareholders, diluted	$	304,861	$	255,021	$	(219,998	)
Total income (loss) available to common shareholders, diluted	$	309,545	$	267,776	$	(233,083	)
Weighted average common shares outstanding, basic		175,484		174,833		168,164
Restricted stock units		556		264		0
Stock options		490		26		0
Employee stock purchase plan		1		1		0
Weighted average common shares outstanding, diluted		176,531		175,124		168,164
Diluted earnings per share: (a)
Income (loss) from continuing operations	$	1.73	$	1.46	$	(1.31	)
Income (loss) from discontinued operations, net of tax	$	0.03	$	0.07	$	(0.08	)
Net income (loss)	$	1.75	$	1.53	$	(1.39	)

(a) Amounts may not sum due to rounding.

The following potentially dilutive common stock equivalents were not included in the earnings (loss) per share calculations for the years ended December 31 because they were anti-dilutive:

	2011		2010		2009
Stock options		711		1,781		2,265
Stock options where certain performance conditions were not met		0		0		459
Restricted stock units		0		0		258
Restricted stock units where certain performance conditions were not met		22		69		144
Employee stock purchase plan		0		0		32

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Note 18: Fair Values of Financial Instruments

The following methods and assumptions were used by the Company in estimating its fair value disclosures for financial instruments:

Current assets and current liabilities: The carrying amounts reported in the Consolidated Balance Sheets for current assets and current liabilities, including revolving credit debt, due to the short-term maturities and variable interest rates, approximate their fair values.

Preferred stock with mandatory redemption requirements and long-term debt: The fair values of preferred stock with mandatory redemption requirements and long-term debt are determined by a valuation model which is based on a conventional discounted cash flow methodology and utilizes assumptions of current market rates. As a majority of the Company’s debts do not trade in active markets, the Company calculated a base yield curve using a risk-free rate (a U.S. Treasury securities yield curve) plus a credit spread that is based on the following two factors: an average of the Company’s own publicly-traded debt securities and the current market rates for U.S. Utility BBB+ debt securities. The Company used these yield curve assumptions to derive a base yield and then adjusted the base yield for specific features of the debt securities of call features, coupon tax treatment and collateral.

The carrying amounts (including fair value adjustments previously recognized in acquisition purchase accounting) and fair values of the financial instruments are as follows:

As of December 31, 2011	Carrying Amount		Fair Value
Preferred stocks with mandatory redemption requirements	$	22,036	$	26,458
Long-term debt (excluding capital lease obligations)		5,366,642		6,230,547

As of December 31, 2010	Carrying Amount		Fair Value
Preferred stocks with mandatory redemption requirements	$	22,794	$	25,475
Long-term debt (excluding capital lease obligations)		5,424,492		5,841,448

Fair Value Measurements

To increase consistency and comparability in fair value measurements, FASB guidance establishes a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value into three levels as follows:

• Level 1—quoted prices (unadjusted) in active markets for identical assets or liabilities that the Company has the ability to access as of the reporting date. Financial assets and liabilities utilizing Level 1 inputs include active exchange-traded equity securities, exchange-based derivatives, mutual funds and money market funds.

• Level 2—inputs other than quoted prices included within Level 1 that are directly observable for the asset or liability or indirectly observable through corroboration with observable market data. Financial assets and liabilities utilizing Level 2 inputs include fixed income securities, non-exchange-based derivatives, commingled investment funds not subject to purchase and sale restrictions and fair-value hedges.

• Level 3—unobservable inputs, such as internally-developed pricing models for the asset or liability due to little or no market activity for the asset or liability. Financial assets and liabilities utilizing Level 3 inputs include infrequently-traded non-exchange-based derivatives and commingled investment funds subject to purchase and sale restrictions.

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Recurring Fair Value Measurements

The following table presents assets and liabilities measured and recorded at fair value on a recurring basis and their level within the fair value hierarchy as of December 31, 2011 and 2010, respectively:

	At Fair Value as of December 31, 2011
Recurring Fair Value Measures	Level 1		Level 2			Level 3		Total
Assets:
Restricted funds	$	57,941		—			—	$	57,941
Rabbi trust investments		—	$	518			—		518
Deposits		2,287		—			—		2,287
Mark-to-market derivative asset		—		5,824			—		5,824
Total assets		60,228		6,342			—		66,570
Liabilities:
Deferred compensation obligation		—		9,036			—		9,036
Total liabilities		—		9,036			—		9,036
Total net assets (liabilities)	$	60,228	$	(2,694	)		—	$	57,534

	At Fair Value as of December 31, 2010
Recurring Fair Value Measures	Level 1		Level 2			Level 3		Total
Assets:
Restricted funds	$	120,784		—			—	$	120,784
Rabbi trust investments		—	$	1,552			—		1,552
Deposits		1,381		—			—		1,381
Total assets		122,165		1,552			—	$	123,717
Liabilities:
Deferred compensation obligation		—		9,180			—		9,180
Mark-to-market derivative liability		—		898			—		898
Total liabilities		—		10,078			—		10,078
Total net assets (liabilities)	$	122,165	$	(8,526	)		—	$	113,639

Restricted funds—The Company’s restricted funds primarily represent proceeds received from financings for the construction and capital improvement of facilities and from customers for future services under operations and maintenance projects. The proceeds of these financings are held in escrow until the designated expenditures are incurred. Restricted funds expected to be released within twelve months subsequent to year end are classified as current.

Rabbi trust investments—The Company’s rabbi trust investments consist primarily of fixed income investments from which supplemental executive retirement plan benefits are paid. The Company includes these assets in other long-term assets.

Deposits—Deposits includes escrow funds and certain other deposits held in trust. The Company includes cash deposits in other current assets.

Deferred compensation obligations—The Company’s deferred compensation plans allow participants to defer certain cash compensation into notional investment accounts. The Company includes such plans in other long-term liabilities. The value of the Company’s deferred compensation obligations is based on the market value of the participants’ notional investment accounts. The notional investments are comprised primarily of mutual funds, which are based on observable market prices.

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Mark-to-market derivative asset and liability-The Company utilizes fixed-to-floating interest-rate swaps, typically designated as fair-value hedges, to achieve a targeted level of variable-rate debt as a percentage of total debt. The Company uses a calculation of future cash inflows and estimated future outflows, which are discounted, to determine the current fair value. Additional inputs to the present value calculation include the contract terms, counterparty credit risk, interest rates and market volatility.

See Note 15 for the Company’s fair value of qualified pension and postretirement welfare plans’ assets.

Non-recurring Fair Value Measurements

As discussed in Note 8, the Company recognized continuing operations goodwill impairment charges of $0, $0, and $428,036 for the years ended December 31, 2011, 2010 and 2009, respectively. The Company’s goodwill valuation model includes significant unobservable inputs and falls within Level 3 of the fair value hierarchy.

Note 19: Operating Leases

The Company has entered into operating leases involving certain facilities and equipment. Rental expenses of continuing operations under operating leases were $32,752 for 2011, $36,264 for 2010 and $34,862 for 2009. The operating leases for facilities will expire over the next 20 years and the operating leases for equipment will expire over the next five years. Certain operating leases have renewal options ranging from one to five years.

At December 31, 2011, the minimum annual future rental commitment under operating leases that have initial or remaining non-cancelable lease terms in excess of one year are $21,528 in 2012, $17,987 in 2013, $14,833 in 2014, $10,877 in 2015, $9,172 in 2016 and $101,472 thereafter.

The Company has a series of agreements with various public entities (the “Partners”) to establish certain joint ventures, commonly referred to as “public-private partnerships.” Under the public-private partnerships, the Company constructed utility plant, financed by the Company, and the Partners constructed utility plant (connected to the Company’s property), financed by the Partners. The Company agreed to transfer and convey some of its real and personal property to the Partners in exchange for an equal principal amount of Industrial Development Bonds (“IDBs”), issued by the Partners under a state Industrial Development Bond and Commercial Development Act. The Company leased back the total facilities, including portions funded by both the Company and the Partners, under leases for a period of 40 years.

The leases related to the portion of the facilities funded by the Company have required payments from the Company to the Partners that approximate the payments required by the terms of the IDBs from the Partners to the Company (as the holder of the IDBs). As the ownership of the portion of the facilities constructed by the Company will revert back to the Company at the end of the lease, the Company has recorded these as capital leases. The lease obligation and the receivable for the principal amount of the IDBs are presented by the Company on a net basis. The carrying value of the facilities funded by the Company recognized as a capital lease asset was $159,211 and $159,707 at December 31, 2011 and 2010, respectively, which is presented within utility plant. The future payments under the lease obligations are equal to and offset by the payments receivable under the IDBs.

At December 31, 2011, the minimum annual future rental commitment under the operating leases for the portion of the facilities funded by the Partners that have initial or remaining non-cancelable lease terms in excess of one year included in the preceding minimum annual rental commitments are $3,629 in 2012, $3,668 in 2013, $3,727 in 2014 through 2016, and $82,620 thereafter.

Note 20: Related Party Transactions

One of the Company’s Directors was employed by an electrical utility that supplies electricity and electrical services to the Company’s subsidiaries in Ohio, Pennsylvania, and New Jersey. The Company purchased, from

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various subsidiaries of this electrical utility, approximately $8,558 of such services in 2009. The Director retired from that electrical utility effective March 31, 2010. The Company purchased, from various subsidiaries of this electrical utility, approximately $3,225 of such services in the first quarter of 2010.

Note 21: Segment Information

The Company has two operating segments referred to as the Regulated Businesses and Market-Based Operations segments. The Company’s chief operating decision maker regularly reviews the operating results of the Regulated Businesses and Market-Based Operations segments to assess segment performance and allocate resources. The evaluation of segment performance and the allocation of resources are based on several measures. The measure that is most consistent with that used by management is income from continuing operations before income tax.

The Regulated Businesses segment includes the Company’s 17 utility subsidiaries in continuing operations that provide water and wastewater services to customers in 16 U.S. states. With the exception of one company, each of these public utility subsidiaries is subject to regulation by public utility commissions and local governments. In addition to providing similar products and services and being subject to the public utility regulatory environment, each of the regulated subsidiaries has similar economic characteristics, production processes, types and classes of customers and water distribution or wastewater collection processes. Each of these companies is also subject to both federal and state regulation regarding the quality of water distributed and the discharge of wastewater residuals.

The Market-Based Operations segment is comprised of market-based businesses that provide a broad range of market-based water and wastewater services and products including homeowner water and sewer line maintenance services, water and wastewater facility operations and maintenance services, granular carbon technologies and products for cleansing water and wastewater, wastewater residuals management services and water and wastewater facility engineering services.

The accounting policies of the segments are the same as those described in the summary of significant accounting policies (see Note 2). The Regulated Businesses and Market-Based Operations segment information includes intercompany costs that are allocated by American Water Works Service Company, Inc. and intercompany interest that is charged by AWCC, which are eliminated to reconcile to the consolidated results of operations. Inter-segment revenues, which are primarily recorded at cost plus mark-up that approximates current market prices, include carbon regeneration services and leased office space, furniture and equipment provided by the Company’s market-based subsidiaries to its regulated subsidiaries. Other includes corporate costs that are not allocated to the Company’s subsidiaries, eliminations of inter-segment transactions, fair value adjustments and associated income and deductions related to the Acquisitions that have not been allocated to the segments for evaluation of segment performance and allocation of resource purposes. The adjustments related to the Acquisitions are reported in Other, as they are excluded from segment performance measures evaluated by management. The following table includes the Company’s summarized segment information:

	As of or for the Year Ended December 31, 2011
	Regulated Businesses		Market-Based Operations		Other			Consolidated
Net operating revenues	$	2,368,891	$	327,815	$	(30,470	)	$	2,666,236
Depreciation and amortization		321,540		6,822		23,459			351,821
Total operating expenses, net		1,609,276		290,854		(37,030	)		1,863,100
Income (loss) from continuing operations before income taxes		535,445		39,250		(71,015	)		503,680
Total assets		12,843,820		280,862		1,651,709			14,776,391
Assets of discontinued operations (included in total assets above)		904,391		0		25,467			929,858
Capital expenditures		920,210		4,648		0			924,858
Capital expenditures of discontinued operations (included in above)		21,052		86		0			21,138

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	As of or for the Year Ended December 31, 2010
	Regulated Businesses		Market-Based Operations		Other			Consolidated
Net operating revenues	$	2,285,656	$	294,723	$	(25,344	)	$	2,555,035
Depreciation and amortization		301,087		7,014		22,163			330,264
Total operating expenses, net		1,587,963		269,060		(30,110	)		1,826,913
Income (loss) from continuing operations before income taxes		478,629		30,443		(79,648	)		429,424
Total assets		12,290,798		240,718		1,554,730			14,086,246
Assets of discontinued operations (included in total assets above)		911,905		6,590		19,210			937,705
Capital expenditures		758,150		7,486		0			765,636
Capital expenditures of discontinued operations (included in above)		26,725		143		0			26,868

	As of or for the Year Ended December 31, 2009
	Regulated Businesses		Market-Based Operations		Other			Consolidated
Net operating revenues	$	2,076,563	$	238,180	$	(24,297	)	$	2,290,446
Depreciation and amortization		286,390		5,306		18,178			309,874
Impairment charge		0		0		428,036			428,036
Total operating expenses, net		1,497,453		217,643		391,515			2,106,611
Income (loss) from continuing operations before income taxes		371,919		25,168		(503,293	)		(106,206	)
Total assets		11,673,685		246,201		1,539,482			13,459,368
Assets of discontinued operations (included in total assets above)		905,938		9,333		17,504			932,775
Capital expenditures		779,428		5,837		0			785,265
Capital expenditures of discontinued operations (included in above)		43,078		111		0			43,189

Note 22: Unaudited Quarterly Data

The following table sets forth certain supplemental unaudited consolidated quarterly financial data for each of the four quarters in the years ended December 31, 2011 and 2010, respectively. The operating results for any quarter are not indicative of results that may be expected for a full year or any future periods.

During the fourth quarter of 2011, the Company discovered errors in the Company’s calculation of gain or loss on discontinued operations that originated in the first and second quarters of 2011. As a result, the Company recorded an after-tax charge totaling $24,555 to reduce the net asset values of those businesses, which included associated parent company goodwill, to their net realizable values. This charge was recognized within discontinued operations and net income and included in results for the full year ended December 31, 2011. The write-downs consisted of $21,099 recognized as of March 31, and $3,456 recognized as of June 30 as reflected in the table below. Management does not consider these write-downs to constitute a triggering event for the balance of the Company’s goodwill of continuing operations. In addition, the adjustment had no impact on income from continuing operations or to the cash flows from operations or total cash flows.

Based on the materiality guidelines contained in SEC Staff Accounting Bulletin No. 99, “Materiality” and Topic 5.F of the Codification of Staff Accounting Bulletins, “Accounting Changes Not Retroactively Applied Due to Immateriality,” the Company concluded that the adjustments to correct the errors were not material to its financial statements for the three months ended March 31, 2011 and June 30, 2011. Because the effect of the adjustments were not material to any previously issued financial statements, the Company determined not to

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amend its previously filed Quarterly Reports on Form 10-Q for the quarters ended March 31, 2011 and June 30, 2011; instead, the Company will make corresponding adjustments to prior period financial statements, as appropriate, the next time those financial statements are filed.

2011	First Quarter		Second Quarter		Third Quarter		Fourth Quarter
	(In thousands, except per share data)
Operating revenues	$	596,715	$	668,873	$	760,869	$	639,779
Operating income		143,250		201,395		281,408		177,083
Income from continuing operations		40,699		74,817		128,495		60,918
Net income		26,233		81,110		137,422		64,848
Basic earnings per common share:
Income from continuing operations	$	0.23	$	0.43	$	0.73	$	0.35
Net income	$	0.15	$	0.46	$	0.78	$	0.37
Diluted earnings per common share:
Income from continuing operations	$	0.23	$	0.42	$	0.73	$	0.34
Net income	$	0.15	$	0.46	$	0.78	$	0.37
2010	First Quarter		Second Quarter		Third Quarter		Fourth Quarter
	(In thousands, except per share data)
Operating revenues	$	554,205	$	630,761	$	744,296	$	625,773
Operating income		123,831		188,367		266,480		149,444
Income from continuing operations		29,328		68,071		119,327		38,346
Net income		30,808		72,751		124,114		40,154
Basic earnings per common share:
Income from continuing operations	$	0.17	$	0.39	$	0.68	$	0.22
Net income	$	0.18	$	0.42	$	0.71	$	0.23
Diluted earnings per common share:
Income from continuing operations	$	0.17	$	0.39	$	0.68	$	0.22
Net income	$	0.18	$	0.42	$	0.71	$	0.23

Amounts may not sum due to rounding; per share amounts may not sum due to changes in shares outstanding during the year.

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ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE

None

ITEM 9A. CONTROLS AND PROCEDURES

Disclosure Controls and Procedures

American Water Works Company, Inc. maintains disclosure controls and procedures that are designed to ensure that information required to be disclosed in its reports filed or submitted under the Securities Exchange Act of 1934 (“the Exchange Act”) is recorded, processed, summarized and reported, within the time periods specified in the SEC’s rules and forms, and that such information is accumulated and communicated to management, including the Chief Executive Officer and the Chief Financial Officer, to allow timely decisions regarding required disclosure.

Our management, including the Chief Executive Officer and the Chief Financial Officer, conducted an evaluation of the effectiveness of our disclosure controls and procedures (as defined in Rules 13a-15(e) of the Exchange Act) as of December 31, 2011 pursuant to 15d-15(e) under the Exchange Act.

Based on that evaluation, our Chief Executive Officer and Chief Financial Officer have concluded that, as of December 31, 2011, our disclosure controls and procedures were effective at a reasonable level of assurance. Our disclosure controls and procedures are designed to provide reasonable assurance that the information required to be disclosed by us in the reports we file or submit under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms.

Management’s Report on Internal Control over Financial Reporting

Our management is responsible for establishing and maintaining adequate internal control over financial reporting, as such term is defined in Exchange Act Rule 13a-15(f). Our 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: (1) pertain to the maintenance of records that in reasonable detail accurately and fairly reflect our transactions and dispositions of our assets; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of the financial statements in accordance with generally accepted accounting principles, and that our receipts and expenditures are being made only in accordance with authorizations of our management and our directors; (3) 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.

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.

Our management, including our Chief Executive Officer and the Chief Financial Officer, assessed the effectiveness of our internal control over financial reporting, as of December 31, 2011, using the criteria described in Internal Control—Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO).

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Based on our evaluation under the framework in Internal Control—Integrated Framework issued by COSO, our management concluded that our internal control over financial reporting was effective as of December 31, 2011.

The effectiveness of our internal control over financial reporting as of December 31, 2011 has been audited by PricewaterhouseCoopers LLP, an independent registered public accounting firm, as stated in their report appearing in Part II, Item 8 of this Annual Report on Form 10-K.

ITEM 9B. OTHER INFORMATION

None.

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PART III

ITEM 10. DIRECTORS, EXECUTIVE OFFICERS OF THE REGISTRANT AND CORPORATE GOVERNANCE

The information required by this item and not given below, is incorporated by reference in the Company’s Proxy Statement for the 2012 Annual Meeting of Stockholders, to be filed with the Securities and Exchange Commission within 120 days following the end of the fiscal year covered by this report, under the captions entitled “Nominees for Election as Directors,” “Information Relative to the Board of Directors and Committees of the Board of Directors,” “Section 16(a) Beneficial Ownership Reporting Compliance,” and “Code of Ethics and Corporate Governance Guidelines.”

We have adopted a Code of Ethics, which applies to directors and employees. The full text of the Code of Ethics is publicly available on our website at http://www.amwater.com. We intend to post on our website any amendments to certain provisions of our Code of Ethics and any waivers of such provisions granted to principal officers.

Name	Age		Office and Employment During Last Ten Years
Jeffry Sterba		56	Mr. Sterba has been our President and Chief Executive Officer since August 2010. Prior to joining American Water, Mr. Sterba served as Chairman and CEO of PNM Resources, Inc., the parent company of PNM, Texas-New Mexico Power Company (TNMP) and First Choice Power, from 2000 until March 2010. Mr. Sterba previously served as Non-Executive Chairman of PNM Resources until retiring from the Board on December 31, 2011. Since joining PNM in 1977, he held a succession of positions including Executive Vice President and Chief Operating Officer, Senior Vice President Bulk Power Services, Senior Vice President Asset Restructuring, Senior Vice President Retail Electric & Water Services and Vice President Revenue Management. From 1998 to 2000, Mr. Sterba was Executive Vice President of United States Enrichment Corporation (USEC), a global energy company headquartered in Maryland. He has served as the chair of Edison Electric Institute, the national association of shareholder owned utilities, and chair of the Electric Power Research Institute, a non-profit center for energy and environment research. He serves on the board of directors of the Meridian Institute and is a member of the Business Environmental Leadership Council for the Pew Center on Global Climate Change. Mr. Sterba also previously served on the board of directors of the U.S. Chamber of Commerce.
Ellen C. Wolf		58	Ms. Wolf has been our Senior Vice President and Chief Financial Officer since March 2006 and served as a member of our board of directors from March 2006 until August 2007. Ms. Wolf’s career began in the accounting firm of Deloitte Haskins & Sells. From 1987 through 1999, Ms. Wolf held various positions in corporate accounting, finance and business development for Bell Atlantic and several of its subsidiaries, including Bell Atlantic Enterprises International, Bell Atlantic Mobile, and Bell Atlantic Corporation. From 1999 through 2003, Ms. Wolf was employed by us as Vice President and Chief Financial Officer. Prior to re-joining us, Ms. Wolf served as Senior Vice President and Chief Financial Officer of USEC Inc., a global energy company, a position she held beginning in December 2003. Currently, Ms. Wolf also serves on the board of directors of Airgas, Inc., where she serves on the audit committee. In addition, Ms. Wolf is on the board of directors of the Philadelphia Zoo.

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Name	Age		Office and Employment During Last Ten Years
Walter J. Lynch		49	Mr. Lynch has been our President and Chief Operating Officer of Regulated Operations since March 2010, and President of Regulated Operations since July 2008. Prior to that date, he served as Executive Vice President, Eastern Division. He also served as president of New Jersey- American Water Company, Inc., Long Island Water Corporation and our Northeast Region. Mr. Lynch joined us in 2001 and served as President of our Products and Services Group, where he was responsible for overseeing our market-based businesses. Prior to this, he was President of the Southwest Region of American Water Services. Mr. Lynch has more than 20 years of experience in engineering, sales and marketing, operations and business development. Before joining us, he was involved with various start-up and growth organizations in the environmental industry. Mr. Lynch worked for Mobil Oil Corporation following his departure from the United States Army where he attained the rank of Captain. In addition, Mr. Lynch is on the board of directors of the National Association of Water Companies and serves on its Executive Committee.
Kellye L. Walker		45	Ms. Walker has been our Chief Administrative Officer since September 2010, and Senior Vice President, General Counsel and Secretary since January 2010. From February 2007 to June 2009, Ms. Walker served as Senior Vice President and General Counsel of Diageo North America, Inc., the largest operating company of Diageo plc. From February 2003 to December 2006, Ms. Walker served as Senior Vice President, General Counsel and Secretary of BJ’s Wholesale Club, Inc., a leading warehouse club operator. Ms. Walker also served as a partner with the law firm of Hill & Barlow in Boston, Massachusetts, and as a partner and/or associate with the law firms of Chaffe, McCall, Phillips, Toler & Sarpy in New Orleans, Louisiana, and Boult, Cummings, Connors & Berry in Nashville, Tennessee.
Mark Chesla		52	Mr. Chesla has been our Vice President and Controller since November 2007. From 2001 to November 2007, Mr. Chesla was Vice President and Controller of Oglethorpe Power Corporation, in Atlanta, Georgia, where he served as that company’s chief accounting officer. In this capacity he was responsible for all aspects of the accounting, internal financial management, regulatory and SEC reporting functions. Mr. Chesla was Vice President, Administration/Controller of SouthStar Energy Services LLC, in Atlanta, Georgia, from 1998 to 2001. Earlier, he held management positions with several other companies, including Piedmont Natural Gas Co., Inc., Aegis Technologies, Inc., Deloitte & Touche LLP and Carolina Power & Light Company.

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Name	Age		Office and Employment During Last Ten Years
Mark F. Strauss		60	Mr. Strauss has been our Senior Vice President of Corporate Strategy and Business Development since September 2010. From December 2006, until his new appointment in September 2010, Mr. Straus was President of American Water Enterprises, managing our Market-Based Operations. Previously, Mr. Strauss was President and Chief Executive Officer of our Applied Water Management Group, which provides customized water and wastewater management solutions to real estate developers, industrial clients and small to midsized communities nationwide. Mr. Strauss joined Applied Water Management Group in 1997 as Corporate Counsel and Secretary. He was promoted to Chief Operating Officer in 2002, a position he held until his appointment as Division President and Chief Executive Officer in 2003. Earlier, he served as Vice President and General Counsel of Vizzoni Brothers Construction, Inc. Mr. Strauss serves as a director of Skylands Community Bank. Mr. Strauss was also an associate at the law firms of Ozzard, Rizzolo, Klein, Mauro & Savo and Toolan, Romond, Abbot and Domenichetti.
Nick O. Rowe		54	Mr. Rowe has been Senior Vice President of our Central Division since November 2011. From January 2009 until his new appointment in November 2011, he was Senior Vice President of our Eastern Division and from 2006 to January 2010, he was President of Kentucky-American Water Company. From 2005 to 2006, he served as Vice President of Service Delivery Operations for the Southeast Region of Kentucky-American Water Company. From 2003 to 2005, he served as Vice President, Business Change for American Water in New Jersey and from 1998 to 2003, Mr. Rowe was Vice President of Operations for Kentucky-American Water Company. From 1987 to 1998, he served in various management positions with responsibility for the day-to-day operations of American Water facilities in several states including Virginia, West Virginia, and Pennsylvania. Mr. Rowe is involved with various regulatory agencies and civic and professional organizations. He is also a member of the American Water Works Association and the National Association of Water Companies.
Kathy L. Pape		59	Ms. Pape has been our Senior Vice President, Mid-Atalntic Division since November 2011 and President of Pennsylvania-American Water Company since July 2007. From 1999 to 2007, Ms. Pape served as Senior Vice President, Treasurer and Rate Counsel for Aqua America, Inc. with responsibility for all financing activities, billing, rates and regulatory filings, budgeting and long-range planning. From 1994 to 1999, Ms. Pape was employed by us as Regional Counsel and Finance Manager, where her responsibilities included rates and regulatory affairs, finance, budgeting and customer service for 10 states. Prior to 1994, Ms. Pape was Vice President and Corporate Counsel for General Waterworks Management and Service Co., Assistant Counsel to the Pennsylvania Public Utility Commission and Assistant Consumer Advocate for the Pennsylvania Office of Consumer Advocate.

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Name	Age		Office and Employment During Last Ten Years
William D. Rogers		51	Mr. Rogers has been our Vice President and Treasurer since October 2010. From 2005 to 2010, he was Chief Financial Officer for NV Energy, an investor-owned utility in Las Vegas, Nevada. From 2005 to 2007, he also served as NV Energy’s Vice Presient of Finance, Risk and Tax and as Corporate Treasurer. Before joining NV Energy, Mr. Rogers was a managing director of capital markets for both Merrill Lynch and JPMorgan Chase in New York.
John R. Bigelow		57	Mr. Bigelow has been our Senior Vice President of Business Services since November 2011. From 2007 until his new appointment in November 2011, he was President of New Jersey-American Water Company, Inc.. Mr. Bigelow joined American Water in 1994 and held a number of senior management positions during his tenure, including American Water’s Senior Vice President of Regulatory Programs and Enterprise Risk Management. From December 2003 to February 2006, Mr. Bigelow served as American Water’s Chief Financial Officer, Vice President and Treasurer of New Jersey American Water, and Director, Vice President and Treasurer of New Jersey American Resources Co. Mr. Bigelow began his career with GPU System Companies, where he spent 18 years in various leadership roles in the finance area. Mr. Bigelow is also a board and/or committee member of Drexel MBA Career Services Advisory Board, New JerseyAmerican Water Company, Inc., William J. Hughes Center for Public Policy, and NJUA (New Jersey Utilities Association).
Sharon Cameron		55	Ms. Cameron has been president of American Water Enterprises, the market based products and services division of American Water, since September 2010. She also serves as President of American Water Resources, Inc., a business she has been leading since 2002. Prior to joining American Water, Ms. Cameron was principal of Marketing Solutions, a marketing consulting firm she launched in 1998, and was a consultant to American Water on the Homeowner Services business. Previously, Ms. Cameron served as vice president of Marketing and Sales at Comcast Corporation (New Jersey), senior marketing manager at Menley & James Laboratories, and marketing manager at Campbell Soup Company.
David K. Baker		55	Mr. Baker has been President of New Jersey-American Water Company, Inc. and Senior Vice President of the Northeast Division since November 2011. From March 2010 until his new appointment in November 2011, he was the Senior Vice President of our Western Division. Mr. Baker joined American Water in 1995, and most recently served as President of both Indiana-American Water and Michigan-American Water from January 2007 until March 2010. His previous leadership roles included serving as Vice President of Business Development for the Central Region and Eastern Division Manager for Illinois-American Water. Prior to joining American Water, Mr. Baker served as Division President/General Manager of Waste Management of Kentucky for ten years.
Emily A. Ashworth		37	Ms. Ashworth has been our Vice President and Chief Information Officer since December 2007. Prior to joining American Water, Ms. Ashworth was a Partner with Computer Science Corporation’s (CSC) Consulting Group. From June 2004 to July 2007, Ms. Ashworth served as a director of Business Process Integration for Pulte Homes. She also held positions with Westinghouse Power Generation Corp., and was a direct contractor for SuperVision International and the U.S. Naval Air Warfare Systems Simulation Training Division.

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Name	Age	Office and Employment During Last Ten Years
Maureen Duffy	42	Ms. Duffy has been our Vice President of Corporate Communications and External Affairs since September 2011. From June 2011 to September 2011, Ms. Duffy served as the Executive Director of Corporate Communications and External Affairs. From September 2008 to June 2011, Ms. Duffy served as Director of External Communications, and from July 2006 until September 2008, she served as Director of Internal Communication. From November 1999 to July 2006, she held various positions with New Jersey American Water, which included Government Affairs/Media Specialist, Communications Manager and Director of Corporate Communications. Prior to joining American Water, Ms. Duffy reported and produced news for WNJN/WNET-TV

ITEM 11. EXECUTIVE COMPENSATION

Information required by this item is incorporated by reference in the Company’s Proxy Statement for the 2012 Annual Meeting of Stockholders, under the captions entitled “Executive Compensation,” “Compensation Discussion and Analysis,” “Compensation Committee Report” and “Director Compensation.”

ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS

Information required by this item setting forth the security ownership of certain beneficial owners and management is incorporated by reference in the Company’s Proxy Statement for the 2012 Annual Meeting of Stockholders, under the caption entitled “Security Ownership of Principal Stockholders and Management” and the “Equity Compensation Plan” table appearing under the caption “Long-Term Equity Incentive Compensation.”

ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS AND DIRECTOR INDEPENDENCE

Information required by this item is incorporated by reference in the Company’s Proxy Statement for the 2012 Annual Meeting of Stockholders, under the captions entitled “Certain Relationships and Related Transactions” and “Director Independence.”

ITEM 14. PRINCIPAL ACCOUNTANT FEES AND SERVICES

Information required by this item is incorporated by reference in the Company’s Proxy Statement for the 2012 Annual Meeting of Stockholders, under the caption entitled “Independent Registered Public Accounting Fees and Services.”

ITEM 15. EXHIBITS AND FINANCIAL STATEMENT SCHEDULES

Financial statement schedules have been omitted since they are either not required or are not applicable as the information is otherwise included in the financial statements or notes thereto.

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SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized, on the 28th day of February, 2012.

AMERICAN WATER WORKS COMPANY, INC.
BY:	/S/    JEFFRY STERBA
	Jeffry Sterba
	President and Chief Executive Officer

Pursuant to the requirements of the Securities Exchange Act of 1934, this Annual Report on Form 10-K has been signed on the 28th day of February, 2012 by the following persons in the capacities indicated.

/S/    JEFFRY STERBA	/s/    RICHARD R. GRIGG
Jeffry Sterba President and Chief Executive Officer (Principal Executive Officer and Director)	Richard R. Grigg (Director)
/s/    ELLEN C. WOLF	/s/    JULIA L. JOHNSON
Ellen C. Wolf Senior Vice President and Chief Financial Officer (Principal Financial and Accounting Officer)	Julia L. Johnson (Director)
/s/    GEORGE MACKENZIE	/s/    WILLIAM J. MARRAZZO
George MacKenzie (Director)	William J. Marrazzo (Director)
/s/    MARTHA CLARK GOSS	/s/    STEPHEN P. ADIK
Martha Clark Goss (Director)	Stephen P. Adik (Director)
/s/    JULIE A. DOBSON
Julie A. Dobson (Director)

143

EXHIBIT INDEX

Exhibit Number	Exhibit Description
2.1	Agreement and Plan of Merger, dated as of September 16, 2001, among RWE Aktiengesellschaft, Thames Water Aqua Holdings GmbH, Apollo Acquisition Company and American Water Works Company, Inc. (incorporated by reference to Exhibit 2.1 to American Water Works Company, Inc.’s Registration Statement on Form S-1, File No. 333-145725, filed March 6, 2008).
2.2	Separation Agreement by and among RWE Aktiengesellschaft and American Water Works Company, Inc. (incorporated by reference to Exhibit 2.2 to American Water Works Company, Inc.’s Registration Statement on Form S-1, File No. 333-145725, filed March 6, 2008).
3.1	Restated Certificate of Incorporation of American Water Works Company, Inc. (incorporated by reference to Exhibit 3.1 to American Water Works Company, Inc.’s Quarterly Report on Form 10-Q, File No. 001-34028, filed November 6, 2008.)
3.2	Amended and Restated Bylaws of American Water Works Company, Inc. (incorporated by reference to Exhibit 3.2 to American Water Works Company, Inc.’s Form 8-K, File No. 001-34028, filed January 5, 2010).
4.1	Indenture, dated as of October 22, 2007 between American Water Capital Corp. and Wells Fargo Bank, National Association (incorporated by reference to Exhibit 4.4 to American Water Capital Corp.’s Registration Statement on Form S-4, File No. 333-148284, and American Water Works Company, Inc.’s Registration Statement on Form S-4, File No. 333-148284-01, filed December 21, 2007).
4.2	Indenture between American Water Capital Corp. and Wells Fargo Bank, National Association (incorporated by reference to Exhibit 4.1 to American Water Works Company, Inc.’s Form 8-K, File No. 001-34028, filed December 3, 2008).
4.3	Indenture, dated as of December 4, 2009, between American Water Capital Corp. and Wells Bank, National Association (incorporated by reference to Exhibit 4.1 to American Water Works Company, Inc.’s Form 8-K, file No. 001-34028, filed December 3, 2010).
4.4	Note Purchase Agreement, as amended, dated as of December 21, 2006, by and between American Water Capital Corp. and the Purchasers named therein for purchase of $101,000,000 5.39% Series A Senior Notes due 2013, $37,500,000 5.52% Series B Senior Notes due 2016, $329,500,000 5.62% Series C Senior Notes due 2018 and $432,000,000 5.77% Series D Senior Notes due 2021 (incorporated by reference to Exhibit 4.2 to American Water Capital Corp.’s Registration Statement on Form S-1, File No. 333-145757-01, and American Water Works Company, Inc.’s Registration Statement on Form S-1, File No. 333-145757, filed October 11, 2007).
4.5	Note Purchase Agreement, as amended, dated as of March 29, 2007, by and between American Water Capital Corp. and the Purchasers named therein for purchase of $100,000,000 5.62% Series E Senior Notes due 2019 and $100,000,000 5.77% Series F Senior Notes due 2022 (incorporated by reference to Exhibit 4.3 to American Water Capital Corp.’s Registration Statement on Form S-1, File No. 333-145757-01, and American Water Works Company, Inc.’s Registration Statement on Form S-1, File No. 333-145757, filed October 11, 2007).
4.6	Note Purchase Agreement, dated May 15, 2008, by and between AWCC and the Purchasers named therein for purchase of $110,000,000 6.25% Series G Senior Notes due 2018 and $90,000,000 6.55% Series H Senior Notes due 2023 (incorporated herein by reference to Exhibit 10.1 to American Water Works Company, Inc.’s Current Report on Form 8-K, File No. 001-34028, filed on May 19, 2008).

144

Exhibit Number	Exhibit Description
9.1	Exchange and Registration Rights Agreement, dated as of October 22, 2007, between American Water Capital Corp., American Water Works Company, Inc. and Citigroup Global Markets Inc, Credit Suisse Securities (USA) LLC, Goldman, Sachs & Co. and Merrill Lynch, Pierce, Fenner & Smith Incorporated, as representatives of the several purchasers (incorporated by reference to Exhibit 4.4 to American Water Capital Corp.’s Registration Statement on Form S-4, File No. 333-148284, and American Water Works Company, Inc.’s Registration Statement on Form S-4, File No. 333-148284-01, filed December 21, 2007).
9.2	Registration Rights Agreement by and among American Water Works Company, Inc., RWE Aktiengesellschaft and RWE Aqua Holdings GmbH (incorporated by reference to Exhibit 9.1 to American Water Works Company, Inc.’s Registration Statement on Form S-1, File No. 333-145725, filed March 6, 2008).
10.1	Agreement between George W. Patrick and American Water Works Company, Inc., dated August 27, 1999 (incorporated by reference to Exhibit 10.1 to American Water Works Company, Inc.’s Form 10-K, File No. 001-34028, filed March 1, 2010).
10.2A	Change in Control Agreement between George W. Patrick and American Water Works Company, Inc., dated January 1, 2000 (incorporated by reference to Exhibit 10.2A to American Water Works Company, Inc.’s Form 10-K, File No. 001-34028, filed March 1, 2010).
10.2B	First Amendment to Change in Control Agreement between George W. Patrick and American Water Works Company, Inc., dated May 24, 2004 (incorporated by reference to Exhibit 10.2B to American Water Works Company, Inc.’s Form 10-K, File No. 001-34028, filed March 1, 2010).
10.2C	Second Amendment to Change in Control Agreement between George W. Patrick and American Water Works Company, Inc., dated July 27, 2005 (incorporated by reference to Exhibit 10.2C to American Water Works Company, Inc.’s Form 10-K, File No. 001-34028, filed March 1, 2010).
10.2D	Third Amendment to Change in Control Agreement between George W. Patrick and American Water Works Company, Inc., dated December 19, 2008 (incorporated by reference to Exhibit 10.2D to American Water Works Company, Inc.’s Form 10-K, File No. 001-34028, filed March 1, 2010).
10.3	Credit Agreement, dated as of September 15, 2006, among American Water Capital Corp., the Lenders identified therein and JPMorgan Chase Bank, N.A (incorporated by reference to Exhibit 10.1 to American Water Capital Corp.’s Registration Statement on Form S-1, File No. 333-145757-01, American Water Works Company, Inc.’s Registration Statement on Form S-1, File No. 333-145757, filed October 11, 2007 and American Water Works Company, Inc.’s Form 10-Q, File No. 001-34028, filed August 4, 2010).
10.4	Support Agreement, as subsequently amended, dated June 22, 2000, by and between American Water Works Company, Inc. and American Water Capital Corp. (incorporated by reference to Exhibit 10.3 to American Water Capital Corp.’s Registration Statement on Form S-1, File No. 333-145757-01, and American Water Works Company, Inc.’s Registration Statement on Form S-1, File No. 333-145757, filed October 11, 2007).
10.5	Amendment 2011-1 to the Pension Plan for Employees of American Water Works Company, Inc. and Its Designated Subsidiaries (incorporated by reference to Exhibit 10.1 to American Water Works Company, Inc.’s Form 10-Q, File No. 001-34028, filed August 3, 2011).
10.6	Employment Agreement between Ellen C. Wolf and American Water Works Company, Inc., dated February 15, 2008 (incorporated by reference to Exhibit 10.5 to American Water Works Company, Inc.’s Registration Statement on Form S-1, File No. 333-145725, filed March 6, 2008).
10.7	Employment Agreement between Jeffry E. Sterba and American Water Works Company, Inc., dated August 15, 2010 (incorporated by reference to Exhibit 99.1 to American Water Works Company, Inc.’s Form 8-K, File No. 001-34028, filed August 17, 2010).

145

Exhibit Number	Exhibit Description
10.8	Employment Agreement between Kellye L. Walker and American Water Works Company, Inc., dated December 21, 2009 (incorporated by reference to Exhibit 10.2 to American Water Works Company, Inc.’s Form 10-Q, File No. 001-34028, filed May 4, 2011).
10.9	Separation and General Release Agreement between American Water Works Company, Inc. and Donald L. Correll, dated August 15, 2010 (incorporated by reference to Exhibit 99.2 to American Water Works Company, Inc.’s Form 8-K, File No. 001-34028, filed August 17, 2010).
10.10	Amended and Restated American Water Works Company, Inc. Executive Retirement Plan, dated as of March 1, 2007 (incorporated by reference to Exhibit 10.8 to American Water Capital Corp.’s Registration Statement on Form S-1, File No. 333-145757-01, and American Water Works Company, Inc.’s Registration Statement on Form S-1, File No. 333-145757, filed October 11, 2007).
10.11	Amended and Restated American Water Works Company, Inc. Deferred Compensation Plan, dated as of January 1, 2001 (incorporated by reference to Exhibit 10.9 to American Water Capital Corp.’s Registration Statement on Form S-1, File No. 333-145757-01, and American Water Works Company, Inc.’s Registration Statement on Form S-1, File No. 333-145757, filed October 11, 2007).
10.12	Settlement Agreement by and between California American Water Company and the U.S. Department of Commerce, National Oceanic and Atmospheric Administration, dated as of June 29, 2006 (incorporated by reference to Exhibit 10.12 to American Water Works Company, Inc.’s Registration Statement on Form S-1, File No. 333-145725, filed March 6, 2008).
10.13	Amended and Restated American Water Works Company, Inc. Nonqualified Employee Stock Purchase Plan, dated as of December 10, 2010 (incorporated by reference to Exhibit 10.12 to American Water Works Company, Inc.’s Form 10-K, File No. 001-34028, filed February 25, 2011).
10.14	American Water Works Company, Inc. Executive Severance Policy, dated as of December 16, 2008 (incorporated by reference to Exhibit 10.1 to American Water Works Company, Inc.’s Form 10-Q, File No. 001-34028, filed November 3, 2010).
10.15	2006 American Water Senior Management Annual Incentive Plan (incorporated by reference to Exhibit 10.21 to American Water Capital Corp.’s Registration Statement on Form S-1, File No. 333-145757-01, and American Water Works Company, Inc.’s Registration Statement on Form S-1, File No. 333-145757, filed October 11, 2007).
10.16	American Water Works Company, Inc. 2007 Omnibus Equity Compensation Plan (incorporated by reference to Exhibit 10.22 to American Water Works Company, Inc.’s Registration Statement on Form S-1, File No. 333-145725, filed March 31, 2008).
10.17	Nonqualified Savings and Deferred Compensation Plan for Employees of American Water Works Company, Inc. and its Designated Subsidiaries (incorporated by reference to Exhibit 10.23 to American Water Works Company, Inc.’s Registration Statement on Form S-1, File No. 333-145725, filed March 26, 2008).
10.18	Nonqualified Deferred Compensation Plan for Non-Employee Directors of American Water Works Company, Inc. (incorporated by reference to Exhibit 10.24 to American Water Works Company, Inc.’s Registration Statement on Form S-1, File No. 333-145725, filed March 26, 2008).
10.19	2008 American Water Senior Management Annual Incentive Plan (incorporated by reference to Exhibit 10.25 to American Water Works Company, Inc.’s Registration Statement on Form S-1, File No. 333-145725, filed April 15, 2008).
10.20	2009 American Water Senior Management Annual Incentive Plan (incorporated by reference to Exhibit 10.1 to American Water Works Company, Inc.’s Current Report on Form 8-K, File No. 001-34028, filed February 26, 2009).

146

Exhibit Number	Exhibit Description
10.21	2010 American Water Annual Incentive Plan Highlights Brochure (incorporated by reference to Exhibit 10.2 to American Water Works Company, Inc.’s Form 10-Q, File No. 001-34028, filed August 4, 2010).
10.22	2011 American Water Annual Incentive Plan Highlights Brochure (incorporated by reference to Exhibit 10.1 to American Water Works Company, Inc.’s Form 10-Q, File No. 001-34028, filed May 4, 2011).
10.23	American Water Works Company, Inc. 2007 Omnibus Equity Compensation Plan First Restricted Stock Unit Grant Form for ML1-ML3 Employees (incorporated by reference to Exhibit 10.26 to American Water Works Company, Inc.’s Registration Statement on S-4/A, filed on May 6, 2008).
10.24	American Water Works Company, Inc. 2007 Omnibus Equity Compensation Plan First Restricted Stock Unit Grant Form for ML4 Employees (incorporated by reference to Exhibit 10.27 to American Water Works Company, Inc.’s Registration Statement on S-4/A, filed on May 6, 2008).
10.25	American Water Works Company, Inc. 2007 Omnibus Equity Compensation Plan Restricted Stock Unit Grant Form for Directors (incorporated by reference to Exhibit 10.28 to American Water Works Company, Inc.’s Registration Statement on S-4/A, filed on May 6, 2008).
10.26	American Water Works Company, Inc. 2007 Omnibus Equity Compensation Plan Second Restricted Stock Unit Grant Form for ML1-ML3 Employees (incorporated by reference to Exhibit 10.29 to American Water Works Company, Inc.’s Registration Statement on S-4/A, filed May 6, 2008).
10.27	American Water Works Company, Inc. 2007 Omnibus Equity Compensation Plan Second Restricted Stock Unit Grant Form for ML4 Employees (incorporated by reference to Exhibit 10.30 to American Water Works Company, Inc.’s Registration Statement on S-4/A, filed May 6, 2008).
10.28	American Water Works Company, Inc. 2007 Omnibus Equity Compensation Plan First Nonqualified Stock Option Grant Form for ML1-ML3 Employees (incorporated by reference to Exhibit 10.31 to American Water Works Company, Inc.’s Registration Statement on S-4/A, filed May 6, 2008).
10.29	American Water Works Company, Inc. 2007 Omnibus Equity Compensation Plan First Nonqualified Stock Option Grant Form for ML4 Employees (incorporated by reference to Exhibit 10.32 to American Water Works Company, Inc.’s Registration Statement on S-4/A, filed May 6, 2008).
10.30	American Water Works Company, Inc. 2007 Omnibus Equity Compensation Plan Nonqualified Stock Option Grant Form for Directors (incorporated by reference to Exhibit 10.33 to American Water Works Company, Inc.’s Registration Statement on S-4/A, filed May 6, 2008).
10.31	American Water Works Company, Inc. 2007 Omnibus Equity Compensation Plan Second Nonqualified Stock Option Grant Form for ML1-ML3 Employees (incorporated by reference to Exhibit 10.34 to American Water Works Company, Inc.’s Registration Statement on S-4/A, filed May 6, 2008).
10.32	American Water Works Company, Inc. 2007 Omnibus Equity Compensation Plan Second Nonqualified Stock Option Grant Form for ML4 Employees (incorporated by reference to Exhibit 10.34 to American Water Works Company, Inc.’s Registration Statement on S-4/A, filed May 6, 2008).
10.33	American Water Works Company, Inc. 2007 Omnibus Equity Compensation Plan 2009 Performance Stock Unit Grant Form for ML1-ML3B Employees (incorporated by reference to Exhibit 10.36 to American Water Works Company, Inc.’s Annual Report on Form 10-K, File No. 001-34028, filed February 27, 2009).

147

Exhibit Number	Exhibit Description
10.34	American Water Works Company, Inc. 2007 Omnibus Equity Compensation Plan 2009 Performance Stock Unit Grant Form for ML4-ML5 Employees (incorporated by reference to Exhibit 10.37 to American Water Works Company, Inc.’s Annual Report on Form 10-K, File No. 001-34028, filed February 27, 2009).
10.35	American Water Works Company, Inc. 2007 Omnibus Equity Compensation Plan 2009 Nonqualified Stock Option Grant Form for ML1-ML3B Employees (incorporated by reference to Exhibit 10.4 to American Water Works Company, Inc.’s Current Report on Form 8-K, File No. 001-34028, filed February 26, 2009).
10.36	American Water Works Company, Inc. 2007 Omnibus Equity Compensation Plan 2009 Nonqualified Stock Option Grant Form for ML4-ML5 Employees (incorporated by reference to Exhibit 10.5 to American Water Works Company, Inc.’s Current Report on Form 8-K, File No. 001-34028, filed February 26, 2009).
10.37	American Water Works Company, Inc. 2007 Omnibus Equity Compensation Plan 2009 Stock Unit Grant Form for Non-Employee Directors (incorporated by reference to Exhibit 10.2 to American Water Works Company, Inc.’s Quarterly Report on Form 10-Q, File No. 001-34028, filed August 6, 2009).
10.38	American Water Works Company, Inc. 2007 Omnibus Equity Compensation Plan 2010 Performance Stock Unit Grant Form A for ML1-ML5 Employees (incorporated by reference to Exhibit 10.1 to American Water Works Company, Inc.’s Form 10-Q, File No. 001-34028, filed May 4, 2010).
10.39	American Water Works Company, Inc. 2007 Omnibus Equity Compensation Plan 2010 Performance Stock Unit Grant Form B for ML1-ML5 Employees (incorporated by reference to Exhibit 10.1 to American Water Works Company, Inc.’s Form 10-Q, File No. 001-34028, filed May 4, 2010).
10.40	American Water Works Company, Inc. 2007 Omnibus Equity Compensation Plan 2010 Performance Stock Unit Grant Form C for ML1-ML5 Employees (incorporated by reference to Exhibit 10.1 to American Water Works Company, Inc.’s Form 10-Q, File No. 001-34028, filed May 4, 2010).
10.41	American Water Works Company, Inc. 2007 Omnibus Equity Compensation Plan 2010 Nonqualified Stock Option Grant for ML1-ML5 Employees (incorporated by reference to Exhibit 10.1 to American Water Works Company, Inc.’s Form 10-Q, File No. 001-34028, filed May 4, 2010).
10.42	American Water Works Company, Inc. 2007 Omnibus Equity Compensation Plan 2010 Form of Stock Unit Grant Agreement for Non-Employee Directors (incorporated by reference to Exhibit 10.3 to American Water Works Company, Inc.’s Form 10-Q, File No. 001-34028, filed August 4, 2010).
10.43	American Water Works Company, Inc. 2007 Omnibus Equity Compensation Plan September 2010 Form of Stock Unit Grant Agreement for Non-Employee Directors (incorporated by reference to American Water Works Company, Inc.’s Form 10-Q, File No. 001-34028, filed November 3, 2010)
10.44	American Water Works Company, Inc. 2007 Omnibus Equity Compensation Plan 2011 Nonqualified Stock Option Grant for ML1 – L5 Employees (incorporated by reference to Exhibit 10.3 to American Water Works Company, Inc.’s Form 10-Q, File No. 001-34028, filed May 4, 2011).
10.45	American Water Works Company, Inc. 2007 Omnibus Equity Compensation Plan 2011 Performance Stock Unit Grant Form A for ML1 – L5 (incorporated by reference to Exhibit 10.4 to American Water Works Company, Inc.’s Form 10-Q, File No. 001-34028, filed May 4, 2011).
10.46	American Water Works Company, Inc. 2007 Omnibus Equity Compensation Plan 2011 Performance Stock Unit Grant Form B for ML1 – L5 (incorporated by reference to Exhibit 10.5 to American Water Works Company, Inc.’s Form 10-Q, File No. 001-34028, filed May 4, 2011).

148

Exhibit Number	Exhibit Description
10.47	American Water Works Company, Inc. 2007 Omnibus Equity Compensation Plan 2011 Form of Stock Unit Grant Agreement for Non-Employee Directors (incorporated by reference to Exhibit 10.2 to American Water Works Company, Inc.’s Form 10-Q, File No. 001-34028, filed August 3, 2011).
10.48	Amendment to the Nonqualified Savings and Deferred Compensation Plan for Employees of American Water Works Company, Inc. and its Designated Subsidiaries, effective as of August 1, 2008 (incorporated by reference to Exhibit 10.1 to American Water Works Company, Inc.’s Quarterly Report on Form 10-Q, File No. 001-34028, filed November 6, 2008.)
10.49	Nonqualified Savings and Deferred Compensation Plan for Employees of American Water Works Company, Inc. and Its Designated Subsidiaries, as amended and restated, effective as of January 1, 2009 (incorporated by reference to Exhibit 10.37 to American Water Works Company, Inc.’s Registration Statement on Form S-1, File No. 333-155245, filed November 18, 2008).
10.50	Nonqualified Deferred Compensation Plan for Non-Employee Directors of American Water Works Company, Inc., as amended and restated, effective as of January 1, 2009 (incorporated by reference to Exhibit 10.38 to American Water Works Company, Inc.’s Registration Statement on Form S-1, File No. 333-155245, filed November 18, 2008).
10.51	Amendment to the Nonqualified Savings and Deferred Compensation Plan for Employees of American Water Works Company, Inc. and its Designated Subsidiaries, effective as of February 6, 2009 (incorporated by reference to Exhibit 10.7 to American Water Works Company, Inc. Current Report on Form 8-K, File No. 001-34028, filed February 26, 2009)
10.52	Amendment to the Nonqualified Deferred Compensation Plan for Non-Employee Directors of American Water Works Company, Inc., effective as of February 6, 2009 (incorporated by reference to Exhibit 10.8 to American Water Works Company, Inc. Current Report on Form 8-K, File No. 001-34028, filed February 26, 2009)
10.53	American Water Works Company, Inc. 2007 Omnibus Equity Compensation Plan Stock Unit Grant Form for Non-Employee Directors (incorporated by reference to Exhibit 10.2 to American Water Works Company, Inc.’s Quarterly Report on Form 10-Q, File No. 001-34028, filed August 6, 2009).
*21.1	Subsidiaries of American Water Works Company, Inc.
*23.1	Consent of PricewaterhouseCoopers LLP.
*31.1	Certification of Jeffry E. Sterba, President and Chief Executive Officer, pursuant to Section 302 of the Sarbanes-Oxley Act.
*31.2	Certification of Ellen C. Wolf, Senior Vice President and Chief Financial Officer, pursuant to Section 302 of the Sarbanes-Oxley Act.
*32.1	Certification of Jeffry E. Sterba, President and Chief Executive Officer, pursuant to Section 906 of the Sarbanes-Oxley Act.
*32.2	Certification of Ellen C. Wolf, Senior Vice President and Chief Financial Officer, pursuant to Section 906 of the Sarbanes-Oxley Act.
101	The following financial statements from American Water Works Company, Inc.’s Annual Report on Form 10-K for the period ended December 31, 2011, filed with the Securities and Exchange Commission on February 24, 2012, formatted in XBRL (eXtensible Business Reporting Language): (i) the Consolidated Balance Sheets; (ii) the Consolidated Statements of Operations and Comprehensive Income; (iii) the Consolidated Statements of Cash Flows; (iv) the Consolidated Statements of Changes in Stockholders’ Equity; and (v) the Notes to Consolidated Financial Statements.

* filed herewith

149

EX-21.1

EXHIBIT 21.1

American Water Works Company, Inc. and its Subsidiaries Ownership Schedule

As of February 21, 2012

Subsidiaries of      American Water	Nature of Legal     Organization	Jurisdiction of    Incorporation or Formation	Percentage of Equity Interest     held directly or indirectly by American Water	Line of Business
AAET, Inc.	Corporation	Delaware	100% held through American Water Enterprises, Inc.	General Partner of AAET, L.P.
American Lake Water Company	Corporation	Illinois	100% held through American Water	Water pipeline company
American Water – Acciona Agua LLC	Limited Liability Company	Delaware	50% held through American Water Enterprises, Inc.; 50% outside ownership by Acciona Agua Corporation (USA)	Joint Venture entity, which contracts with Tampa Bay to remedy, operate and manage the Tampa Bay Seawater Desalination Plant.
American Water Canada Corp.	Corporation	Ontario	100% held through American Water Enterprises Holding, Inc.	Holds contracts for operation and maintenance of water and/or wastewater facilities in Canada
American Water Capital Corp.	Corporation	Delaware	100% held through American Water	Funding vehicle for AWW and its utility subsidiaries
American Water Carbon Services Corp.	Corporation	Ontario	100% held through American Water Canada Corp.	Supplies carbon regeneration materials to water facilities in Canada
American Water Engineering, Inc.	Corporation	New Jersey	100% held through American Water (USA), Inc.	Inactive
American Water Enterprises Holding, Inc.	Corporation	Delaware	100% held through American Water Enterprises, Inc.	Holding company for many AWE subsidiaries in the US; Holds contract to operate and maintain Jefferson Parish, LA East Bank wastewater treatment plant
American Water Enterprises, Inc.	Corporation	Delaware	100% held through American Water	Holding company for the non-regulated business; Has some contracts due to historical reasons
American Water Industrials, Inc.	Corporation	Delaware	100% held through American Water Enterprises, Inc.	Holding company
American Water Operations and Maintenance, Inc.	Corporation	Texas	100% held through American Water (USA), Inc.	Primary entity for contracts for design, building and/or operation of water and wastewater facilities and operations, maintenance and management of water and wastewater facilities in the US
American Water Resources, Inc.	Corporation	Virginia	100% held through American Water	a) Homeowner Services Group – water line and sewer line protection programs b) Carbon Services – reactivates spent carbon c) Leasing (NOT managed by AWEG)

Subsidiaries of      American Water	Nature of Legal     Organization	Jurisdiction of    Incorporation or Formation	Percentage of Equity Interest     held directly or indirectly by American Water	Line of Business
American Water Resources Holdings, Inc.	Corporation	Delaware	Wholly owned subsidiary of American Water (USA), Inc.	Holding company
American Water Resources of Texas, Inc.	Corporation	Delaware	Wholly owned subsidiary of American Water Resources Holdings, Inc.	Entity allows for the sale of service contracts in the state of Texas.
American Water Services CDM, Inc.	Corporation	Washington	80% held through American Water (USA), Inc.; 20% outside common stock held by Camp Dresser and McKee, Inc.	Joint venture operating the Tolt water treatment facility located in Seattle, WA
American Water Services Underground Infrastructure Corp.	Corporation	Ontario	100% held through American Water Canada Corp.	Current contracts for closed circuit television inspection of water and/or wastewater pipes
American Water (USA), Inc.	Corporation	Delaware	100% held through American Water Enterprises Holding, Inc.	Holding company
American Water Works Company, Inc.	Corporation	Delaware	100% held through AMERICAN WATER	Water and Wastewater-related product and services
American Water Works Service Company, Inc.	Corporation	Delaware	100% held through American Water	Professional water and/or wastewater services
American Water Services LLC	Limited Liability Company	New Jersey	100% held through American Water	Holding Company
AW Contract Services Holding, Inc.	Corporation	Delaware	100% held through AWE	Holding Company
AW Contract Services (USA), Inc.	Corporation	Delaware	100% held through AW Contract Services Holding, Inc.	Current contracts for water and/or wastewater services
AW Contract Services (Canada), Inc.	Corporation	Federal Canada	100% held through AW Contract Services Holding, Inc.	Current contracts for water and/or wastewater services
AW Technologies Incorporated	Corporation	Delaware	100% held through AWE	Water and/or wastewater services using emerging technologies
Bluefield Valley Water Works Company	Corporation	Virginia	100% held through West Virginia-American Water Company	Water and/or wastewater utility
Braemar Acres Limited	Corporation	Ontario	100% held through Uniflo Limited	Currently owns real property for storage of lime materials used by Terratec Environmental Ltd. in Canada
California – American Water Company	Corporation	California	100% held through American Water	Water and/or wastewater utility

Subsidiaries of      American Water	Nature of Legal     Organization	Jurisdiction of    Incorporation or Formation	Percentage of Equity Interest     held directly or indirectly by American Water	Line of Business
EMC American Water Canada, Inc.	Corporation	Canada (Federal Corporation)	100% held through American Water Canada Corp.	Operation and maintenance of water and wastewater facilities in Canada.
E’town LLC	Limited liability company	Delaware	100% held through TWH LLC	Holding company
E’town Properties, Inc.	Corporation	Delaware	100% held through American Water Works Company, Inc.	Set up by Elizabethtown Water Company entity to hold real estate for development and/or sale
E’town Services, LLC	Limited Liability Company	New Jersey	100% held through AWE	Holds wastewater services contract among E’town Corp, Elizabeth, NJ and the Union County Improvement Authority
Edison Water Company	Corporation	New Jersey	100% held through AWE	Manage water contract for Township of Edison, NJ
EMC Batesville, LLC	Limited liability company	Missouri	100% held through EMC	Single purpose entity formed for improvements made to, and subsequent operation of, a wastewater treatment plant and water reuse system located in Batesville, Arkansas, as well as for the lease of related equipment used thereon.
EMC of St. Charles County, LLC	Limited liability company	Missouri	100% held through EMC	Regulated sewer utility providing sewer services to a residential development located in St. Charles County, Missouri.
Environmental Management Corp.	Corporation	New Jersey	100% held through AWE	Provides design, build and operation services for the water and wastewater assets of industrial firms and municipalities in the US and other countries.
Hawaii – American Water Company	Corporation	Nevada	100% held through American Water	Water and/or wastewater utility
Illinois – American Water Company	Corporation	Illinois	100% held through American Water (0.1% outside preferred stock)	Water and/or wastewater utility
Indiana – American Water Company	Corporation	Indiana	100% held through American Water	Water and/or wastewater utility
Iowa – American Water Company	Corporation	Delaware	100% held through American Water	Water and/or wastewater utility
Kentucky – American Water Company	Corporation	Kentucky	100% held through American Water	Water and/or wastewater utility
Laurel Oak Properties Corporation	Corporation	Delaware	100% held through American Water	Entity to hold real estate for development and/or sale

Subsidiaries of      American Water	Nature of Legal     Organization	Jurisdiction of    Incorporation or Formation	Percentage of Equity Interest     held directly or indirectly by American Water	Line of Business
Liberty Water Company	Corporation	New Jersey	100% held through AWE	Manage water contract for City of Elizabeth, NJ
Long Island Water Corporation	Corporation	New York	100% held through American Water	Water and/or wastewater utility
Maryland – American Water Company	Corporation	Maryland	100% held through American Water	Water and/or wastewater utility
Michigan – American Water Company	Corporation	Michigan	100% held through American Water	Water and/or wastewater utility
Missouri – American Water Company	Corporation	Missouri	100% held through American Water	Water and/or wastewater utility
Mobile Residuals Management Inc.	Corporation	Ontario	100% held through American Water Canada Corp.	Inactive
Mobile Residuals Management (USA), Inc.	Corporation	Delaware	100% held through American Water (USA), Inc	Mobile biosolids and residuals management; Ongoing contracts in CA and NJ
New Jersey – American Water Company	Corporation	New Jersey	100% held through American Water	Water and/or wastewater utility
Ohio – American Water Company	Corporation	Ohio	100% held through American Water	Water and/or wastewater utility
OMI/Thames Water Stockton, Inc.	Corporation	Delaware	50% held through TWNA, Inc. and 50% held through Operations and Management, Inc.	Water and/or wastewater services
Pennsylvania – American Water Company	Corporation	Pennsylvania	96.5% held through American Water (3.5% outside preferred stock)	Water and/or wastewater utility
Philip Automated Management Controls, Inc.	Corporation	Georgia	100% held through American Water (USA), Inc.	Inactive
Prism-Berlie (Windsor) Limited	Corporation	Ontario	100% held through Terratec Environmental Ltd.	Holds contract to operate pelitizing facility in Windsor, Ontario
Rialto Water Services, L.P.	Limited Partnership	Delaware	100% held through American Water (USA) and Rialto Water Services, Inc.	Rialto concession bid. Percentage will fall below 50% if transaction completed as a concession.
Tennessee – American Water Company	Corporation	Tennessee	99.89% held through American Water (0.11% outside preferred stock)	Water and/or wastewater utility
Terratec Environmental Ltd.	Corporation	Ontario	100% held through American Water Canada Corp.	Primary entity for holding contracts for biosolids management land application and disposal
Texas-American Water Company	Corporation	Texas	100% through American Water	Water and/or wastewater utility

Subsidiaries of      American Water	Nature of Legal     Organization	Jurisdiction of    Incorporation or Formation	Percentage of Equity Interest     held directly or indirectly by American Water	Line of Business
TWH LLC	Limited Liability Company	Delaware	100% held through American Water	Holding company
TWNA, Inc. formerly Thames Water North America, Inc.	Corporation	Delaware	100% held through American Water	Water and/or wastewater services
Uniflo Limited	Corporation	Ontario	100% held through Terratec Environmental Ltd.	Holding company
Virginia – American Water Company	Corporation	Virginia	100% held through American Water	Water and/or wastewater utility
West Virginia – American Water Company	Corporation	West Virginia	99.97% held through American Water (0.03% outside common stock)	Water and/or wastewater utility

EX-23.1

Exhibit 23.1

CONSENT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

We hereby consent to the incorporation by reference in the Registration Statements on Form S-8 (Nos.

333-168543 and 333-150381) and Form S-3 (Nos. 333-165624 and 333-158949) of American Water Works Company, Inc. of our report dated February 28, 2012 relating to the financial statements and the effectiveness of internal control over financial reporting, which appears in this Form 10-K.

/s/ PricewaterhouseCoopers LLP

Philadelphia, Pennsylvania

February 28, 2012

EX-31.1

Exhibit 31.1

CERTIFICATION OF PRINCIPAL EXECUTIVE OFFICER

I, Jeffry Sterba, certify that:

1. I have reviewed this annual report on Form 10-K of American Water Works Company, Inc.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the consolidated financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, 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;

c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a) all significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: February 28, 2012

By:	/s/    JEFFRY STERBA
	Jeffry Sterba
	President and Chief Executive Officer (Principal Executive Officer)

EX-31.2

Exhibit 31.2

CERTIFICATION OF PRINCIPAL FINANCIAL OFFICER AND CHIEF ACCOUNTING OFFICER

I, Ellen C. Wolf, certify that:

1. I have reviewed this annual report on Form 10-K of American Water Works Company, Inc.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the consolidated financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, 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;

c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a) all significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: February 28, 2012

By:	/S/    ELLEN C. WOLF
	Ellen C. Wolf
	Senior Vice President and Chief Financial Officer (Principal Financial and Accounting Officer)

EX-32.1

Exhibit 32.1

AMERICAN WATER WORKS COMPANY, INC.

CERTIFICATION PURSUANT TO

RULE 13a-14(b) UNDER THE SECURITIES EXCHANGE ACT AND

18 U.S.C. SECTION 1350,

I, Jeffry Sterba, President and Chief Executive Officer of American Water Works Company, Inc. (the “Company”), hereby certify that, based on my knowledge:

(1) The Company’s Annual Report on Form 10-K for the fiscal year ended December 31, 2011 (the “Report”) fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 as amended; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

By:	/S/    JEFFRY STERBA
	Jeffry Sterba President and Chief Executive Officer (Principal Executive Officer)

February 28, 2012

EX-32.2

Exhibit 32.2

AMERICAN WATER WORKS COMPANY, INC.

CERTIFICATION PURSUANT TO

RULE 13a-14(b) UNDER THE SECURITIES EXCHANGE ACT AND

18 U.S.C. SECTION 1350,

I, Ellen C. Wolf, Senior Vice President and Chief Financial Officer, of American Water Works Company, Inc. (the “Company”), hereby certify that, based on my knowledge:

(1) The Company’s Annual Report on Form 10-K for the fiscal year ended December 31, 2011 (the “Report”) fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 as amended; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

By:	/S/    ELLEN C. WOLF
	Ellen C. Wolf
	Senior Vice President and Chief Financial Officer (Principal Financial and Accounting Officer)

February 28, 2012

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Stockholders' Equity (Tables)

12 Months Ended

Dec. 31, 2011

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Summary Information Regarding Issuances Under DRIP

	2011		2010
Shares of common stock issued		64		63
Cash proceeds received	$	1,827	$	1,425

Cash Dividend Payment During Period

	2011		2010
Dividends per share, three months ended:
March 31	$	0.22	$	0.21
June 30		0.22		0.21
September 30		0.23		0.22
December 31		0.23		0.22
Total dividends paid, three months ended:
March 31	$	38,525	$	36,679
June 30		38,580		36,689
September 30		40,358		38,457
December 31		40,392		38,476

Schedule Of Accumulated Other Comprehensive Loss

	2011			2010
Employee benefit plans funded status adjustments	$	(101,457	)	$	(75,639	)
Foreign currency translation		3,780			4,193
Balance at December 31	$	(97,677	)	$	(71,446	)

Schedule Of Stock-Based Compensation Expense

	2011			2010			2009
Stock options	$	3,182		$	4,116		$	3,415
Restricted stock units		6,340			5,863			3,799
Employee stock purchase plan		486			355			388
Stock-based compensation in operation and maintenance expense		10,008			10,334			7,602
Income tax benefit		(3,903	)		(4,030	)		(2,965	)
After-tax stock-based compensation expense	$	6,105		$	6,304		$	4,637

Stock Option Activity

	Shares			Weighted Average Exercise Price (per share)		Weighted Average Remaining Life (years)		Aggregate Intrinsic Value
Options outstanding at January 1, 2011		2,870		$	21.38
Granted		736			27.08
Forfeited or expired		(71	)		23.27
Exercised		(423	)		21.27
Options outstanding at December 31, 2011		3,112		$	22.70		4.3	$	28,493
Exercisable at December 31, 2011		1,686		$	21.34		3.5	$	17,738

Weighted Average Assumptions Used

	2011			2010			2009
Expected volatility		29.50	%		30.74	%		32.00	%
Risk-free interest rate		1.24	%		1.50	%		1.30	%
Expected life (years)		3			3			3
Grant date fair value per share	$	29.95		$	23.23		$	21.75

Additional Information To Restricted Stock Activity

	Shares			Weighted Average Grant Date Fair Value (per share)
Nonvested total at January 1, 2011		479		$	22.60
Granted		205			29.95
Vested		(89	)		22.88
Forfeited		(18	)		25.28
Nonvested total at December 31, 2011		577		$	25.09

Stock Option [Member]

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Weighted Average Assumptions

	2011			2010			2009
Dividend yield		3.25	%		3.83	%		3.86	%
Expected volatility		29.32	%		31.77	%		31.67	%
Risk-free interest rate		1.93	%		2.14	%		1.79	%
Expected life (years)		4.35			4.29			4.36
Exercise price	$	27.08		$	22.01		$	20.70
Grant date fair value per share	$	5.14		$	4.33		$	3.96

Additional Information To Stock Options Activity

	2011		2010			2009
Intrinsic value	$	3,026	$	333		$	0
Exercise proceeds		8,991		3,010			0
Income tax benefit (shortfall)		511		(89	)		0

Restricted Stock Units [Member]

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Additional Information To Stock Options Activity

	2011		2010		2009
Intrinsic value	$	2,068	$	1,241	$	51
Income tax benefit (shortfall)		99		15		(2	)

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Fair Values Of Financial Instruments (Fair Value And Carrying Value Of Preferred Stocks And Long-Term Debt) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2011	Dec. 31, 2010
Fair Values Of Financial Instruments [Abstract]
Preferred stocks with mandatory redemption requirements, Carrying Amount	$ 22,036	$ 22,794
Long-term debt (excluding capital lease obligations), Carrying Amount	5,366,642	5,424,492
Preferred stocks with mandatory redemption requirements, Fair Value	26,458	25,475
Long-term debt (excluding capital lease obligations), Fair Value	$ 6,230,547	$ 5,841,448

XML

Utility Plant (Narrative) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Utility Plant [Abstract]
Depreciation expense	$ 268,987	$ 250,107	$ 237,741
Provision for depreciation, percentage of aggregate average depreciable asset	2.68%	2.62%	2.62%

XML

Segment Information (Tables)

12 Months Ended

Dec. 31, 2011

Dec. 31, 2010

Dec. 31, 2009

Segment Information [Abstract]

Summarized Segment Information

	As of or for the Year Ended December 31, 2011
	Regulated Businesses		Market-Based Operations		Other			Consolidated
Net operating revenues	$	2,368,891	$	327,815	$	(30,470	)	$	2,666,236
Depreciation and amortization		321,540		6,822		23,459			351,821
Total operating expenses, net		1,609,276		290,854		(37,030	)		1,863,100
Income (loss) from continuing operations before income taxes		535,445		39,250		(71,015	)		503,680
Total assets		12,843,820		280,862		1,651,709			14,776,391
Assets of discontinued operations (included in total assets above)		904,391		0		25,467			929,858
Capital expenditures		920,210		4,648		0			924,858
Capital expenditures of discontinued operations (included in above)		21,052		86		0			21,138

	As of or for the Year Ended December 31, 2010
	Regulated Businesses		Market-Based Operations		Other			Consolidated
Net operating revenues	$	2,285,656	$	294,723	$	(25,344	)	$	2,555,035
Depreciation and amortization		301,087		7,014		22,163			330,264
Total operating expenses, net		1,587,963		269,060		(30,110	)		1,826,913
Income (loss) from continuing operations before income taxes		478,629		30,443		(79,648	)		429,424
Total assets		12,290,798		240,718		1,554,730			14,086,246
Assets of discontinued operations (included in total assets above)		911,905		6,590		19,210			937,705
Capital expenditures		758,150		7,486		0			765,636
Capital expenditures of discontinued operations (included in above)		26,725		143		0			26,868

	As of or for the Year Ended December 31, 2009
	Regulated Businesses		Market-Based Operations		Other			Consolidated
Net operating revenues	$	2,076,563	$	238,180	$	(24,297	)	$	2,290,446
Depreciation and amortization		286,390		5,306		18,178			309,874
Impairment charge		0		0		428,036			428,036
Total operating expenses, net		1,497,453		217,643		391,515			2,106,611
Income (loss) from continuing operations before income taxes		371,919		25,168		(503,293	)		(106,206	)
Total assets		11,673,685		246,201		1,539,482			13,459,368
Assets of discontinued operations (included in total assets above)		905,938		9,333		17,504			932,775
Capital expenditures		779,428		5,837		0			785,265
Capital expenditures of discontinued operations (included in above)		43,078		111		0			43,189

XML

Stockholders' Equity (Stock Option Activity) (Details) (USD $) In Thousands, except Per Share data, unless otherwise specified	0 Months Ended	12 Months Ended
	Aug. 15, 2010	Dec. 31, 2011 Stock Option [Member] years
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares, Options outstanding at January 1, 2011		2,870
Shares Granted		736
Shares, Forfeited or expired	(33)	(71)
Shares, Exercised		(423)
Shares, Options outstanding at December 31, 2011		3,112
Shares, Exercisable at December 31, 2011		1,686
Weighted Average Exercise Price (per share), Options outstanding at January 1, 2011		$ 21.38
Weighted Average Exercise Price (per share), Granted		$ 27.08
Weighted Average Exercise Price (per share), Forfeited or expired		$ 23.27
Weighted Average Exercise Price (per share), Exercised		$ 21.27
Weighted Average Exercise Price (per share), Options outstanding at December 31, 2011		$ 22.70
Weighted Average Exercise Price (per share), Exercisable at December 31, 2011		$ 21.34
Weighted Average Remaining Life (years), Options outstanding at December 31, 2011		4.30
Weighted Average Remaining Life (years), Exercisable at December 31, 2011		3.50
Aggregate Intrinsic Value, Options outstanding at December 31, 2011		$ 28,493
Aggregate Intrinsic Value, Exercisable at December 31, 2011		$ 17,738

XML

Utility Plant (Components Of Utility Plant By Category) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010
Public Utility, Property, Plant and Equipment [Line Items]
Construction work in progress	$ 460,529	$ 299,733
Utility plant, gross	14,232,047	13,375,436
Less accumulated depreciation	3,360,005	3,134,094
Utility plant, net	10,872,042	10,241,342
Water Plant [Member] | Land And Other Non-Depreciable Assets [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Utility plant excluding Construction work in progress	128,286	125,648
Water Plant [Member] | Sources Of Supply [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Utility plant excluding Construction work in progress	565,301	527,552
Range of Remaining Useful Lives, Minimum (years)	20
Range of Remaining Useful Lives, Maximum (years)	127
Water Plant [Member] | Treatment And Pumping Facilities [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Utility plant excluding Construction work in progress	2,665,525	2,524,241
Range of Remaining Useful Lives, Minimum (years)	3
Range of Remaining Useful Lives, Maximum (years)	101
Water Plant [Member] | Transmission And Distribution Facilities [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Utility plant excluding Construction work in progress	6,632,828	6,333,032
Range of Remaining Useful Lives, Minimum (years)	9
Range of Remaining Useful Lives, Maximum (years)	127
Water Plant [Member] | Services, Meters And Fire Hydrants [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Utility plant excluding Construction work in progress	2,539,696	2,402,038
Range of Remaining Useful Lives, Minimum (years)	6
Range of Remaining Useful Lives, Maximum (years)	96
Water Plant [Member] | General Structures And Equipment [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Utility plant excluding Construction work in progress	693,880	643,973
Range of Remaining Useful Lives, Minimum (years)	3
Range of Remaining Useful Lives, Maximum (years)	112
Wastewater Plant [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Utility plant excluding Construction work in progress	$ 546,002	$ 519,219
Range of Remaining Useful Lives, Minimum (years)	4
Range of Remaining Useful Lives, Maximum (years)	86

XML

Long-Term Debt (Future Sinking Fund Payments And Maturities) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2011
Long-Term Debt [Abstract]
2012	$ 28,855
2013	112,594
2014	9,416
2015	49,568
2016	47,172
Thereafter	$ 5,092,338

XML

Employee Benefits (Schedule Of Effect Of One Percentage Point Change In Assumed Health Care Cost Trend Rates) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2011
Employee Benefits [Abstract]
Effect on total of service and interest cost components, One - Percentage - Point Increase	$ 7,145
Effect on total of service and interest cost components, One - Percentage - Point Decrease	5,838
Effect on other postretirement benefit obligation, One - Percentage - Point Increase	83,456
Effect on other postretirement benefit obligation One - Percentage - Point Decrease	$ 69,318

XML

Earnings (Loss) Per Common Share (Tables)

12 Months Ended

Dec. 31, 2011

Earnings (Loss) Per Common Share [Abstract]

Reconciliation Of Net Income (Loss) And Weighted Average Common Shares Outstanding For Calculating Basic Net Income (Loss) Per Share

	Years Ended December 31,
	2011		2010		2009
Basic
Income (loss) from continuing operations	$	304,929	$	255,072	$	(219,998	)
Income (loss) from discontinued operations, net of tax		4,684		12,755		(13,085	)
Net income (loss)		309,613		267,827		(233,083	)
Less: Distributed earnings to common shareholders		158,708		150,724		137,597
Less: Distributed earnings to participating securities		68		51		0
Undistributed earnings		150,837		117,052		(370,680	)
Undistributed earnings allocated to common shareholders		150,772		117,014		(370,680	)
Undistributed earnings allocated to participating securities		65		38		0
Total income (loss) from continuing operations available to common shareholders, basic	$	304,796	$	254,983	$	(219,998	)
Total income (loss) available to common shareholders, basic	$	309,480	$	267,738	$	(233,083	)
Weighted average common shares outstanding, basic		175,484		174,833		168,164
Basic earnings (loss) per share: (a)
Income (loss) from continuing operations	$	1.74	$	1.46	$	(1.31	)
Income (loss) from discontinued operations, net of tax	$	0.03	$	0.07	$	(0.08	)
Net income (loss)	$	1.76	$	1.53	$	(1.39	)

(a) Amounts may not sum due to rounding.

Reconciliation Of Net Income (Loss) And Weighted Average Common Shares Outstanding For Calculating Diluted Net Income (Loss) Per Share

	Years Ended December 31,
	2011		2010		2009
Diluted
Total income (loss) from continuing operations available to common shareholders, basic	$	304,796	$	254,983	$	(219,998	)
Income (loss) from discontinued operations, net of tax		4,684		12,755		(13,085	)
Total income (loss) available to common shareholders, basic		309,480		267,738		(233,083	)
Undistributed earnings allocated to participating securities		65		38		0
Total income (loss) from continuing operations available to common shareholders, diluted	$	304,861	$	255,021	$	(219,998	)
Total income (loss) available to common shareholders, diluted	$	309,545	$	267,776	$	(233,083	)
Weighted average common shares outstanding, basic		175,484		174,833		168,164
Restricted stock units		556		264		0
Stock options		490		26		0
Employee stock purchase plan		1		1		0
Weighted average common shares outstanding, diluted		176,531		175,124		168,164
Diluted earnings per share: (a)
Income (loss) from continuing operations	$	1.73	$	1.46	$	(1.31	)
Income (loss) from discontinued operations, net of tax	$	0.03	$	0.07	$	(0.08	)
Net income (loss)	$	1.75	$	1.53	$	(1.39	)

(a) Amounts may not sum due to rounding.

Schedule Of Potentially Dilutive Common Stock Equivalents Not Included In Earnings (Loss) Per Share Calculations

	2011		2010		2009
Stock options		711		1,781		2,265
Stock options where certain performance conditions were not met		0		0		459
Restricted stock units		0		0		258
Restricted stock units where certain performance conditions were not met		22		69		144
Employee stock purchase plan		0		0		32

XML

Acquisitions And Divestitures (Tables)

12 Months Ended

Dec. 31, 2011

Acquisitions And Divestitures [Abstract]

Schedule Of Income Statement And Balance Sheet

	Years Ended December 31,
	2011			2010		2009
Operating revenues	$	173,447		$	155,642	$	150,257
Total operating expenses, net		147,012			135,673		160,483
Operating income (loss)		26,435			19,969		(10,226	)
Other income (expense), net		(270	)		43		4,767
Income (loss) from discontinued operations before income taxes		26,165			20,012		(5,459	)
Provision for income taxes		21,481			7,257		7,626
Income (loss) from discontinued operations, net of tax	$	4,684		$	12,755	$	(13,085	)

	December 31, 2011		December 31, 2010
Assets:
Total property, plant and equipment	$	833,023	$	819,977
Current assets		21,906		20,710
Regulatory assets		43,849		39,833
Goodwill		29,608		55,107
Other		1,472		2,078
Total assets of discontinued operations	$	929,858	$	937,705
Liabilities:
Long-term debt	$	11,697	$	17,272
Current portion of long-term debt		12,839		8,668
Other current liabilities		29,530		39,505
Advances for construction		205,034		214,045
Regulatory liabilities		4,617		7,622
Other		15,540		(4,058	)
Contributions in aid of construction		102,961		90,906
Total liabilities of discontinued operations	$	382,218	$	373,960

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Long-Term Debt (Long-Term Debt Issued) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2011
Debt Instrument [Line Items]
Total issuances	$ 12,510
Private Activity Bonds And Government Funded Debt [Member] | Other Subsidiaries [Member]
Debt Instrument [Line Items]
Interest Rate, minimum	0.00%
Interest Rate, maximum	5.90%
Maturity Date Range, minimum	2011
Maturity Date Range, maximum	2034
Fixed Rate [Member] | Private Activity Bonds And Government Funded Debt [Member] | Other Subsidiaries [Member]
Debt Instrument [Line Items]
Interest Rate, minimum	0.00%
Interest Rate, maximum	1.56%
Maturity Date	2031
Total issuances	$ 12,510

XML

Stockholders' Equity (Summary Of Restricted Stock Activity) (Details) (Restricted Stock Units [Member], USD $) In Thousands, except Per Share data, unless otherwise specified	1 Months Ended	12 Months Ended
	Aug. 31, 2010	Dec. 31, 2011
Restricted Stock Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Nonvested total at January 1, 2011		479
Shares, Granted		205
Shares, Vested		(89)
Shares, Forfeited	(9)	(18)
Nonvested total at December 31, 2011		577
Weighted Average Grant Date Fair Value (per share), Nonvested total at January 1, 2011		$ 22.60
Weighted Average Grant Date Fair Value (per share), Granted		$ 29.95
Weighted Average Grant Date Fair Value (per share), Vested		$ 22.88
Weighted Average Grant Date Fair Value (per share), Forfeited		$ 25.28
Weighted Average Grant Date Fair Value (per share), Nonvested total at December 31, 2011		$ 25.09

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Income Taxes (Narrative) (Details) (USD $) In Thousands, unless otherwise specified	1 Months Ended	12 Months Ended
	Mar. 31, 2010	Dec. 31, 2011	Dec. 31, 2010
Income Tax Examination [Line Items]
Income tax refund claims	$ 25,314
Net of deferred tax assets and regulatory assets		16,979
Liability balance not including interest and penalties		214	80
Unrecognized tax benefit excluding interest and penalties, that would affect the effective tax rate		6,644	6,644
Capital loss carry forwards		4,357	0
Federal [Member]
Income Tax Examination [Line Items]
Net operating loss carryforwards		1,187,427	1,185,337
Net operating loss carryforwards expiration date		until 2024
Canadian [Member]
Income Tax Examination [Line Items]
Net operating loss carryforwards		6,198	5,398
Net operating loss carryforwards expiration date		between 2014 and 2030
State [Member]
Income Tax Examination [Line Items]
Net operating loss carryforwards		$ 739,804	$ 714,674
Net operating loss carryforwards expiration date		between 2012 and 2031

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Other Receivables, Net (Components Of Other Receivables) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2011	Dec. 31, 2010
Other Receivables, Net [Abstract]
Market-based trade accounts receivable	$ 26,734	$ 36,357
Allowance for doubtful accounts-market based trade accounts receivable	(3,067)	(3,015)
Market-based unbilled revenue	14,367	14,273
Other	22,379	23,974
Other receivables, net	$ 60,413	$ 71,589

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Earnings (Loss) Per Common Share (Reconciliation Of Net Income (Loss) And Weighted Average Common Shares Outstanding For Calculating Diluted Net Income (Loss) Per Share) (Details) (USD $) In Thousands, except Per Share data, unless otherwise specified	3 Months Ended								12 Months Ended
	Dec. 31, 2011	Sep. 30, 2011	Jun. 30, 2011	Mar. 31, 2011	Dec. 31, 2010	Sep. 30, 2010	Jun. 30, 2010	Mar. 31, 2010	Dec. 31, 2011		Dec. 31, 2010		Dec. 31, 2009
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Total income (loss) from continuing operations available to common shareholders, basic									$ 304,796		$ 254,983		$ (219,998)
Income (loss) from discontinued operations, net of tax									4,684		12,755		(13,085)
Total income (loss) available to common shareholders, basic									309,480		267,738		(233,083)
Undistributed earnings allocated to participating securities									65		38		0
Total income (loss) from continuing operations available to common shareholders, diluted									304,861		255,021		(219,998)
Total income (loss) available to common shareholders, diluted									$ 309,545		$ 267,776		$ (233,083)
Weighted average common shares outstanding, basic									175,484		174,833		168,164
Weighted average common shares outstanding, diluted									176,531		175,124		168,164
Income (loss) from continuing operations	$ 0.34	$ 0.73	$ 0.42	$ 0.23	$ 0.22	$ 0.68	$ 0.39	$ 0.17	$ 1.73	[1],[2]	$ 1.46	[1],[2]	$ (1.31)	[1],[2]
Income (loss) from discontinued operations, net of tax									$ 0.03	[1],[2]	$ 0.07	[1],[2]	$ (0.08)	[1],[2]
Net income (loss)	$ 0.37	$ 0.78	$ 0.46	$ 0.15	$ 0.23	$ 0.71	$ 0.42	$ 0.18	$ 1.75	[1],[2]	$ 1.53	[1],[2]	$ (1.39)	[1],[2]
Restricted Stock Units [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Stock-based compensation									556		264		0
Stock Options [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Stock-based compensation									490		26		0
Employee Stock Purchase Plan [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Stock-based compensation									1		1		0

[1] Amounts may not sum due to rounding

[2] Amounts may not sum due to rounding.

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Long-Term Debt (Narrative) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended					0 Months Ended									12 Months Ended
	Dec. 31, 2011		Dec. 31, 2010		Dec. 31, 2009	Jul. 12, 2010 Interest Rate Swap [Member]	Dec. 31, 2011 Long-Term Debt [Member] Mortgage Bonds [Member] Fixed Rate [Member] Other Subsidiaries [Member]		Dec. 31, 2010 Long-Term Debt [Member] Mortgage Bonds [Member] Fixed Rate [Member] Other Subsidiaries [Member]		Dec. 31, 2011 Long-Term Debt [Member] Private Activity Bonds And Government Funded Debt [Member] Fixed Rate [Member] Other Subsidiaries [Member]		Dec. 31, 2010 Long-Term Debt [Member] Private Activity Bonds And Government Funded Debt [Member] Fixed Rate [Member] Other Subsidiaries [Member]		Dec. 31, 2011 Minimum [Member]	Dec. 31, 2011 Minimum [Member] Line Of Credit [Member]	Dec. 31, 2011 Maximum [Member]	Dec. 31, 2011 Maximum [Member] Line Of Credit [Member]	Dec. 31, 2011 Collateralized Utility Plant [Member] Long-Term Debt [Member] Private Activity Bonds And Government Funded Debt [Member] Fixed Rate [Member] Other Subsidiaries [Member]
Debt Instrument [Line Items]
Long-term debt	$ 5,339,943	[1]	$ 5,401,553	[1]			$ 697,800	[1]	$ 730,991	[1]	$ 1,206,332	[1]	$ 1,201,723	[1]					$ 1,150,003
Fixed rate debt						100,000
Line of credit facility consolidated debt to consolidated capitalization ratio															0.58	0.70	1.00	1.00
Redeemable debt, amount outstanding	1,701,322
Fixed rate of debt						6.085%
Derivative description of variable rate basis						LIBOR plus 3.422%
Maturity						2017
Notional amount of variable interest rate swap outstanding	100,000		100,000
Interest income	$ 10,942		$ 10,320		$ 10,397

[1] AWCC, which is a wholly-owned subsidiary of the Company, has a strong support agreement with its parent that, under certain circumstances, is the functional equivalent of a guarantee.

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Short-Term Debt (Schedule Of Line Of Credit Facility Sub-Limits And Available Capacity) (Details) (Letter Of Credit [Member], USD $) In Thousands, unless otherwise specified	Dec. 31, 2011	Dec. 31, 2010
Letter Of Credit [Member]
Short-term Debt [Line Items]
Letter of credit sublimit	$ 150,000	$ 150,000
Letter of credit available capacity	$ 113,548	$ 113,203

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Long-Term Debt (Derivative Fair Value Balance) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2011		Dec. 31, 2010
Derivatives, Fair Value [Line Items]
Derivative fair value balance, Regulatory and other long-term assets	$ 5,824
Derivative fair value balance, Regulatory and other long-term liabilities			898
Fair value adjustment to interest rate hedge	(6,111)	[1]	345	[1]
Other [Member]
Derivatives, Fair Value [Line Items]
Derivative fair value balance, Regulatory and other long-term assets	5,824		0
Derivative fair value balance, Regulatory and other long-term liabilities	0		898
Long-Term Debt [Member]
Derivatives, Fair Value [Line Items]
Fair value adjustment to interest rate hedge	$ 6,111		$ (345)

[1] AWCC, which is a wholly-owned subsidiary of the Company, has a strong support agreement with its parent that, under certain circumstances, is the functional equivalent of a guarantee.

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Short-Term Debt (Schedule Of Short-Term Borrowings Activity) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010
Short-Term Debt [Abstract]
Average borrowings	$ 362,615	$ 164,782
Maximum borrowings outstanding	$ 494,900	$ 263,500
Weighted average interest rates, computed on a daily basis	0.41%	0.42%
Weighted average interest rates, at December 31	0.56%	0.46%

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Long-Term Debt (Components Of Long-Term Debt) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2011		Dec. 31, 2010
Debt Instrument [Line Items]
Long-term debt	$ 5,339,943	[1]	$ 5,401,553	[1]
Unamortized debt discount, net	43,888	[1],[2]	51,154	[1],[2]
Fair value adjustment to interest rate hedge	6,111	[1]	(345)	[1]
Total long-term debt	5,389,942	[1]	5,452,362	[1]
Capital lease obligations	1,264		5,076
Private Activity Bonds And Government Funded Debt [Member] | Other Subsidiaries [Member]
Debt Instrument [Line Items]
Interest Rate, minimum	0.00%
Interest Rate, maximum	5.90%
Maturity Date Range, minimum	2011
Maturity Date Range, maximum	2034
Mandatory Redeemable Preferred Stock [Member] | Other Subsidiaries [Member]
Debt Instrument [Line Items]
Interest Rate, minimum	4.60%
Interest Rate, maximum	9.18%
Maturity Date Range, minimum	2013
Maturity Date Range, maximum	2019
Fixed Rate [Member] | Private Activity Bonds And Government Funded Debt [Member] | Other Subsidiaries [Member]
Debt Instrument [Line Items]
Interest Rate, minimum	0.00%
Interest Rate, maximum	1.56%
Fixed Rate [Member] | Senior Notes [Member] | American Water Capital Corp. ("AWCC") [Member]
Debt Instrument [Line Items]
Interest Rate, minimum	6.00%
Interest Rate, maximum	8.25%
Maturity Date Range, minimum	2011
Maturity Date Range, maximum	2039
Fixed Rate [Member] | Mortgage Bonds [Member] | Other Subsidiaries [Member]
Debt Instrument [Line Items]
Interest Rate, minimum	8.21%
Interest Rate, maximum	9.71%
Maturity Date Range, minimum	2011
Maturity Date Range, maximum	2022
Long-Term Debt [Member]
Debt Instrument [Line Items]
Fair value adjustment to interest rate hedge	(6,111)		345
Long-Term Debt [Member] | Mandatory Redeemable Preferred Stock [Member] | Other Subsidiaries [Member]
Debt Instrument [Line Items]
Interest Rate, minimum	4.60%	[1]
Interest Rate, maximum	9.75%
Weighted Average Rate	8.43%	[1]
Maturity Date Range, minimum	2013
Maturity Date Range, maximum	2036
Long-term debt	22,101	[1]	22,844	[1]
Long-Term Debt [Member] | Notes Payable And Other [Member] | Other Subsidiaries [Member]
Debt Instrument [Line Items]
Interest Rate, minimum	9.49%	[1],[3]
Interest Rate, maximum	13.96%
Weighted Average Rate	12.12%	[1],[3]
Maturity Date Range, minimum	2013	[1],[3]
Maturity Date Range, maximum	2026
Long-term debt	1,691	[1],[3]	5,689	[1],[3]
Long-Term Debt [Member] | Fixed Rate [Member] | Private Activity Bonds And Government Funded Debt [Member] | American Water Capital Corp. ("AWCC") [Member]
Debt Instrument [Line Items]
Interest Rate, minimum	4.85%	[1]
Interest Rate, maximum	6.75%
Weighted Average Rate	5.72%	[1]
Maturity Date Range, minimum	2018	[1]
Maturity Date Range, maximum	2040
Long-term debt	322,610	[1]	322,610	[1]
Long-Term Debt [Member] | Fixed Rate [Member] | Private Activity Bonds And Government Funded Debt [Member] | Other Subsidiaries [Member]
Debt Instrument [Line Items]
Interest Rate, minimum	0.00%	[1]
Interest Rate, maximum	6.20%
Weighted Average Rate	5.07%	[1]
Maturity Date Range, minimum	2012	[1]
Maturity Date Range, maximum	2039
Long-term debt	1,206,332	[1]	1,201,723	[1]
Long-Term Debt [Member] | Fixed Rate [Member] | Senior Notes [Member] | American Water Capital Corp. ("AWCC") [Member]
Debt Instrument [Line Items]
Interest Rate, minimum	5.39%	[1]
Interest Rate, maximum	10.00%
Weighted Average Rate	6.25%	[1]
Maturity Date Range, minimum	2013	[1]
Maturity Date Range, maximum	2040
Long-term debt	3,089,409	[1]	3,117,696	[1]
Long-Term Debt [Member] | Fixed Rate [Member] | Mortgage Bonds [Member] | Other Subsidiaries [Member]
Debt Instrument [Line Items]
Interest Rate, minimum	5.48%	[1]
Interest Rate, maximum	9.71%
Weighted Average Rate	7.40%	[1]
Maturity Date Range, minimum	2012	[1]
Maturity Date Range, maximum	2039
Long-term debt	$ 697,800	[1]	$ 730,991	[1]

[1] AWCC, which is a wholly-owned subsidiary of the Company, has a strong support agreement with its parent that, under certain circumstances, is the functional equivalent of a guarantee.

[2] Includes fair value adjustments previously recognized in acquisition purchase accounting.

[3] Includes capital lease obligations of $1,264 and $5,076 at December 31, 2011 and 2010, respectively.

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Stockholders' Equity (Additional Information To Stock Options Activity) (Details) (Stock Option [Member], USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Stock Option [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Intrinsic value	$ 3,026	$ 333	$ 0
Exercise proceeds	8,991	3,010	0
Income tax benefit (shortfall)	$ 511	$ (89)	$ 0

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Commitments And Contingencies

12 Months Ended

Dec. 31, 2011

Commitments And Contingencies [Abstract]

Commitments And Contingencies

Note 16: Commitments and Contingencies

The Company is also routinely involved in legal actions incident to the normal conduct of its business. At December 31, 2011, the Company has accrued approximately $2,900 as probable costs and it is reasonably possible that additional losses could range up to $9,700 for these matters. For certain matters, the Company is unable to estimate possible losses. The Company believes that damages or settlements, if any, recovered by plaintiffs in such claims or actions will not have a material adverse effect on the Company's results of operations, financial position or cash flows.

The Company enters into agreements for the provision of services to water and wastewater facilities for the United States military, municipalities and other customers. The Company's military services agreements expire between 2051 and 2060 and have remaining performance commitments as measured by estimated remaining contract revenue of $2,037,000 at December 31, 2011. The military contracts are subject to customary termination provisions held by the U.S. Federal Government prior to the agreed upon contract expiration. The Company's Operations and Maintenance agreements with municipalities and other customers expire between 2012 and 2048 and have remaining performance commitments as measured by estimated remaining contract revenue of $1,076,000 at December 31, 2011. Some of the Company's long-term contracts to operate and maintain a municipality's, federal government's or other party's water or wastewater treatment and delivery facilities include responsibility for certain maintenance for some of those facilities, in exchange for an annual fee. Unless specifically required to perform certain maintenance activities, the maintenance costs are recognized when the maintenance is performed.

Commitments have been made in connection with certain construction programs. The estimated capital expenditures required under legal and binding contractual obligations amounted to $171,878 at December 31, 2011.

The Company's regulated subsidiaries maintain agreements with other water purveyors for the purchase of water to supplement their water supply. The Company's subsidiaries purchased water expense under these types of agreements amounted to approximately $104,384, $103,898 and $96,053 during the years ended December 31, 2011, 2010 and 2009, respectively. The estimated annual commitment related to the minimum quantities of water purchased is expected to approximate $48,916 in 2012, $47,576 in 2013, $47,452 in 2014, $47,404 in 2015, $43,439 in 2016 and $448,920 thereafter.

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Significant Accounting Policies (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2011 years	Dec. 31, 2010	Dec. 31, 2009
Voting interest	50.00%
Nonutility property estimated useful life, minimum (years)	3
Nonutility property estimated useful life, maximum (years)	50
Book overdrafts for disbursement accounts	$ 34,002	$ 50,881
Number of business reporting units for market based services	7
Impairment charge	0	0	428,036
Estimated refunds	18,681	22,451
Non-cash utility property received as advances and contributions	23,504	27,566	77,094
Amortization of contributions in aid of construction	18,327	17,423	16,371
Remediation costs accrued	5,500	6,630
Accrual related to conservation agreement	3,500
Accrual for environmental loss contingencies payments	1,100
Regulatory assets	9,187	10,642
Additional regulatory assets granted for recovery		3,500
United States Government [Member]
Agreements range, high	50
Industries and Municipalities [Member]
Agreements range, low	2
Agreements range, high	40
Software [Member]
Acquisition cost, carrying value	$ 49,241	$ 60,408

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Short-Term Debt (Tables)

12 Months Ended

Dec. 31, 2011

Short-Term Debt [Abstract]

Components Of Short-Term Debt

	2011		2010
Revolving credit lines	$	0	$	2,734
Commercial paper, net of $52 and $10 discount at 2011 and 2010, respectively		481,048		175,290
Book overdraft		34,002		50,881
Total short-term debt	$	515,050	$	228,905

Schedule Of Available Capacity Under Commercial Paper Program

	2011		2010
Commercial paper program	$	700,000	$	700,000
Commercial paper program available capacity		218,900		524,700

Schedule Of Line Of Credit Facility Sub-Limits And Available Capacity

	2011		2010
Letter of credit sublimit	$	150,000	$	150,000
Letter of credit available capacity		113,548		113,203

Schedule Of Short-Term Borrowings Activity

	2011			2010
Average borrowings	$	362,615		$	164,782
Maximum borrowings outstanding		494,900			263,500
Weighted average interest rates, computed on a daily basis		0.41	%		0.42	%
Weighted average interest rates, at December 31		0.56	%		0.46	%

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Preferred Stock Without Mandatory Redemption Requirements (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Class of Stock [Line Items]
Preferred stock without mandatory redemption requirements	$ 4,547	$ 4,547
Dividends issued	224	224	225
4.50% [Member]
Class of Stock [Line Items]
Preferred stock without mandatory redemption requirements	1,720	1,720
Preferred stock, dividend rate, percentage		4.50%
5.00% [Member]
Class of Stock [Line Items]
Preferred stock without mandatory redemption requirements	1,952	1,952
Preferred stock, dividend rate, percentage		5.00%
5.50% [Member]
Class of Stock [Line Items]
Preferred stock without mandatory redemption requirements	486	486
Preferred stock, dividend rate, percentage		5.50%
5.75% [Member]
Class of Stock [Line Items]
Preferred stock without mandatory redemption requirements	$ 389	$ 389
Preferred stock, dividend rate, percentage		5.75%

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Employee Benefits (Schedule Of Significant Unobservable Inputs) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010
Pension Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets beginning balance	$ 860,973	$ 695,520
Actual return on assets	2,529	105,078
Fair value of plan assets ending balance	981,068	860,973
Pension Plan Assets [Member] | Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets ending balance	148,574	141,403
Pension Plan Assets [Member] | Guaranteed Annuity Contracts [Member] | Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets beginning balance	141,403	124,938
Actual return on assets	(3,425)	20,381
Transfers in(out)	10,596	(3,916)
Fair value of plan assets ending balance	148,574	141,403
Postretirement Benefit Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets beginning balance	374,403	312,042
Actual return on assets	2,619	45,305
Fair value of plan assets ending balance	382,670	374,403
Postretirement Benefit Plan Assets [Member] | Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets ending balance

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Regulatory Assets And Liabilities (Tables)

12 Months Ended

Dec. 31, 2011

Regulatory Assets And Liabilities [Abstract]

Components Of Regulatory Assets

	2011		2010
Income taxes recoverable through rates	$	252,570	$	247,104
Debt and preferred stock expense		73,096		76,278
Deferred pension expense		256,858		207,633
Deferred other postretirement benefit expense		149,393		126,894
Deferred security costs		4,837		7,479
Deferred business services project expense		8,776		10,670
Deferred tank painting costs		29,500		26,924
Deferred rate case expense		14,553		9,322
Purchase premium recoverable through rates		60,635		60,647
Environmental remediation recoverable through rates		9,187		10,642
Coastal water project costs		24,419		27,084
San Clemente Dam project costs		22,890		18,723
Removal costs recoverable through rates		80,402		59,317
Other		92,545		87,457
	$	1,079,661	$	976,174

Components Of Regulatory Liabilities

	2011		2010
Removal costs recovered through rates	$	272,618	$	260,947
Other		53,211		35,174
	$	325,829	$	296,121

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Acquisitions And Divestitures (Schedule Of Summary Of Discontinued Operations) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Acquisitions And Divestitures [Abstract]
Operating revenues	$ 173,447	$ 155,642	$ 150,257
Total operating expenses, net	147,012	135,673	160,483
Operating income (loss)	26,435	19,969	(10,226)
Other income (expense), net	(270)	43	4,767
Income (loss) from discontinued operations before income taxes	26,165	20,012	(5,459)
Provision for income taxes	21,481	7,257	7,626
Income (loss) from discontinued operations, net of tax	$ 4,684	$ 12,755	$ (13,085)

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Stockholders' Equity (Schedule Of Accumulated Other Comprehensive Loss) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2011	Dec. 31, 2010
Stockholders' Equity [Abstract]
Employee benefit plans funded status adjustments	$ (101,457)	$ (75,639)
Foreign currency translation	3,780	4,193
Balance at December 31	$ (97,677)	$ (71,446)

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Fair Values Of Financial Instruments (Narrative) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Fair Values Of Financial Instruments [Abstract]
Impairment charge	$ 0	$ 0	$ 428,036

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Regulatory Assets And Liabilities (Components Of Regulatory Liabilities) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2011	Dec. 31, 2010
Regulatory Liabilities [Line Items]
Regulatory liabilities	$ 325,829	$ 296,121
Removal Costs Recovered Through Rates [Member]
Regulatory Liabilities [Line Items]
Regulatory liabilities	272,618	260,947
Other Regulatory Liability [Member]
Regulatory Liabilities [Line Items]
Regulatory liabilities	$ 53,211	$ 35,174

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Fair Values Of Financial Instruments (Tables)

12 Months Ended

Dec. 31, 2011

Fair Values Of Financial Instruments [Abstract]

Fair Value And Carrying Value Of Preferred Stocks And Long-Term Debt

As of December 31, 2011	Carrying Amount		Fair Value
Preferred stocks with mandatory redemption requirements	$	22,036	$	26,458
Long-term debt (excluding capital lease obligations)		5,366,642		6,230,547

As of December 31, 2010	Carrying Amount		Fair Value
Preferred stocks with mandatory redemption requirements	$	22,794	$	25,475
Long-term debt (excluding capital lease obligations)		5,424,492		5,841,448

Recurring Fair Value Measurements

	At Fair Value as of December 31, 2011
Recurring Fair Value Measures	Level 1		Level 2			Level 3		Total
Assets:
Restricted funds	$	57,941		—			—	$	57,941
Rabbi trust investments		—	$	518			—		518
Deposits		2,287		—			—		2,287
Mark-to-market derivative asset		—		5,824			—		5,824
Total assets		60,228		6,342			—		66,570
Liabilities:
Deferred compensation obligation		—		9,036			—		9,036
Total liabilities		—		9,036			—		9,036
Total net assets (liabilities)	$	60,228	$	(2,694	)		—	$	57,534

	At Fair Value as of December 31, 2010
Recurring Fair Value Measures	Level 1		Level 2			Level 3		Total
Assets:
Restricted funds	$	120,784		—			—	$	120,784
Rabbi trust investments		—	$	1,552			—		1,552
Deposits		1,381		—			—		1,381
Total assets		122,165		1,552			—	$	123,717
Liabilities:
Deferred compensation obligation		—		9,180			—		9,180
Mark-to-market derivative liability		—		898			—		898
Total liabilities		—		10,078			—		10,078
Total net assets (liabilities)	$	122,165	$	(8,526	)		—	$	113,639

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Consolidated Statements Of Changes In Stockholders' Equity (Parenthetical) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Consolidated Statements Of Changes In Stockholders' Equity [Abstract]
Direct stock reinvestment and purchase plan, expense	$ 19	$ 96	$ 7,824
Other comprehensive income (loss), tax	$ (16,507)	$ (4,724)	$ 10,242

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Segment Information (Summarized Segment Information) (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended								12 Months Ended
	Dec. 31, 2011	Sep. 30, 2011	Jun. 30, 2011	Mar. 31, 2011	Dec. 31, 2010	Sep. 30, 2010	Jun. 30, 2010	Mar. 31, 2010	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Segment Reporting Information [Line Items]
Net operating revenues	$ 639,779	$ 760,869	$ 668,873	$ 596,715	$ 625,773	$ 744,296	$ 630,761	$ 554,205	$ 2,666,236	$ 2,555,035	$ 2,290,446
Customers in number of states	16								16
Depreciation and amortization									351,821	330,264	309,874
Impairment charge									0	0	428,036
Total operating expenses, net									1,863,100	1,826,913	2,106,611
Income (loss) from continuing operations before income taxes									503,680	429,424	(106,206)
Total assets	14,776,391				14,086,246				14,776,391	14,086,246	13,459,368
Assets of discontinued operations (included in total assets above)	929,858				937,705				929,858	937,705	932,775
Capital expenditures									924,858	765,636	785,265
Capital expenditures of discontinued operations (included in above)									21,138	26,868	43,189
Number of operating segments									2
Number of utility subsidiaries									17
Regulated Businesses [Member]
Segment Reporting Information [Line Items]
Net operating revenues									2,368,891	2,285,656	2,076,563
Depreciation and amortization									321,540	301,087	286,390
Impairment charge											0
Total operating expenses, net									1,609,276	1,587,963	1,497,453
Income (loss) from continuing operations before income taxes									535,445	478,629	371,919
Total assets	12,843,820				12,290,798				12,843,820	12,290,798	11,673,685
Assets of discontinued operations (included in total assets above)	904,391				911,905				904,391	911,905	905,938
Capital expenditures									920,210	758,150	779,428
Capital expenditures of discontinued operations (included in above)									21,052	26,725	43,078
Market-Based Operations [Member]
Segment Reporting Information [Line Items]
Net operating revenues									327,815	294,723	238,180
Depreciation and amortization									6,822	7,014	5,306
Impairment charge											0
Total operating expenses, net									290,854	269,060	217,643
Income (loss) from continuing operations before income taxes									39,250	30,443	25,168
Total assets	280,862				240,718				280,862	240,718	246,201
Assets of discontinued operations (included in total assets above)	0				6,590				0	6,590	9,333
Capital expenditures									4,648	7,486	5,837
Capital expenditures of discontinued operations (included in above)									86	143	111
Other [Member]
Segment Reporting Information [Line Items]
Net operating revenues									(30,470)	(25,344)	(24,297)
Depreciation and amortization									23,459	22,163	18,178
Impairment charge											428,036
Total operating expenses, net									(37,030)	(30,110)	391,515
Income (loss) from continuing operations before income taxes									(71,015)	(79,648)	(503,293)
Total assets	1,651,709				1,554,730				1,651,709	1,554,730	1,539,482
Assets of discontinued operations (included in total assets above)	25,467				19,210				25,467	19,210	17,504
Capital expenditures									0	0	0
Capital expenditures of discontinued operations (included in above)									$ 0	$ 0	$ 0

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Goodwill (Narrative) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009	Nov. 30, 2011
Goodwill [Abstract]
Total Net, ending balance	$ 1,195,069	$ 1,195,585	$ 1,195,274	$ 1,195,069
Goodwill	1,195,069	1,195,585	1,195,274	1,195,069
Impairment charge	$ 0	$ 0	$ 428,036

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General Taxes (Tables)

12 Months Ended

Dec. 31, 2011

General Taxes [Abstract]

Components Of General Tax Expense From Continuing Operations

	2011		2010		2009
Gross receipts and franchise	$	90,674	$	86,063	$	79,410
Property and capital stock		77,330		78,184		70,907
Payroll		31,705		31,089		27,834
Other general		10,769		10,261		8,469
	$	210,478	$	205,597	$	186,620

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Related Party Transactions

12 Months Ended

Dec. 31, 2011

Related Party Transactions [Abstract]

Related Party Transactions

Note 20: Related Party Transactions

One of the Company's Directors was employed by an electrical utility that supplies electricity and electrical services to the Company's subsidiaries in Ohio, Pennsylvania, and New Jersey. The Company purchased, from various subsidiaries of this electrical utility, approximately $8,558 of such services in 2009. The Director retired from that electrical utility effective March 31, 2010. The Company purchased, from various subsidiaries of this electrical utility, approximately $3,225 of such services in the first quarter of 2010.

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Operating Leases

12 Months Ended

Dec. 31, 2011

Operating Leases [Abstract]

Operating Leases

Note 19: Operating Leases

The Company has entered into operating leases involving certain facilities and equipment. Rental expenses of continuing operations under operating leases were $32,752 for 2011, $36,264 for 2010 and $34,862 for 2009. The operating leases for facilities will expire over the next 20 years and the operating leases for equipment will expire over the next five years. Certain operating leases have renewal options ranging from one to five years.

At December 31, 2011, the minimum annual future rental commitment under operating leases that have initial or remaining non-cancelable lease terms in excess of one year are $21,528 in 2012, $17,987 in 2013, $14,833 in 2014, $10,877 in 2015, $9,172 in 2016 and $101,472 thereafter.

The Company has a series of agreements with various public entities (the "Partners") to establish certain joint ventures, commonly referred to as "public-private partnerships." Under the public-private partnerships, the Company constructed utility plant, financed by the Company, and the Partners constructed utility plant (connected to the Company's property), financed by the Partners. The Company agreed to transfer and convey some of its real and personal property to the Partners in exchange for an equal principal amount of Industrial Development Bonds ("IDBs"), issued by the Partners under a state Industrial Development Bond and Commercial Development Act. The Company leased back the total facilities, including portions funded by both the Company and the Partners, under leases for a period of 40 years.

The leases related to the portion of the facilities funded by the Company have required payments from the Company to the Partners that approximate the payments required by the terms of the IDBs from the Partners to the Company (as the holder of the IDBs). As the ownership of the portion of the facilities constructed by the Company will revert back to the Company at the end of the lease, the Company has recorded these as capital leases. The lease obligation and the receivable for the principal amount of the IDBs are presented by the Company on a net basis. The carrying value of the facilities funded by the Company recognized as a capital lease asset was $159,211 and $159,707 at December 31, 2011 and 2010, respectively, which is presented within utility plant. The future payments under the lease obligations are equal to and offset by the payments receivable under the IDBs.

At December 31, 2011, the minimum annual future rental commitment under the operating leases for the portion of the facilities funded by the Partners that have initial or remaining non-cancelable lease terms in excess of one year included in the preceding minimum annual rental commitments are $3,629 in 2012, $3,668 in 2013, $3,727 in 2014 through 2016, and $82,620 thereafter.

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Employee Benefits (Schedule Of Accumulated And Projected Benefit Obligations) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2011	Dec. 31, 2010
Employee Benefits [Abstract]
Projected benefit obligation	$ 1,402,000	$ 1,285,000
Fair value of plan assets	981,000	861,000
Accumulated benefit obligation	1,257,000	1,138,000
Fair value of plan assets	$ 981,000	$ 861,000

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Allowance For Uncollectible Accounts (Schedule Of Allowances For Uncollectible Accounts) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Allowance For Uncollectible Accounts [Abstract]
Balance at January 1	$ (17,474)	$ (18,148)	$ (16,859)
Amounts charged to expense	(16,178)	(17,973)	(20,999)
Amounts written off	21,855	22,124	23,104
Recoveries of amounts written off	(3,522)	(3,477)	(3,394)
Balance at December 31	$ (15,319)	$ (17,474)	$ (18,148)

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Income Taxes (Tables)

12 Months Ended

Dec. 31, 2011

Income Taxes [Abstract]

Components Of Income Tax Expense From Continuing Operations

	2011			2010			2009
State income taxes
Current	$	(7,440	)	$	24,653		$	(19,582	)
Deferred
Current		(171	)		78			(1,661	)
Non-current		44,576			11,024			38,908
		36,965			35,755			17,665
Federal income taxes
Current		12,239			(1,500	)		555
Deferred
Current		(314	)		69			(16,189	)
Non-current		151,403			141,589			113,174
Amortization of deferred investment tax credits		(1,542	)		(1,561	)		(1,413	)
		161,786			138,597			96,127
	$	198,751		$	174,352		$	113,792

Reconciliation Of Income Tax Expense From Continuing Operations

	2011			2010			2009
Income tax at statutory rate	$	176,288		$	150,298		$	(37,172	)
Increases (decreases) resulting from:
State taxes, net of federal taxes		24,027			23,241			11,482
Change in valuation allowance		(160	)		(533	)		(6,578	)
Flow through differences		2,895			2,807			2,760
Amortization of deferred investment tax credits		(1,542	)		(1,561	)		(1,413	)
Subsidiary preferred dividends		668			675			680
Impairment charges		0			0			143,321
Other, net		(3,425	)		(575	)		712
Actual income tax expense	$	198,751		$	174,352		$	113,792

Components Of The Net Deferred Tax Liability From Continuing Operations

	2011			2010
Deferred tax assets:
Advances and contributions	$	475,280		$	463,694
Deferred investment tax credits		11,202			11,789
Other postretirement benefits		101,258			92,620
Tax losses and credits		284,636			327,128
Pension benefits		132,972			141,530
Unamortized debt discount, net		23,872			22,889
Other		13,308			8,429
		1,042,528			1,068,079
Valuation allowance		(20,701	)		(22,733	)
		1,021,827			1,045,346
Deferred tax liabilities:
Utility plant, principally due to depreciation differences		1,958,044			1,846,338
Income taxes recoverable through rates		94,331			93,495
Deferred security costs		1,982			3,065
Deferred business services project expenses		4,573			4,566
Deferred other postretirement benefits		58,238			48,155
Deferred pension benefits		97,899			78,972
Other		95,557			81,005
		2,310,624			2,155,596
	$	(1,288,797	)	$	(1,110,250	)

Changes In Company Gross Liability Excluding Interest And Penalties For Unrecognized Tax Benefits

Balance at January 1, 2010	$	112,021
Increases in current period tax positions		7,434
Decreases due to lapse of statute of limitations		(1,141	)
Balance at December 31, 2010		118,314
Increases in current period tax positions		46,961
Decreases in prior period measurement of tax positions		(6,697	)
Balance at December 31, 2011	$	158,578

Changes In The Company Valuation Allowance

Balance at January 1, 2009	$	28,862
Increases in current period tax positions		2,778
Decreases in current period tax positions		(5,698	)
Decreases in prior period tax positions		(321	)
Balance at December 31, 2009	$	25,621
Increases in current period tax positions		907
Decreases in current period tax positions		(2,740	)
Balance at December 31, 2010	$	23,788
Increases in current period tax positions		1,525
Decreases in current period tax positions		(3,734	)
Balance at December 31, 2011	$	21,579

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Segment Information

12 Months Ended

Dec. 31, 2011

Segment Information [Abstract]

Segment Information

Note 21: Segment Information

The Company has two operating segments referred to as the Regulated Businesses and Market-Based Operations segments. The Company's chief operating decision maker regularly reviews the operating results of the Regulated Businesses and Market-Based Operations segments to assess segment performance and allocate resources. The evaluation of segment performance and the allocation of resources are based on several measures. The measure that is most consistent with that used by management is income from continuing operations before income tax.

The Regulated Businesses segment includes the Company's 17 utility subsidiaries in continuing operations that provide water and wastewater services to customers in 16 U.S. states. With the exception of one company, each of these public utility subsidiaries is subject to regulation by public utility commissions and local governments. In addition to providing similar products and services and being subject to the public utility regulatory environment, each of the regulated subsidiaries has similar economic characteristics, production processes, types and classes of customers and water distribution or wastewater collection processes. Each of these companies is also subject to both federal and state regulation regarding the quality of water distributed and the discharge of wastewater residuals.

The Market-Based Operations segment is comprised of market-based businesses that provide a broad range of market-based water and wastewater services and products including homeowner water and sewer line maintenance services, water and wastewater facility operations and maintenance services, granular carbon technologies and products for cleansing water and wastewater, wastewater residuals management services and water and wastewater facility engineering services.

The accounting policies of the segments are the same as those described in the summary of significant accounting policies (see Note 2). The Regulated Businesses and Market-Based Operations segment information includes intercompany costs that are allocated by American Water Works Service Company, Inc. and intercompany interest that is charged by AWCC, which are eliminated to reconcile to the consolidated results of operations. Inter-segment revenues, which are primarily recorded at cost plus mark-up that approximates current market prices, include carbon regeneration services and leased office space, furniture and equipment provided by the Company's market-based subsidiaries to its regulated subsidiaries. Other includes corporate costs that are not allocated to the Company's subsidiaries, eliminations of inter-segment transactions, fair value adjustments and associated income and deductions related to the Acquisitions that have not been allocated to the segments for evaluation of segment performance and allocation of resource purposes. The adjustments related to the Acquisitions are reported in Other, as they are excluded from segment performance measures evaluated by management. The following table includes the Company's summarized segment information:

	As of or for the Year Ended December 31, 2011
	Regulated Businesses		Market-Based Operations		Other			Consolidated
Net operating revenues	$	2,368,891	$	327,815	$	(30,470	)	$	2,666,236
Depreciation and amortization		321,540		6,822		23,459			351,821
Total operating expenses, net		1,609,276		290,854		(37,030	)		1,863,100
Income (loss) from continuing operations before income taxes		535,445		39,250		(71,015	)		503,680
Total assets		12,843,820		280,862		1,651,709			14,776,391
Assets of discontinued operations (included in total assets above)		904,391		0		25,467			929,858
Capital expenditures		920,210		4,648		0			924,858
Capital expenditures of discontinued operations (included in above)		21,052		86		0			21,138

	As of or for the Year Ended December 31, 2010
	Regulated Businesses		Market-Based Operations		Other			Consolidated
Net operating revenues	$	2,285,656	$	294,723	$	(25,344	)	$	2,555,035
Depreciation and amortization		301,087		7,014		22,163			330,264
Total operating expenses, net		1,587,963		269,060		(30,110	)		1,826,913
Income (loss) from continuing operations before income taxes		478,629		30,443		(79,648	)		429,424
Total assets		12,290,798		240,718		1,554,730			14,086,246
Assets of discontinued operations (included in total assets above)		911,905		6,590		19,210			937,705
Capital expenditures		758,150		7,486		0			765,636
Capital expenditures of discontinued operations (included in above)		26,725		143		0			26,868

	As of or for the Year Ended December 31, 2009
	Regulated Businesses		Market-Based Operations		Other			Consolidated
Net operating revenues	$	2,076,563	$	238,180	$	(24,297	)	$	2,290,446
Depreciation and amortization		286,390		5,306		18,178			309,874
Impairment charge		0		0		428,036			428,036
Total operating expenses, net		1,497,453		217,643		391,515			2,106,611
Income (loss) from continuing operations before income taxes		371,919		25,168		(503,293	)		(106,206	)
Total assets		11,673,685		246,201		1,539,482			13,459,368
Assets of discontinued operations (included in total assets above)		905,938		9,333		17,504			932,775
Capital expenditures		779,428		5,837		0			785,265
Capital expenditures of discontinued operations (included in above)		43,078		111		0			43,189

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Unaudited Quarterly Data

12 Months Ended

Dec. 31, 2011

Unaudited Quarterly Data [Abstract]

Unaudited Quarterly Data

Note 22: Unaudited Quarterly Data

The following table sets forth certain supplemental unaudited consolidated quarterly financial data for each of the four quarters in the years ended December 31, 2011 and 2010, respectively. The operating results for any quarter are not indicative of results that may be expected for a full year or any future periods.

During the fourth quarter of 2011, the Company discovered errors in the Company's calculation of gain or loss on discontinued operations that originated in the first and second quarters of 2011. As a result, the Company recorded an after-tax charge totaling $24,555 to reduce the net asset values of those businesses, which included associated parent company goodwill, to their net realizable values. This charge was recognized within discontinued operations and net income and included in results for the full year ended December 31, 2011. The write-downs consisted of $21,099 recognized as of March 31, and $3,456 recognized as of June 30 as reflected in the table below. Management does not consider these write-downs to constitute a triggering event for the balance of the Company's goodwill of continuing operations. In addition, the adjustment had no impact on income from continuing operations or to the cash flows from operations or total cash flows.

Based on the materiality guidelines contained in SEC Staff Accounting Bulletin No. 99, "Materiality" and Topic 5.F of the Codification of Staff Accounting Bulletins, "Accounting Changes Not Retroactively Applied Due to Immateriality," the Company concluded that the adjustments to correct the errors were not material to its financial statements for the three months ended March 31, 2011 and June 30, 2011. Because the effect of the adjustments were not material to any previously issued financial statements, the Company determined not to amend its previously filed Quarterly Reports on Form 10-Q for the quarters ended March 31, 2011 and June 30, 2011; instead, the Company will make corresponding adjustments to prior period financial statements, as appropriate, the next time those financial statements are filed.

2011	First Quarter		Second Quarter		Third Quarter		Fourth Quarter
	(In thousands, except per share data)
Operating revenues	$	596,715	$	668,873	$	760,869	$	639,779
Operating income		143,250		201,395		281,408		177,083
Income from continuing operations		40,699		74,817		128,495		60,918
Net income		26,233		81,110		137,422		64,848
Basic earnings per common share:
Income from continuing operations	$	0.23	$	0.43	$	0.73	$	0.35
Net income	$	0.15	$	0.46	$	0.78	$	0.37
Diluted earnings per common share:
Income from continuing operations	$	0.23	$	0.42	$	0.73	$	0.34
Net income	$	0.15	$	0.46	$	0.78	$	0.37

2010	First Quarter		Second Quarter		Third Quarter		Fourth Quarter
	(In thousands, except per share data)
Operating revenues	$	554,205	$	630,761	$	744,296	$	625,773
Operating income		123,831		188,367		266,480		149,444
Income from continuing operations		29,328		68,071		119,327		38,346
Net income		30,808		72,751		124,114		40,154
Basic earnings per common share:
Income from continuing operations	$	0.17	$	0.39	$	0.68	$	0.22
Net income	$	0.18	$	0.42	$	0.71	$	0.23
Diluted earnings per common share:
Income from continuing operations	$	0.17	$	0.39	$	0.68	$	0.22
Net income	$	0.18	$	0.42	$	0.71	$	0.23

Amounts may not sum due to rounding; per share amounts may not sum due to changes in shares outstanding during the year.

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Consolidated Statements Of Changes In Stockholders' Equity (USD $) In Thousands	Common Stock [Member]	Paid-In Capital [Member]	Accumulated Deficit [Member]	Accumulated Other Comprehensive Loss [Member]	Treasury Stock [Member]	Preferred Stock Of Subsidiary Companies Without Mandatory Redemption Requirements [Member]	Total
Balance at Dec. 31, 2008	$ 1,600	$ 5,888,253	$ (1,705,594)	$ (82,251)	$ (7)	$ 4,557	$ 4,106,558
Balance (in shares) at Dec. 31, 2008	160,000				0
Net income (loss)			(233,083)				(233,083)
Common stock offering, net of expenses	145	242,156					242,301
Common stock offering, net of expenses (in shares)	14,500
Employee stock purchase plan	1	2,453			23		2,477
Employee stock purchase plan (in shares)	128				1
Stock-based compensation activity		7,215	(279)		(16)		6,920
Stock-based compensation activity (in shares)	2				(1)
Other comprehensive income (loss), net of tax				17,574			17,574
Dividends			(137,331)				(137,331)
Balance at Dec. 31, 2009	1,746	6,140,077	(2,076,287)	(64,677)	0	4,557	4,005,416
Balance (in shares) at Dec. 31, 2009	174,630				0
Net income (loss)			267,827				267,827
Direct stock reinvestment and purchase plan, net of expense	1	1,328					1,329
Direct stock reinvestment and purchase plan, net of expense (in shares)	63						63
Employee stock purchase plan	1	2,502			127		2,630
Employee stock purchase plan (in shares)	112				7
Stock-based compensation activity	2	12,768	(474)		(146)		12,150
Stock-based compensation activity (in shares)	191				(8)
Subsidiary preferred stock redemption						(10)	(10)
Other comprehensive income (loss), net of tax				(6,769)			(6,769)
Dividends			(150,301)				(150,301)
Balance at Dec. 31, 2010	1,750	6,156,675	(1,959,235)	(71,446)	(19)	4,547	4,132,272
Balance (in shares) at Dec. 31, 2010	174,996				(1)
Net income (loss)			309,613				309,613
Direct stock reinvestment and purchase plan, net of expense	1	1,807					1,808
Direct stock reinvestment and purchase plan, net of expense (in shares)	64						64
Employee stock purchase plan	1	3,533					3,534
Employee stock purchase plan (in shares)	121
Stock-based compensation activity	5	18,543	(921)		19		17,646
Stock-based compensation activity (in shares)	483				1
Other comprehensive income (loss), net of tax				(26,231)			(26,231)
Dividends			(198,258)				(198,258)
Balance at Dec. 31, 2011	$ 1,757	$ 6,180,558	$ (1,848,801)	$ (97,677)	$ 0	$ 4,547	$ 4,240,384
Balance (in shares) at Dec. 31, 2011	175,664				0

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Significant Accounting Policies (Policy)

12 Months Ended

Dec. 31, 2011

Significant Accounting Policies [Abstract]

Principles Of Consolidation

Principles of Consolidation

The accompanying consolidated financial statements include the accounts of AWW and its subsidiaries. Intercompany balances and transactions between subsidiaries have been eliminated. The Company uses the equity method to report its investments in two joint venture investments in each of which the Company holds a 50% voting interest and cannot exercise control over the operations and policies of the investments. Under the equity method, the Company records its interests as an investment and its percentage share of earnings as earnings or losses of investee.

Use Of Estimates

Use of Estimates

The preparation of consolidated financial statements in conformity with accounting principles generally accepted in the United States requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosures of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from these estimates. The Company considers benefit plan assumptions; the carrying values of goodwill and other long-lived assets, including regulatory assets; revenue recognition; and accounting for income taxes to be its critical accounting estimates. The Company's significant estimates that are particularly sensitive to change in the near term are amounts reported for pension and other postemployment benefits, contingency-related obligations and goodwill.

Regulation

Regulation

The Company's regulated utilities are subject to economic regulation by the public utility commissions and the local governments of the states in which they operate (the "Regulators"). These Regulators have allowed recovery of costs and credits which the Company has recorded as regulatory assets and liabilities. Accounting for future recovery of costs and credits as regulatory assets and liabilities is in accordance with authoritative guidance applicable to those companies whose rates are established by or are subject to approval by an independent third-party regulator. Regulated utilities defer costs and credits on the balance sheet as regulatory assets and liabilities when it is probable that those costs and credits will be recognized in the rate making process in a period different from the period in which they would have been reflected in operations by a market-based company. These deferred regulatory assets and liabilities are then reflected in the statement of operations in the period in which the costs and credits are reflected in the rates charged for service. (See Note 7)

Property, Plant And Equipment

Property, Plant and Equipment

Property, plant and equipment consist primarily of utility plant. Additions to utility plant and replacements of retirement units of property are capitalized. Costs include material, direct labor and such indirect items as engineering and supervision, payroll taxes and benefits, transportation and an allowance for funds used during construction. The costs incurred to acquire and internally develop computer software for internal use are capitalized as a unit of property. The carrying value of these costs amounted to $49,241 and $60,408 at December 31, 2011 and 2010, respectively. The cost of repairs; maintenance, including planned major maintenance activities; and minor replacements of property is charged to maintenance expense as incurred.

When units of property are replaced, retired or abandoned, the recorded value thereof is credited to the asset account and charged to accumulated depreciation. To the extent the Company recovers cost of removal or other retirement costs through rates after the retirement costs are incurred, a regulatory asset is recorded. In some cases, the Company recovers retirement costs through rates during the life of the associated asset and before the costs are incurred. These amounts result in a regulatory liability being reported based on the amounts previously recovered through customer rates, until the costs to retire those assets are incurred.

The cost of property, plant and equipment is depreciated using the straight-line average remaining life method.

Nonutility property consists primarily of buildings and equipment utilized by the Company for internal operations. This property is stated at cost, net of accumulated depreciation calculated using the straight-line method over the estimated useful lives of the assets, ranging from three to 50 years.

Cash And Cash Equivalents

Cash and Cash Equivalents

Substantially all cash is invested in interest-bearing accounts. All highly liquid investments with a maturity of three months or less when purchased are considered to be cash equivalents.

The Company had book overdrafts for certain of its disbursement accounts of $34,002 and $50,881 at December 31, 2011 and 2010, respectively. A book overdraft represents transactions that have not cleared the bank accounts at the end of the period. The Company transfers cash on an as-needed basis to fund these items as they clear the bank. The balance of the book overdraft is reported as short-term debt and the change in the book overdraft balance is reported as cash flows from financing activities.

Restricted Funds

Restricted Funds

Restricted funds primarily represent proceeds from financings for the construction and capital improvement of facilities and deposits for future services under operation and maintenance projects. The proceeds of these financings are held in escrow until the designated expenditures are incurred. Restricted funds expected to be released within 12 months subsequent to year end are classified as current.

Utility Customer Accounts Receivable

Utility Customer Accounts Receivable

Regulated utility customer accounts receivable represent amounts billed to water and wastewater customers on a cycle basis. Credit is extended based on the guidelines of the applicable Regulators and collateral is generally not required.

Allowance For Uncollectible Accounts

Allowance for Uncollectible Accounts

Allowances for uncollectible accounts are maintained for estimated probable losses resulting from the Company's inability to collect receivables from customers. Accounts that are outstanding longer than the payment terms are considered past due. A number of factors are considered in determining the allowance for uncollectible accounts, including the length of time receivables are past due and previous loss history. The Company writes off accounts when they become uncollectible. (See Note 5)

Other Receivables, Net

Other Receivables, Net

Other receivables, net consists of market-based trade accounts receivable and market-based unbilled revenues, net of a reserve for doubtful accounts, and non-utility customer receivables of the regulated subsidiaries. In determining the reserve for uncollectible market-based accounts, the Company considers the length of time the trade accounts receivable are past due and the customers' current ability to pay their obligations. Unbilled receivables are accrued when service has been provided but has not been billed to customers. (See Note 6)

Materials And Supplies

Materials and Supplies

Materials and supplies are stated at the lower of cost or net realizable value. Cost is determined using the average cost method.

Goodwill

Goodwill

Goodwill is primarily associated with the acquisitions of AWW in 2003 and E'town Corporation in 2001 (the "Acquisitions") and has been assigned to reporting units based on the fair values at the date of the Acquisitions. The Regulated Businesses segment is a single reporting unit. In the Market-Based Operations segment, the business is organized into seven reporting units for its market-based services. Goodwill is reviewed annually, or more frequently if changes in circumstances indicate the carrying value may not be recoverable. Annual impairment reviews are performed in the fourth quarter of the calendar year, in conjunction with the timing of the completion of the Company's annual strategic business plan.

The Company considers the carrying value of goodwill to be one of its critical accounting estimates. The Company believes the assumptions and other considerations used to value goodwill to be appropriate. However, if experience differs from the assumptions and considerations used in its analysis, the resulting change could have a material adverse impact on the consolidated financial statements.

No impairment charge was recorded in the Company's continuing operations for the years ended December 31, 2011 and 2010, respectively. For the year ended December 31, 2009, the Company recorded goodwill impairment charges to continuing operations of $428,036. (See Note 8)

Long-Lived Assets

Long-Lived Assets

Long-lived assets include land, buildings, equipment and long-term investments. Long-lived assets, other than investments and land, are depreciated over their estimated useful lives, and are reviewed for impairment whenever changes in circumstances indicate the carrying value of the asset may not be recoverable. Such circumstances would include items such as a significant decrease in the market value of a long-lived asset, a significant adverse change in the manner the asset is being used or planned to be used or in its physical condition, or a history of operating or cash flow losses associated with the use of the asset. In addition, changes in the expected useful life of these long-lived assets may also be an impairment indicator. When such events or changes occur, the Company estimates the fair value of the asset from future cash flows expected to result from the use and, if applicable, the eventual disposition of the assets and compares that to the carrying value of the asset. If the carrying value is greater than the fair value, an impairment loss is recorded.

The Company considers the carrying value of long-lived assets to be one of its critical accounting estimates. The Company believes the assumptions and other considerations used to evaluate the carrying value of long-lived assets to be appropriate. However, if actual experience differs from the assumptions and considerations used in its estimates, the resulting change could have a material adverse impact on the consolidated financial statements.

The key variables to determine value include assumptions regarding sales volume, rates, operating costs, labor and other benefit costs, capital additions, assumed discount rates and other economic factors. These variables require significant management judgment and include inherent uncertainties since they are forecasting future events. If such assets are considered impaired, an impairment loss is recognized equal to the amount by which the asset's carrying value exceeds its fair value.

The long-lived assets of the regulated utility subsidiaries are grouped on a separate entity basis for impairment testing as they are integrated state-wide operations that do not have the option to curtail service and generally have uniform tariffs. A regulatory asset is charged to earnings if and when future recovery in rates of that asset is no longer probable.

The Company holds other investments including investments in privately held companies and investments in joint ventures accounted for using the equity method. The Company's investments in privately held companies and joint ventures are classified as other long-term assets.

The fair values of long-term investments are dependent on the financial performance and solvency of the entities in which the Company invests, as well as volatility inherent in the external markets. If such assets are considered impaired, an impairment loss is recognized equal to the amount by which the asset's carrying value exceeds its fair value.

Advances And Contributions In Aid Of Construction

Advances and Contributions in Aid of Construction

Regulated utility subsidiaries may receive advances and contributions from customers, home builders and real estate developers to fund construction necessary to extend service to new areas. Advances for construction are refundable for limited periods of time as new customers begin to receive service or other contractual obligations are fulfilled. Included in other current liabilities at December 31, 2011 and 2010 in the accompanying Consolidated Balance Sheets are estimated refunds of $18,681 and $22,451, respectively. Those amounts represent expected refunds during the next 12-month period. Advances that are no longer refundable are reclassified to contributions in aid of construction. Contributions in aid of construction are permanent collections of plant assets or cash for a particular construction project. For ratemaking purposes, the amount of such contributions generally serves as a rate base reduction since the contributions represent non-investor supplied funds.

Generally, the Company depreciates utility plant funded by contributions and amortizes its contributions balance as a reduction to depreciation expense, producing a result which is functionally equivalent to reducing the original cost of the utility plant for the contributions. Certain of the Company's subsidiaries do not depreciate contributed property, based on regulatory guidelines. Amortization of contributions in aid of construction was $18,327, $17,423 and $16,371 for the years ended December 31, 2011, 2010 and 2009, respectively.

Recognition Of Revenues

Recognition of Revenues

Revenues of the regulated utility subsidiaries are recognized as water and wastewater services are provided and include amounts billed to customers on a cycle basis and unbilled amounts based on estimated usage from the date of the latest meter reading to the end of the accounting period.

The Company has agreements with the United States Government to operate and maintain water and wastewater systems at various military bases pursuant to 50-year contracts ("military agreements"). These contracts also include construction components that are accounted for separately from the operations and management components. The military agreements are subject to periodic price redetermination adjustments and modifications for changes in circumstance. Additionally, the Company has agreements ranging in length from two to 40 years with various industries and municipalities to operate and maintain water and wastewater systems ("O&M agreements"). Revenue from operations and management services are recognized as services are provided. (See Note 16)

Construction Contracts

Construction Contracts

Revenues from construction projects are recognized over the contract term based on the estimated percentage of completion during the period compared to the total estimated services to be provided over the entire contract. Losses on contracts are recognized during the period in which the loss first becomes probable and estimable. Revenues recognized during the period in excess of billings on construction contracts are recorded as unbilled revenue. Billings in excess of revenues recognized on construction contracts are recorded as other current liabilities until the recognition criteria are met. Changes in contract performance and related estimated contract profitability may result in revisions to costs and revenues and are recognized in the period in which revisions are determined.

Income Taxes

Income Taxes

AWW and its subsidiaries participate in a consolidated federal income tax return for U.S. tax purposes. Members of the consolidated group are charged with the amount of federal income tax expense determined as if they filed separate returns.

Certain income and expense items are accounted for in different time periods for financial reporting than for income tax reporting purposes. The Company provides deferred income taxes on the difference between the tax basis of assets and liabilities and the amounts at which they are carried in the financial statements. These deferred income taxes are based on the enacted tax rates expected to be in effect when these temporary differences are projected to reverse. In addition, the regulated utility subsidiaries recognize regulatory assets and liabilities for the effect on revenues expected to be realized as the tax effects of temporary differences, previously flowed through to customers, reverse.

Investment tax credits have been deferred by the regulated utility subsidiaries and are being amortized to income over the average estimated service lives of the related assets.

The Company recognizes accrued interest and penalties related to tax positions as a component of income tax expense and accounts for sales tax collected from customers and remitted to taxing authorities on a net basis.

Allowance For Funds Used During Construction ("AFUDC")

Allowance for Funds Used During Construction ("AFUDC")

AFUDC is a non-cash credit to income with a corresponding charge to utility plant that represents the cost of borrowed funds or a return on equity funds devoted to plant under construction. The regulated utility subsidiaries record AFUDC to the extent permitted by the Regulators.

Environmental Costs

Environmental Costs

The Company's water and wastewater operations are subject to federal, state, local and foreign requirements relating to environmental protection, and as such, the Company periodically becomes subject to environmental claims in the normal course of business. Environmental expenditures that relate to current operations or provide a future benefit are expensed or capitalized as appropriate. Remediation costs that relate to an existing condition caused by past operations are accrued, on an undiscounted basis, when it is probable that these costs will be incurred and can be reasonably estimated. Remediation costs accrued amounted to $5,500 and $6,630 at December 31, 2011 and 2010, respectively. At December 31, 2011, the entire accrual relates to a conservation agreement entered into by a subsidiary of the Company with the National Oceanic and Atmospheric Administration ("NOAA") requiring the Company to, among other provisions, implement certain measures to protect the steelhead trout and its habitat in the Carmel River watershed in the state of California. The Company paid and expensed $3,500 related to this agreement during 2009, and has agreed to pay $1,100 annually from 2010 to 2016. The Company pursues recovery of incurred costs through all appropriate means, including regulatory recovery through customer rates. The Company's regulatory assets at December 31, 2011 and 2010 include $9,187 and $10,642, respectively, related to the NOAA agreement, including an additional $3,500 granted in 2010 for recovery of the 2009 payment.

Derivative Financial Instruments

Derivative Financial Instruments

The Company uses derivative financial instruments for purposes of hedging exposures to fluctuations in interest rates. These derivative contracts are entered into for periods consistent with the related underlying exposures and do not constitute positions independent of those exposures. The Company does not enter into derivative contracts for speculative purposes and does not use leveraged instruments.

All derivatives are recognized on the balance sheet at fair value. On the date the derivative contract is entered into, the Company may designate the derivative as a hedge of the fair value of a recognized asset or liability (fair-value hedge) or a hedge of a forecasted transaction or of the variability of cash flows to be received or paid related to a recognized asset or liability (cash-flow hedge).

Changes in the fair value of a fair-value hedge, along with the gain or loss on the underlying hedged item, are recorded in current-period earnings. The effective portion of gains and losses on cash-flow hedges are recorded in other comprehensive income (loss), until earnings are affected by the variability of cash flows. Any ineffective portion of designated hedges is recognized in current-period earnings.

Cash flows from derivative contracts are included in net cash provided by operating activities.

Reclassifications

Reclassifications

Certain reclassifications for discontinued operations (see Note 3) have been made to conform previously reported data to the current presentation.

XML

Short-Term Debt (Narrative) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended							12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2011 Letter Of Credit [Member]	Dec. 31, 2010 Letter Of Credit [Member]	Dec. 31, 2011 Revolving Credit Facility [Member]	Dec. 18, 2008 The Bank Of New York Mellon [Member] Commitment Amount Through September 15, 2012 [Member]	Sep. 15, 2008 The Bank Of New York Mellon [Member] Commitment Amount Through September 15, 2013 [Member]	Dec. 31, 2011 PNC Bank, N.A. [Member]	Dec. 31, 2011 Minimum [Member]	Dec. 31, 2011 Minimum [Member] Line Of Credit [Member]	Dec. 31, 2011 Maximum [Member]	Dec. 31, 2011 Maximum [Member] Line Of Credit [Member]
Short-term Debt [Line Items]
Senior unsecured credit facility						$ 40,000	$ 685,000
Letter of credit sublimit			150,000	150,000				10,000
Letters of credit, outstanding amount	36,830				36,452
LIBOR basis points	The maximum LIBOR margin is 55 basis points
Line of credit facility consolidated debt to consolidated capitalization ratio									0.58	0.70	1.00	1.00
Revolving credit lines, borrowings	$ 0	$ 2,734
Line of credit, termination date								December 31, 2011

XML

Operating Leases (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Operating Leased Assets [Line Items]
Rental expenses under operating leases	$ 32,752	$ 36,264	$ 34,862
Minimum annual future rental commitment, 2012	21,528
Minimum annual future rental commitment, 2013	17,987
Minimum annual future rental commitment, 2014	14,833
Minimum annual future rental commitment, 2015	10,877
Minimum annual future rental commitment, 2016	9,172
Minimum annual future rental commitment, thereafter	101,472
Capital lease asset	159,211	159,707
Equipment [Member]
Operating Leased Assets [Line Items]
Operating leases expiration term, years		five
Facilities [Member]
Operating Leased Assets [Line Items]
Operating leases expiration term, years		20
Minimum annual future rental commitment, 2012	3,629
Minimum annual future rental commitment, 2013	3,668
Minimum annual future rental commitment, 2014	3,727
Minimum annual future rental commitment, 2015	3,727
Minimum annual future rental commitment, 2016	3,727
Minimum annual future rental commitment, thereafter	$ 82,620
The Partners [Member]
Operating Leased Assets [Line Items]
Operating leases expiration term, years	40

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Preferred Stock Without Mandatory Redemption Requirements (Tables)

12 Months Ended

Dec. 31, 2011

Preferred Stock Without Mandatory Redemption Requirements [Abstract]

Schedule Of Preferred Stock Agreements Without Mandatory Redemption Requirements

Dividend Yield	Balance at December 31,
	2011		2010
4.50%	$	1,720	$	1,720
5.00%		1,952		1,952
5.50%		486		486
5.75%		389		389
	$	4,547	$	4,547

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Acquisitions And Divestitures (Schedule Of Assets And Liabilities Of Discontinued Operations) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2011	Dec. 31, 2010
Acquisitions And Divestitures [Abstract]
Total property, plant and equipment	$ 833,023	$ 819,977
Current assets	21,906	20,710
Regulatory assets	43,849	39,833
Goodwill	29,608	55,107
Other	1,472	2,078
Total assets of discontinued operations	929,858	937,705
Long-term debt	11,697	17,272
Current portion of long-term debt	12,839	8,668
Other current liabilities	29,530	39,505
Advances for construction	205,034	214,045
Regulatory liabilities	4,617	7,622
Other	15,540	(4,058)
Contributions in aid of construction	102,961	90,906
Total liabilities of discontinued operations	$ 382,218	$ 373,960

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Stockholders' Equity (Weighted Average Assumptions Used) (Details) (Restricted Stock Units [Member], USD $)	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Restricted Stock Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expected volatility	29.50%	30.74%	32.00%
Risk-free interest rate	1.24%	1.50%	1.30%
Expected life (years)	3	3	3
Grant date fair value per share	$ 29.95	$ 23.23	$ 21.75

XML

Consolidated Balance Sheets (USD $) In Thousands, unless otherwise specified	Dec. 31, 2011	Dec. 31, 2010
Property, plant and equipment
Utility plant-at original cost, net of accumulated depreciation of $3,360,005 in 2011 and $3,134,094 in 2010	$ 10,872,042	$ 10,241,342
Nonutility property, net of accumulated depreciation of $164,417 in 2011 and $137,483 in 2010	149,056	140,298
Total property, plant and equipment	11,021,098	10,381,640
Current assets
Cash and cash equivalents	14,207	13,112
Restricted funds	32,438	94,066
Utility customer accounts receivable	150,720	145,747
Allowance for uncollectible accounts	(15,319)	(17,474)
Unbilled utility revenues	134,938	132,876
Other receivables, net	60,413	71,589
Income taxes receivable	7,672	6,473
Materials and supplies	28,598	27,743
Assets of discontinued operations	929,858	937,705
Other	54,134	45,938
Total current assets	1,397,659	1,457,775
Regulatory and other long-term assets
Regulatory assets	1,079,661	976,174
Restricted funds	25,503	26,718
Goodwill	1,195,069	1,195,585
Other	57,401	48,354
Total regulatory and other long-term assets	2,357,634	2,246,831
TOTAL ASSETS	14,776,391	14,086,246
Capitalization
Common stock ($.01 par value, 500,000 shares authorized, 175,664 shares outstanding in 2011 and 174,996 in 2010)	1,757	1,750
Paid-in capital	6,180,558	6,156,675
Accumulated deficit	(1,848,801)	(1,959,235)
Accumulated other comprehensive loss	(97,677)	(71,446)
Treasury stock	0	(19)
Common stockholders' equity	4,235,837	4,127,725
Preferred stock without mandatory redemption requirements	4,547	4,547
Total stockholders' equity	4,240,384	4,132,272
Long-term debt
Long-term debt	5,339,947	5,394,135
Redeemable preferred stock at redemption value	21,137	22,135
Total capitalization	9,601,468	9,548,542
Current liabilities
Short-term debt	515,050	228,905
Current portion of long-term debt	28,858	36,092
Accounts payable	243,709	188,343
Taxes accrued	36,606	36,939
Interest accrued	59,067	60,465
Liabilities of discontinued operations	382,218	373,960
Other	223,597	182,060
Total current liabilities	1,489,105	1,106,764
Regulatory and other long-term liabilities
Advances for construction	386,970	397,164
Deferred income taxes	1,288,797	1,110,250
Deferred investment tax credits	29,427	30,969
Regulatory liabilities	325,829	296,121
Accrued pension expense	411,998	413,513
Accrued postretirement benefit expense	237,086	215,217
Other	38,963	42,150
Total regulatory and other long-term liabilities	2,719,070	2,505,384
Contributions in aid of construction	966,748	925,556
Commitments and contingencies (See Note 16)
TOTAL CAPITALIZATION AND LIABILITIES	$ 14,776,391	$ 14,086,246

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Employee Benefits (Components Of General Tax Expense From Continuing Operations) (Tables)

12 Months Ended

Dec. 31, 2011

Defined Benefit Plan Disclosure [Line Items]

Schedule Of Significant Unobservable Inputs

The following table presents a reconciliation of the beginning and ending balances of the fair value measurements using significant unobservable inputs (Level 3):

	Level 3
Balance, January 1, 2011	$	141,403
Actual return on assets		(3,425	)
Transfers in(out)		10,596
Balance, December 31, 2011	$	148,574

	Level 3
Balance, January 1, 2010	$	124,938
Actual return on assets		20,381
Transfers in (out)		(3,916	)
Balance, December 31, 2010	$	141,403

Schedule Of Rollforward Changes In Benefit Obligation And Plan Assets

	Pension Benefits						Other Benefits
	2011			2010			2011			2010
Change in benefit obligation
Benefit obligation at January 1	$	1,285,456		$	1,128,162		$	590,187		$	548,139
Service cost		33,641			30,675			13,938			14,663
Interest cost		69,047			67,602			31,219			32,149
Plan participants' contributions		—			—			2,241			2,307
Amendments		0			3,762			0			(8,195	)
Actuarial (gain) loss		55,743			93,399			4,826			23,764
Gross benefits paid		(41,933	)		(38,144	)		(23,824	)		(23,989	)
Federal subsidy		—			—			1,779			1,349
Benefit obligation at December 31	$	1,401,954		$	1,285,456		$	620,366		$	590,187
Change in Plan Assets
Fair value of plan assets at January 1	$	860,973		$	695,520		$	374,403		$	312,042
Actual return on plan assets		2,529			105,078			2,619			45,305
Employer contributions		159,499			98,519			27,231			38,738
Plan participants' contributions		—			—			2,241			2,307
Benefits paid		(41,933	)		(38,144	)		(23,824	)		(23,989	)
Fair value of plan assets at December 31	$	981,068		$	860,973		$	382,670		$	374,403
Funded status at December 31	$	(420,886	)	$	(424,483	)	$	(237,696	)	$	(215,784	)
Amounts recognized in the balance sheet consist of:
Current liability	$	(1,909	)	$	(2,097	)	$	(33	)	$	(33	)
Noncurrent liability		(418,977	)		(422,386	)		(237,663	)		(215,751	)
Net amount recognized	$	(420,886	)	$	(424,483	)	$	(237,696	)	$	(215,784	)
Asset (liability) of discontinued operations included in net amount recognized above	$	(6,979	)	$	(8,873	)	$	(577	)	$	(534	)

Summary Of Accumulated Other Comprehensive Income And Regulatory Assets

	Pension Benefits				Other Benefits
	2011		2010		2011			2010
Net actuarial loss (gain)	$	409,129	$	302,357	$	164,305		$	140,453
Prior service cost (credit)		5,858		6,580		(16,864	)		(18,788	)
Net amount recognized	$	414,987	$	308,937	$	147,441		$	121,665
Regulatory assets	$	248,663	$	184,937	$	147,441		$	121,665
Accumulated other comprehensive income		166,324		124,000		—			—
	$	414,987	$	308,937	$	147,441		$	121,665

Schedule Of Accumulated And Projected Benefit Obligations

	Projected Benefit Obligation Exceeds the Fair Value of Plans' Assets
	2011		2010
Projected benefit obligation	$	1,402,000	$	1,285,000
Fair value of plan assets		981,000		861,000

	Accumulated Benefit Obligation Exceeds the Fair Value of Plans' Assets
	2011		2010
Accumulated benefit obligation	$	1,257,000	$	1,138,000
Fair value of plan assets		981,000		861,000

Schedule Of Expected Cash Flows For Pension And Postretirement Benefit Plans

	Pension Benefits		Other Benefits
2012 expected employer contributions
To plan trusts	$	126,700	$	29,983
To plan participants		1,909		33

Schedule Of Expected Benefit Payments

	Pension Benefits		Other Benefits
	Expected Benefit Payments		Expected Benefit Payments		Expected Federal Subsidy Payments
2012	$	47,139	$	26,188	$	1,814
2013		53,268		28,794		1,994
2014		59,412		31,641		2,161
2015		65,742		34,618		2,328
2016		72,373		37,581		2,515
2017—2021		458,798		228,379		15,770

Schedule Of Significant Assumptions Of Pension And Postretirement Benefit Plans

	Pension Benefits									Other Benefits
	2011			2010			2009			2011			2010			2009
Weighted-average assumptions used to determine December 31 benefit obligations
Discount rate		5.02	%		5.32	%		5.93	%		5.05	%		5.27	%		5.82	%
Rate of compensation increase		3.25	%		3.50	%		4.00	%		N/A			N/A			N/A
Medical trend		N/A			N/A			N/A			graded from 7.5% in 2012 to 5% in 2019+			graded from 8% in 2011 to 5% in 2017+			graded from 8.5% in 2010 to 5% in 2017+
Weighted-average assumptions used to determine net periodic cost
Discount rate		5.32	%		5.93	%		6.12	%		5.27	%		5.82	%		6.09	%
Expected return on plan assets		7.90	%		7.90	%		7.90	%		7.60	%		7.60	%		7.60	%
Rate of compensation increase		3.50	%		4.00	%		4.00	%		N/A			N/A			N/A
Medical trend		N/A			N/A			N/A			graded from 8% in 2011 to 5% in 2017+			graded from 8.5% in 2010 to 5% in 2017+			graded from 8% in 2009 to 5% in 2015+

Schedule Of Effect Of One Percentage Point Change In Assumed Health Care Cost Trend Rates

	One- Percentage- Point Increase		One- Percentage- Point Decrease
Effect on total of service and interest cost components	$	7,145	$	5,838
Effect on other postretirement benefit obligation	$	83,456	$	69,318

Components Of Net Periodic Benefit Costs

	2011			2010			2009
Components of net periodic pension benefit cost
Service cost	$	33,641		$	30,675		$	28,426
Interest cost		69,047			67,602			62,919
Expected return on plan assets		(72,109	)		(56,751	)		(42,224	)
Amortization of:
Prior service cost (credit)		722			322			182
Actuarial (gain) loss		18,551			17,902			23,968
Net periodic pension benefit cost	$	49,852		$	59,750		$	73,271
Other changes in plan assets and benefit obligations recognized in other comprehensive income, net of tax
Amortization of prior service credit (cost)	$	(175	)	$	(79	)	$	(46	)
Current year actuarial (gain) loss		30,497			11,836			(9,981	)
Amortization of actuarial gain (loss)		(4,504	)		(4,368	)		(5,994	)
Total recognized in other comprehensive income	$	25,818		$	7,389		$	(16,021	)
Total recognized in net periodic benefit cost and comprehensive income	$	75,670		$	67,139		$	57,250
Components of net periodic other postretirement benefit cost
Service cost	$	13,938		$	14,663		$	13,172
Interest cost		31,219			32,149			29,180
Expected return on plan assets		(28,779	)		(24,372	)		(18,638	)
Amortization of:
Transition obligation (asset)		0			173			173
Prior service cost (credit)		(1,924	)		(1,180	)		(1,180	)
Actuarial (gain) loss		7,133			8,159			9,155
Net periodic other postretirement benefit cost	$	21,587		$	29,592		$	31,862

Schedule Of Estimated Amounts Amortized Accumulated Other Comprehensive Income

	Pension Benefits		Other Benefits
Actuarial (gain) loss	$	29,923	$	9,537
Prior service cost (credit)		722		(1,914	)
Total	$	30,645	$	7,623

Pension Plan Assets [Member]

Defined Benefit Plan Disclosure [Line Items]

Schedule Of Changes In Fair Value Of Plan Assets

The fair values and asset allocations of pension plan assets at December 31, 2011, by asset category, follow:

Asset Category	Target Allocation 2012			Total		Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Percentage of Plan Assets at December 31, 2011
Cash		—		$	9,794	$	9,794		—		—		—
Equity securities:
U.S. large cap		36	%		364,025		364,025		—		—		37	%
U.S. small cap value		12	%		119,996		116,748	$	3,248		—		12	%
International		22	%		202,917		26		100,745	$	102,146		21	%
Fixed income securities:		30	%										30	%
U.S. Treasury and government bonds		—			61,278		61,278		—		—		—
Corporate bonds		—			48,564		2,487		46,077		—		—
Mortgage-backed securities		—			118,837		—		118,837		—		—
Guaranteed annuity contracts		—			55,657		—		9,229		46,428		—
Total		100	%	$	981,068	$	554,358	$	278,136	$	148,574		100	%

The fair values and asset allocations of pension plan assets at December 31, 2010, by asset category, follow:

Asset Category	Target Allocation 2011			Total		Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Percentage of Plan Assets at December 31, 2010
Cash		—		$	6,467	$	6,467		—		—		—
Equity securities:
U.S. large cap		36	%		299,548		299,548		—		—		35	%
U.S. small cap value		12	%		113,356		113,356		—		—		13	%
International		22	%		190,330		682	$	94,363	$	95,285		22	%
Fixed income securities:		30	%										30	%
U.S. Treasury and government bonds		—			63,469		63,469		—		—		—
Corporate Bonds		—			33,118		—		33,118		—		—
Mortgage-backed securities		—			99,478		—		99,478		—		—
Guaranteed annuity contracts		—			55,207		—		9,089		46,118		—
Total		100	%	$	860,973	$	483,522	$	236,048	$	141,403		100	%

Postretirement Benefit Plan Assets [Member]

Defined Benefit Plan Disclosure [Line Items]

Schedule Of Changes In Fair Value Of Plan Assets

The fair values and asset allocations of postretirement benefit plan assets at December 31, 2011, by asset category, follow:

Asset Category	Target Allocation 2012			Total		Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Percentage of Plan Assets at December 31, 2011
Cash		—		$	10,196	$	10,196		—		—		—
Equity securities:
U.S. large cap		36	%		136,625		136,625		—		—		36	%
U.S. small cap value		12	%		52,092		50,720	$	1,372		—		14	%
International		22	%		78,294		45,537		32,757		—		20	%
Fixed income securities:		30	%										30	%
U.S. Treasury securities		—			12,897		12,897		—		—		—
Corporate bonds		—			46,953		—		46,953		—		—
Mortgage-backed securities		—			45,613		—		45,613		—		—
Total		100	%	$	382,670	$	255,975	$	126,695		—		100	%

The fair values and asset allocations of postretirement benefit plan assets at December 31, 2010, by asset category, follow:

Asset Category	Target Allocation 2011			Total		Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Percentage of Plan Assets at December 31, 2010
Cash		—		$	12,500	$	12,500		—		—		—
Equity securities:
U.S. large cap		36	%		131,775		131,775		—		—		35	%
U.S. small cap value		12	%		53,898		53,898		—		—		14	%
International		22	%		77,935		77,935		—		—		21	%
Fixed income securities:		30	%										30	%
U.S. Treasury securities		—			16,025		16,025		—		—		—
Corporate Bonds		—			34,746		—	$	34,746		—		—
Mortgage-backed securities		—			47,524		—		47,524		—		—
Total		100	%	$	374,403	$	292,133	$	82,270		—		100	%

XML

Employee Benefits (Schedule Of Changes In Fair Value Of Plan Assets) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Pension Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Target Allocation, Total	100.00%	100.00%
Percentage of Plan Assets, Total	100.00%	100.00%
Fair value of plan assets	$ 981,068	$ 860,973	$ 695,520
Postretirement Benefit Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Target Allocation, Total	100.00%	100.00%
Percentage of Plan Assets, Total	100.00%	100.00%
Fair value of plan assets	382,670	374,403	312,042
Level 1 [Member] | Pension Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	554,358	483,522
Level 1 [Member] | Postretirement Benefit Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	255,975	292,133
Level 2 [Member] | Pension Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	278,136	236,048
Level 2 [Member] | Postretirement Benefit Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	126,695	82,270
Level 3 [Member] | Pension Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	148,574	141,403
Level 3 [Member] | Postretirement Benefit Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets
Level 3 [Member] | Guaranteed Annuity Contracts [Member] | Pension Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	148,574	141,403	124,938
Cash [Member] | Pension Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Target Allocation, Fixed income
Fair value of plan assets	9,794	6,467
Cash [Member] | Postretirement Benefit Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Target Allocation, Fixed income
Fair value of plan assets	10,196	12,500
Cash [Member] | Level 1 [Member] | Pension Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	9,794	6,467
Cash [Member] | Level 1 [Member] | Postretirement Benefit Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	10,196	12,500
Cash [Member] | Level 2 [Member] | Pension Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets
Cash [Member] | Level 2 [Member] | Postretirement Benefit Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets
Cash [Member] | Level 3 [Member] | Pension Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets
Cash [Member] | Level 3 [Member] | Postretirement Benefit Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets
Equity Securities [Member] | U.S. Large Cap [Member] | Pension Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Target Allocation, Equity securities	36.00%	36.00%
Percentage of Plan Assets, Equity securities	37.00%	35.00%
Fair value of plan assets	364,025	299,548
Equity Securities [Member] | U.S. Large Cap [Member] | Postretirement Benefit Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Target Allocation, Equity securities	36.00%	36.00%
Percentage of Plan Assets, Equity securities	36.00%	35.00%
Fair value of plan assets	136,625	131,775
Equity Securities [Member] | U.S. Small Cap Value [Member] | Pension Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Target Allocation, Equity securities	12.00%	12.00%
Percentage of Plan Assets, Equity securities	12.00%	13.00%
Fair value of plan assets	119,996	113,356
Equity Securities [Member] | U.S. Small Cap Value [Member] | Postretirement Benefit Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Target Allocation, Equity securities	12.00%	12.00%
Percentage of Plan Assets, Equity securities	14.00%	14.00%
Fair value of plan assets	52,092	53,898
Equity Securities [Member] | International [Member] | Pension Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Target Allocation, Equity securities	22.00%	22.00%
Percentage of Plan Assets, Equity securities	21.00%	22.00%
Fair value of plan assets	202,917	190,330
Equity Securities [Member] | International [Member] | Postretirement Benefit Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Target Allocation, Equity securities	22.00%	22.00%
Percentage of Plan Assets, Equity securities	20.00%	21.00%
Fair value of plan assets	78,294	77,935
Equity Securities [Member] | Level 1 [Member] | U.S. Large Cap [Member] | Pension Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	364,025	299,548
Equity Securities [Member] | Level 1 [Member] | U.S. Large Cap [Member] | Postretirement Benefit Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	136,625	131,775
Equity Securities [Member] | Level 1 [Member] | U.S. Small Cap Value [Member] | Pension Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	116,748	113,356
Equity Securities [Member] | Level 1 [Member] | U.S. Small Cap Value [Member] | Postretirement Benefit Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	50,720	53,898
Equity Securities [Member] | Level 1 [Member] | International [Member] | Pension Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	26	682
Equity Securities [Member] | Level 1 [Member] | International [Member] | Postretirement Benefit Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	45,537	77,935
Equity Securities [Member] | Level 2 [Member] | U.S. Large Cap [Member] | Postretirement Benefit Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets
Equity Securities [Member] | Level 2 [Member] | U.S. Small Cap Value [Member] | Pension Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	3,248
Equity Securities [Member] | Level 2 [Member] | U.S. Small Cap Value [Member] | Postretirement Benefit Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1,372
Equity Securities [Member] | Level 2 [Member] | International [Member] | Pension Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	100,745	94,363
Equity Securities [Member] | Level 2 [Member] | International [Member] | Postretirement Benefit Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	32,757
Equity Securities [Member] | Level 3 [Member] | U.S. Large Cap [Member] | Postretirement Benefit Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets
Equity Securities [Member] | Level 3 [Member] | U.S. Small Cap Value [Member] | Postretirement Benefit Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets
Equity Securities [Member] | Level 3 [Member] | International [Member] | Pension Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	102,146	95,285
Equity Securities [Member] | Level 3 [Member] | International [Member] | Postretirement Benefit Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets
Fixed Income Securities [Member] | Pension Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Target Allocation, Fixed income	30.00%	30.00%
Percentage of Plan Assets, Fixed Income	30.00%	30.00%
Fixed Income Securities [Member] | Postretirement Benefit Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Target Allocation, Fixed income	30.00%	30.00%
Percentage of Plan Assets, Fixed Income	30.00%	30.00%
Fixed Income Securities [Member] | U.S. Treasury And Government Bonds [Member] | Pension Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Target Allocation, Fixed income
Fair value of plan assets	61,278	63,469
Fixed Income Securities [Member] | U.S. Treasury And Government Bonds [Member] | Postretirement Benefit Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Target Allocation, Fixed income
Fair value of plan assets	12,897	16,025
Fixed Income Securities [Member] | Corporate Bonds [Member] | Pension Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Target Allocation, Fixed income
Fair value of plan assets	48,564	33,118
Fixed Income Securities [Member] | Corporate Bonds [Member] | Postretirement Benefit Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Target Allocation, Fixed income
Fair value of plan assets	46,953	34,746
Fixed Income Securities [Member] | Mortgage-Backed Securities [Member] | Pension Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Target Allocation, Fixed income
Fair value of plan assets	118,837	99,478
Fixed Income Securities [Member] | Mortgage-Backed Securities [Member] | Postretirement Benefit Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Target Allocation, Fixed income
Fair value of plan assets	45,613	47,524
Fixed Income Securities [Member] | Guaranteed Annuity Contracts [Member] | Pension Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Target Allocation, Fixed income
Fair value of plan assets	55,657	55,207
Fixed Income Securities [Member] | Level 1 [Member] | Postretirement Benefit Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets
Fixed Income Securities [Member] | Level 1 [Member] | U.S. Treasury And Government Bonds [Member] | Pension Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	61,278	63,469
Fixed Income Securities [Member] | Level 1 [Member] | U.S. Treasury And Government Bonds [Member] | Postretirement Benefit Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	12,897	16,025
Fixed Income Securities [Member] | Level 1 [Member] | Corporate Bonds [Member] | Pension Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	2,487
Fixed Income Securities [Member] | Level 1 [Member] | Corporate Bonds [Member] | Postretirement Benefit Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets
Fixed Income Securities [Member] | Level 1 [Member] | Mortgage-Backed Securities [Member] | Postretirement Benefit Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets
Fixed Income Securities [Member] | Level 2 [Member] | Postretirement Benefit Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets
Fixed Income Securities [Member] | Level 2 [Member] | U.S. Treasury And Government Bonds [Member] | Postretirement Benefit Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets
Fixed Income Securities [Member] | Level 2 [Member] | Corporate Bonds [Member] | Pension Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	46,077	33,118
Fixed Income Securities [Member] | Level 2 [Member] | Corporate Bonds [Member] | Postretirement Benefit Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	46,953	34,746
Fixed Income Securities [Member] | Level 2 [Member] | Mortgage-Backed Securities [Member] | Pension Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	118,837	99,478
Fixed Income Securities [Member] | Level 2 [Member] | Mortgage-Backed Securities [Member] | Postretirement Benefit Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	45,613	47,524
Fixed Income Securities [Member] | Level 2 [Member] | Guaranteed Annuity Contracts [Member] | Pension Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	9,229	9,089
Fixed Income Securities [Member] | Level 3 [Member] | Postretirement Benefit Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets
Fixed Income Securities [Member] | Level 3 [Member] | U.S. Treasury And Government Bonds [Member] | Postretirement Benefit Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets
Fixed Income Securities [Member] | Level 3 [Member] | Corporate Bonds [Member] | Postretirement Benefit Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets
Fixed Income Securities [Member] | Level 3 [Member] | Mortgage-Backed Securities [Member] | Postretirement Benefit Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets
Fixed Income Securities [Member] | Level 3 [Member] | Guaranteed Annuity Contracts [Member] | Pension Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	$ 46,428	$ 46,118

XML

Fair Values Of Financial Instruments (Recurring Fair Value Measurements) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2011	Dec. 31, 2010
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Restricted funds	$ 57,941	$ 120,784
Rabbi trust investments	518	1,552
Deposits	2,287	1,381
Mark-to-market derivative asset	5,824
Total assets	66,570	123,717
Deferred compensation obligation	9,036	9,180
Mark-to-market derivative liability		898
Total liabilities	9,036	10,078
Total net assets (liabilities)	57,534	113,639
Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Restricted funds	57,941	120,784
Deposits	2,287	1,381
Total assets	60,228	122,165
Total net assets (liabilities)	60,228	122,165
Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Rabbi trust investments	518	1,552
Mark-to-market derivative asset	5,824
Total assets	6,342	1,552
Deferred compensation obligation	9,036	9,180
Mark-to-market derivative liability		898
Total liabilities	9,036	10,078
Total net assets (liabilities)	(2,694)	(8,526)
Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Restricted funds
Rabbi trust investments
Deposits
Mark-to-market derivative asset
Total assets
Deferred compensation obligation
Mark-to-market derivative liability
Total liabilities
Total net assets (liabilities)

XML

Consolidated Statements Of Cash Flows (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
CASH FLOWS FROM OPERATING ACTIVITIES
Net income (loss)	$ 309,613	$ 267,827	$ (233,083)
Adjustments
Depreciation and amortization	351,821	330,264	309,874
Impairment charge	0	0	428,036
Provision for deferred income taxes	195,494	152,760	134,232
Amortization of deferred investment tax credits	(1,542)	(1,561)	(1,413)
Provision for losses on utility accounts receivable	16,178	17,973	20,999
Allowance for other funds used during construction	(13,131)	(9,644)	(8,342)
(Gain) loss on asset dispositions and purchases	(993)	111	(295)
Pension and non-pension post retirement benefits	71,439	89,342	105,133
Stock-based compensation expense	10,008	10,334	7,602
Other, net	44,521	9,033	21,000
Changes in assets and liabilities
Receivables and unbilled utility revenues	(17,433)	(33,044)	(18,751)
Taxes receivable, including income taxes	(1,199)	17,920	(17,920)
Other current assets	(14,917)	5,149	(6,737)
Pension and non-pension post retirement benefit contributions	(186,730)	(137,257)	(127,446)
Accounts payable	37,824	6,487	52
Taxes accrued, including income taxes	4,274	39,577	(13,321)
Interest accrued	(1,417)	746	6,499
Other current liabilities	4,547	8,916	(9,963)
Net cash provided by operating activities	808,357	774,933	596,156
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(924,858)	(765,636)	(785,265)
Acquisitions	(7,220)	(1,642)	(18,144)
Proceeds from sale of assets and securities	9,972	239	1,237
Removal costs from property, plant and equipment retirements, net	(53,134)	(43,695)	(29,900)
Net funds released	62,843	63,991	129,711
Other	0	0	(1,250)
Net cash used in investing activities	(912,397)	(746,743)	(703,611)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from long-term debt	12,510	268,559	542,926
Repayment of long-term debt	(70,045)	(272,700)	(178,131)
Proceeds from issuance of common stock (net of 2009 expenses of $7,824)	0	0	242,301
Net borrowings (repayments) under short-term debt agreements	303,024	93,029	(352,005)
Proceeds from issuances of employee stock plans and DRIP	13,866	6,711	2,089
Advances and contributions for construction, net of refunds of $21,061 in 2011, $35,830 in 2010 and $27,481 in 2009	22,298	7,042	21,211
Change in cash overdraft position	(16,862)	17,173	(7,508)
Debt issuance costs	(552)	(6,619)	(13,165)
Redemption of preferred stocks	(1,888)	(228)	(218)
Dividends paid	(157,855)	(150,301)	(137,331)
Other	639	0	0
Net cash provided by (used in) financing activities	105,135	(37,334)	120,169
Net increase (decrease) in cash and cash equivalents	1,095	(9,144)	12,714
Cash and cash equivalents at beginning of period	13,112	22,256	9,542
Cash and cash equivalents at end of period	14,207	13,112	22,256
Cash paid during the year for:
Interest, net of capitalized amount	331,944	329,417	303,958
Income taxes, net of refunds of $812 in 2011, $37,790 in 2010 and $2,754 in 2009	14,269	(30,108)	11,205
Non-cash investing activity
Capital expenditures acquired on account but unpaid as of year end	104,816	112,313	59,219
Non-cash financing activity
Advances and contributions	23,504	27,566	77,094
Long-term debt	$ 0	$ 122,775	$ 179,931

XML

Income Taxes (Changes In The Company Valuation Allowance) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009	Dec. 31, 2008
Income Taxes [Abstract]
Beginning Balance	$ 21,579	$ 23,788	$ 25,621	$ 28,862
Increases in current period tax positions	1,525	907	2,778
Decreases in current period tax positions	(3,734)	(2,740)	(5,698)
Decreases in prior period tax positions			(321)
Ending Balance	$ 21,579	$ 23,788	$ 25,621	$ 28,862

XML

Regulatory Assets And Liabilities (Narrative) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended					12 Months Ended			1 Months Ended	12 Months Ended
	Dec. 31, 2011 Debt And Preferred Stock Expense [Member] years	Dec. 31, 2011 Deferred Pension Expense [Member]	Dec. 31, 2010 Deferred Pension Expense [Member]	Dec. 31, 2011 Deferred Other Postretirement Benefit Expense [Member]	Dec. 31, 2010 Deferred Other Postretirement Benefit Expense [Member]	Dec. 31, 2011 Deferred Rate Case Expense [Member] years	Dec. 31, 2011 Coastal Water Project Costs [Member]	Dec. 31, 2010 Coastal Water Project Costs [Member]	Dec. 31, 2008 Removal Costs Recovered Through Rates [Member]	Dec. 31, 2011 Maximum [Member] Deferred Security Costs [Member] years	Dec. 31, 2011 Maximum [Member] Deferred Tank Painting Costs [Member] years	Dec. 31, 2011 Minimum [Member] Deferred Security Costs [Member] years	Dec. 31, 2011 Minimum [Member] Deferred Tank Painting Costs [Member] years
Regulatory Assets [Line Items]
Regulatory assets amortization period	30					3				10	15	5	2
Regulatory assets underfunded status		$ 243,926	$ 180,200	$ 147,441	$ 121,665
Deferred regulatory assets							2,528	7,677
Amortization of regulatory assets									$ 48,000

XML

Employee Benefits (Summary Of Accumulated Other Comprehensive Income And Regulatory Assets) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009	Dec. 31, 2012 Pension Plan Assets [Member]	Dec. 31, 2011 Pension Plan Assets [Member]	Dec. 31, 2010 Pension Plan Assets [Member]	Dec. 31, 2012 Postretirement Benefit Plan Assets [Member]	Dec. 31, 2011 Postretirement Benefit Plan Assets [Member]	Dec. 31, 2010 Postretirement Benefit Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Net actuarial loss (gain)	$ 4,504	$ 4,368	$ 5,994	$ 29,923	$ 409,129	$ 302,357	$ 9,537	$ 164,305	$ 140,453
Prior service cost (credit)				722	5,858	6,580	(1,914)	(16,864)	(18,788)
Net amount recognized				30,645	414,987	308,937	7,623	147,441	121,665
Regulatory assets					248,663	184,937		147,441	121,665
Accumulated other comprehensive income					$ 166,324	$ 124,000

XML

Allowance For Uncollectible Accounts (Tables)

12 Months Ended

Dec. 31, 2011

Allowance For Uncollectible Accounts [Abstract]

Schedule Of Allowances For Uncollectible Accounts

	2011			2010			2009
Balance at January 1	$	(17,474	)	$	(18,148	)	$	(16,859	)
Amounts charged to expense		(16,178	)		(17,973	)		(20,999	)
Amounts written off		21,855			22,124			23,104
Recoveries of amounts written off		(3,522	)		(3,477	)		(3,394	)
Balance at December 31	$	(15,319	)	$	(17,474	)	$	(18,148	)

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Stockholders' Equity (Summary Information Regarding Issuances Under DRIP) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010
Stockholders' Equity [Abstract]
Shares of common stock issued	64	63
Cash proceeds received	$ 1,827	$ 1,425

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General Taxes

12 Months Ended

Dec. 31, 2011

General Taxes [Abstract]

General Taxes

Note 13: General Taxes

Components of general tax expense from continuing operations for the years ended December 31 are as follows:

	2011		2010		2009
Gross receipts and franchise	$	90,674	$	86,063	$	79,410
Property and capital stock		77,330		78,184		70,907
Payroll		31,705		31,089		27,834
Other general		10,769		10,261		8,469
	$	210,478	$	205,597	$	186,620

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Other Receivables, Net (Tables)

12 Months Ended

Dec. 31, 2011

Other Receivables, Net [Abstract]

Components Of Other Receivables

	2011			2010
Market-based trade accounts receivable	$	26,734		$	36,357
Allowance for doubtful accounts—market-based trade accounts receivable		(3,067	)		(3,015	)
Market-based unbilled revenue		14,367			14,273
Other		22,379			23,974
	$	60,413		$	71,589

Schedule Of Market Based Allowances For Uncollectible Accounts

	2011			2010			2009
Balance at January 1	$	(3,015	)	$	(3,520	)	$	(4,622	)
Amounts charged to (expense) income		(3,583	)		(223	)		796
Amounts written off		2,886			748			476
Recoveries of amounts written off		645			(20	)		(170	)
Balance at December 31	$	(3,067	)	$	(3,015	)	$	(3,520	)

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Employee Benefits (Schedule Of Rollforward Changes In Benefit Obligation And Plan Assets) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Defined Benefit Plan Disclosure [Line Items]
Noncurrent liability allocated to discontinued operations	$ 15,540	$ (4,058)
Pension Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Benefit obligation at January 1	1,285,456	1,128,162
Service cost	33,641	30,675
Interest cost	69,047	67,602
Amendments	0	3,762
Actuarial (gain) loss	55,743	93,399
Benefit obligation at December 31	1,401,954	1,285,456
Fair value of plan assets beginning balance	860,973	695,520
Actual return on plan assets	2,529	105,078
Employer contributions	159,499	98,519
Benefits paid	(41,933)	(38,144)
Fair value of plan assets ending balance	981,068	860,973
Funded status at December 31	(420,886)	(424,483)
Current liability	(1,909)	(2,097)
Noncurrent liability	(418,977)	(422,386)
Net amount recognized	(420,886)	(424,483)
Asset (liability) of discontinued operations included in net amount recognized above	(6,979)	(8,873)
Postretirement Benefit Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Benefit obligation at January 1	590,187	548,139
Service cost	13,938	14,663	13,172
Interest cost	31,219	32,149	29,180
Plan participants' contributions	2,241	2,307
Amendments	0	(8,195)
Actuarial (gain) loss	4,826	23,764
Federal subsidy	1,779	1,349
Benefit obligation at December 31	620,366	590,187	548,139
Fair value of plan assets beginning balance	374,403	312,042
Actual return on plan assets	2,619	45,305
Employer contributions	27,231	38,738
Benefits paid	(23,824)	(23,989)
Fair value of plan assets ending balance	382,670	374,403	312,042
Funded status at December 31	(237,696)	(215,784)
Current liability	(33)	(33)
Noncurrent liability	(237,663)	(215,751)
Net amount recognized	(237,696)	(215,784)
Asset (liability) of discontinued operations included in net amount recognized above	$ (577)	$ (534)

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Employee Benefits

12 Months Ended

Dec. 31, 2011

Employee Benefits [Abstract]

Employee Benefits

Note 15: Employee Benefits

Pension and Other Postretirement Benefits

The Company maintains noncontributory defined benefit pension plans covering eligible non-union employees of its regulated utility and shared services operations. Benefits under the plans are based on the employee's years of service and compensation. The pension plans have been closed for most employees hired on or after January 1, 2006. Union employees hired on or after January 1, 2001 had their accrued benefit frozen and will be able to receive this benefit as a lump sum upon termination or retirement. Union employees hired on or after January 1, 2001 and non-union employees hired on or after January 1, 2006 are provided with a 5.25% of base pay defined contribution plan.

The Company's funding policy is to contribute at least the minimum amount required by the Employee Retirement Income Security Act of 1974 and also an additional contribution if needed to avoid "at risk" status and benefit restrictions under the Pension Protection Act of 2006. The Company may also increase its contributions, if appropriate, to its tax and cash position and the plan's funded position. Pension plan assets are invested in a number of investments including equity and bond mutual funds, fixed income securities and guaranteed interest contracts with insurance companies.

Pension expense in excess of the amount contributed to the pension plans is deferred by certain regulated subsidiaries pending future recovery in rates charged for utility services as contributions are made to the plans. (See Note 7)

The Company also has several unfunded noncontributory supplemental non-qualified pension plans that provide additional retirement benefits to certain employees.

The Company maintains postretirement benefit plans providing varying levels of medical and life insurance to eligible retirees. The retiree welfare plans are closed for union employees hired on or after January 1, 2006. The plans had previously closed for non-union employees hired on or after January 1, 2002.

The Company's policy is to fund postretirement benefit costs for rate-making purposes. Plan assets are invested in equity and bond mutual funds.

The obligations of the plans are dominated by obligations for active employees. Because the timing of expected benefit payments is so far in the future and the size of the plan assets are small relative to the Company's assets, the investment strategy is to allocate a large portion of assets to equities, which the Company believes will provide the highest return over the long-term period. The fixed income assets are invested in long duration debt securities in order to better match the duration of the plan liability.

The Company periodically conducts an asset liability modeling study to ensure the investment strategy is aligned with the profile of the obligations. The long-term goals are to maximize the plan funded status and minimize contributions and pension expense, while taking into account the potential volatility risks on each of these items.

None of the Company's securities are included in pension or other postretirement benefit plan assets.

The investment policy guidelines of the pension plan require that the fixed income portfolio has an overall weighted average credit rating of AA or better by Standard & Poor's and the minimum credit quality for fixed income securities must be BBB- or better. Up to 20% of the portfolio may be invested in collateralized mortgage obligations backed by the United States Government.

The fair values and asset allocations of pension plan assets at December 31, 2011, by asset category, follow:

Asset Category	Target Allocation 2012			Total		Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Percentage of Plan Assets at December 31, 2011
Cash		—		$	9,794	$	9,794		—		—		—
Equity securities:
U.S. large cap		36	%		364,025		364,025		—		—		37	%
U.S. small cap value		12	%		119,996		116,748	$	3,248		—		12	%
International		22	%		202,917		26		100,745	$	102,146		21	%
Fixed income securities:		30	%										30	%
U.S. Treasury and government bonds		—			61,278		61,278		—		—		—
Corporate bonds		—			48,564		2,487		46,077		—		—
Mortgage-backed securities		—			118,837		—		118,837		—		—
Guaranteed annuity contracts		—			55,657		—		9,229		46,428		—
Total		100	%	$	981,068	$	554,358	$	278,136	$	148,574		100	%

The following table presents a reconciliation of the beginning and ending balances of the fair value measurements using significant unobservable inputs (Level 3):

	Level 3
Balance, January 1, 2011	$	141,403
Actual return on assets		(3,425	)
Transfers in(out)		10,596
Balance, December 31, 2011	$	148,574

The fair values and asset allocations of pension plan assets at December 31, 2010, by asset category, follow:

Asset Category	Target Allocation 2011			Total		Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Percentage of Plan Assets at December 31, 2010
Cash		—		$	6,467	$	6,467		—		—		—
Equity securities:
U.S. large cap		36	%		299,548		299,548		—		—		35	%
U.S. small cap value		12	%		113,356		113,356		—		—		13	%
International		22	%		190,330		682	$	94,363	$	95,285		22	%
Fixed income securities:		30	%										30	%
U.S. Treasury and government bonds		—			63,469		63,469		—		—		—
Corporate Bonds		—			33,118		—		33,118		—		—
Mortgage-backed securities		—			99,478		—		99,478		—		—
Guaranteed annuity contracts		—			55,207		—		9,089		46,118		—
Total		100	%	$	860,973	$	483,522	$	236,048	$	141,403		100	%

The following table presents a reconciliation of the beginning and ending balances of the fair value measurements using significant unobservable inputs (Level 3):

	Level 3
Balance, January 1, 2010	$	124,938
Actual return on assets		20,381
Transfers in (out)		(3,916	)
Balance, December 31, 2010	$	141,403

The Company's other postretirement benefit plans are partially funded and plan assets are invested in a manner consistent with the pension plan investment policy.

The fair values and asset allocations of postretirement benefit plan assets at December 31, 2011, by asset category, follow:

Asset Category	Target Allocation 2012			Total		Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Percentage of Plan Assets at December 31, 2011
Cash		—		$	10,196	$	10,196		—		—		—
Equity securities:
U.S. large cap		36	%		136,625		136,625		—		—		36	%
U.S. small cap value		12	%		52,092		50,720	$	1,372		—		14	%
International		22	%		78,294		45,537		32,757		—		20	%
Fixed income securities:		30	%										30	%
U.S. Treasury securities		—			12,897		12,897		—		—		—
Corporate bonds		—			46,953		—		46,953		—		—
Mortgage-backed securities		—			45,613		—		45,613		—		—
Total		100	%	$	382,670	$	255,975	$	126,695		—		100	%

The fair values and asset allocations of postretirement benefit plan assets at December 31, 2010, by asset category, follow:

Asset Category	Target Allocation 2011			Total		Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Percentage of Plan Assets at December 31, 2010
Cash		—		$	12,500	$	12,500		—		—		—
Equity securities:
U.S. large cap		36	%		131,775		131,775		—		—		35	%
U.S. small cap value		12	%		53,898		53,898		—		—		14	%
International		22	%		77,935		77,935		—		—		21	%
Fixed income securities:		30	%										30	%
U.S. Treasury securities		—			16,025		16,025		—		—		—
Corporate Bonds		—			34,746		—	$	34,746		—		—
Mortgage-backed securities		—			47,524		—		47,524		—		—
Total		100	%	$	374,403	$	292,133	$	82,270		—		100	%

Valuation Techniques Used to Determine Fair Value

Cash—Cash and investments with maturities of three months or less when purchased, including certain short-term fixed-income securities, are considered cash and are included in the recurring fair value measurements hierarchy as Level 1.

Equity securities—With respect to equity securities, the trustees obtain prices from pricing services, whose prices are obtained from direct feeds from market exchanges, which the Company is able to independently corroborate. Equity securities are valued based on quoted prices in active markets and categorized as Level 1.

Fixed-income securities—U.S. Treasury securities and government bonds have been categorized in Level 1 because they trade in highly-liquid and transparent markets that the Company can corroborate. The fair values of corporate bonds, mortgage backed securities and a certain guaranteed annuity contract are based on evaluated prices that reflect observable market information, such as actual trade information of similar securities and have been categorized as Level 2 because the valuations are calculated using models which utilize actively traded market data that the Company can corroborate. Certain other guaranteed annuity contracts are invested in a commingled fund and categorized as Level 3 because the investments are not publicly quoted. The fund administrator values the fund using the net asset value per fund share, derived from the quoted prices in active markets of the underlying securities. Since these valuation inputs are not highly observable, the commingled funds have been categorized as Level 3.

In 2011, after a review of the underlying pension investments, the Company began classifying certain international equity securities as Level 2 and Level 3 and reclassified the prior years' presentations to conform to the 2011 presentation.

The following table provides a rollforward of the changes in the benefit obligation and plan assets for the most recent two years for all plans combined:

	Pension Benefits						Other Benefits
	2011			2010			2011			2010
Change in benefit obligation
Benefit obligation at January 1	$	1,285,456		$	1,128,162		$	590,187		$	548,139
Service cost		33,641			30,675			13,938			14,663
Interest cost		69,047			67,602			31,219			32,149
Plan participants' contributions		—			—			2,241			2,307
Amendments		0			3,762			0			(8,195	)
Actuarial (gain) loss		55,743			93,399			4,826			23,764
Gross benefits paid		(41,933	)		(38,144	)		(23,824	)		(23,989	)
Federal subsidy		—			—			1,779			1,349
Benefit obligation at December 31	$	1,401,954		$	1,285,456		$	620,366		$	590,187
Change in Plan Assets
Fair value of plan assets at January 1	$	860,973		$	695,520		$	374,403		$	312,042
Actual return on plan assets		2,529			105,078			2,619			45,305
Employer contributions		159,499			98,519			27,231			38,738
Plan participants' contributions		—			—			2,241			2,307
Benefits paid		(41,933	)		(38,144	)		(23,824	)		(23,989	)
Fair value of plan assets at December 31	$	981,068		$	860,973		$	382,670		$	374,403
Funded status at December 31	$	(420,886	)	$	(424,483	)	$	(237,696	)	$	(215,784	)
Amounts recognized in the balance sheet consist of:
Current liability	$	(1,909	)	$	(2,097	)	$	(33	)	$	(33	)
Noncurrent liability		(418,977	)		(422,386	)		(237,663	)		(215,751	)
Net amount recognized	$	(420,886	)	$	(424,483	)	$	(237,696	)	$	(215,784	)
Asset (liability) of discontinued operations included in net amount recognized above	$	(6,979	)	$	(8,873	)	$	(577	)	$	(534	)

The following table provides the components of the Company's accumulated other comprehensive income and regulatory assets that have not been recognized as components of periodic benefit costs as of December 31:

	Pension Benefits				Other Benefits
	2011		2010		2011			2010
Net actuarial loss (gain)	$	409,129	$	302,357	$	164,305		$	140,453
Prior service cost (credit)		5,858		6,580		(16,864	)		(18,788	)
Net amount recognized	$	414,987	$	308,937	$	147,441		$	121,665
Regulatory assets	$	248,663	$	184,937	$	147,441		$	121,665
Accumulated other comprehensive income		166,324		124,000		—			—
	$	414,987	$	308,937	$	147,441		$	121,665

At December 31, 2011 and 2010, the projected benefit obligation, accumulated benefit obligation and fair value of plan assets for pension plans with a projected obligation in excess of plan assets were as follows:

	Projected Benefit Obligation Exceeds the Fair Value of Plans' Assets
	2011		2010
Projected benefit obligation	$	1,402,000	$	1,285,000
Fair value of plan assets		981,000		861,000

	Accumulated Benefit Obligation Exceeds the Fair Value of Plans' Assets
	2011		2010
Accumulated benefit obligation	$	1,257,000	$	1,138,000
Fair value of plan assets		981,000		861,000

The accumulated postretirement benefit obligation exceeds plan assets for all of the Company's other postretirement benefit plans.

In August 2006, the Pension Protection Act ("PPA") was signed into law in the U.S. The PPA replaces the funding requirements for defined benefit pension plans by requiring that defined benefit plans contribute to 100% of the current liability funding target over seven years. Defined benefit plans with a funding status of less than 80% of the current liability are defined as being "at risk" and additional funding requirements and benefit restrictions may apply. The PPA was effective for the 2008 plan year with short-term phase-in provisions for both the funding target and at-risk determination. The Company's qualified defined benefit plan is currently funded above the at-risk threshold, and therefore the Company expects that the plans will not be subject to the "at risk" funding requirements of the PPA. The Company is proactively monitoring the plan's funded status and projected contributions under the new law to appropriately manage the potential impact on cash requirements.

Minimum funding requirements for the qualified defined benefit pension plan are determined by government regulations and not by accounting pronouncements. The Company plans to contribute amounts at least equal to the minimum required contributions in 2012 to the qualified pension plans. The Company plans to contribute its 2012 other postretirement benefit cost for rate-making purposes.

Information about the expected cash flows for the pension and postretirement benefit plans is as follows:

	Pension Benefits		Other Benefits
2012 expected employer contributions
To plan trusts	$	126,700	$	29,983
To plan participants		1,909		33

The Company made 2012 contributions to fund pension benefits and other benefits of $32,931 and $7,496, respectively, through February 2012.

The following table reflects the net benefits expected to be paid from the plan assets or the Company's assets:

	Pension Benefits		Other Benefits
	Expected Benefit Payments		Expected Benefit Payments		Expected Federal Subsidy Payments
2012	$	47,139	$	26,188	$	1,814
2013		53,268		28,794		1,994
2014		59,412		31,641		2,161
2015		65,742		34,618		2,328
2016		72,373		37,581		2,515
2017—2021		458,798		228,379		15,770

Because the above amounts are net benefits, plan participants' contributions have been excluded from the expected benefits.

Accounting for pensions and other postretirement benefits requires an extensive use of assumptions about the discount rate, expected return on plan assets, the rate of future compensation increases received by the Company's employees, mortality, turnover and medical costs. Each assumption is reviewed annually. The assumptions are selected to represent the average expected experience over time and may differ in any one year from actual experience due to changes in capital markets and the overall economy. These differences will impact the amount of pension and other postretirement benefit expense that the Company recognizes.

The significant assumptions related to the Company's pension and other postretirement benefit plans are as follows:

	Pension Benefits									Other Benefits
	2011			2010			2009			2011			2010			2009
Weighted-average assumptions used to determine December 31 benefit obligations
Discount rate		5.02	%		5.32	%		5.93	%		5.05	%		5.27	%		5.82	%
Rate of compensation increase		3.25	%		3.50	%		4.00	%		N/A			N/A			N/A
Medical trend		N/A			N/A			N/A			graded from 7.5% in 2012 to 5% in 2019+			graded from 8% in 2011 to 5% in 2017+			graded from 8.5% in 2010 to 5% in 2017+
Weighted-average assumptions used to determine net periodic cost
Discount rate		5.32	%		5.93	%		6.12	%		5.27	%		5.82	%		6.09	%
Expected return on plan assets		7.90	%		7.90	%		7.90	%		7.60	%		7.60	%		7.60	%
Rate of compensation increase		3.50	%		4.00	%		4.00	%		N/A			N/A			N/A
Medical trend		N/A			N/A			N/A			graded from 8% in 2011 to 5% in 2017+			graded from 8.5% in 2010 to 5% in 2017+			graded from 8% in 2009 to 5% in 2015+

N/A—Assumption is not applicable.

The discount rate assumption was determined for the pension and postretirement benefit plans independently. At year end 2011, the Company began using an approach that approximates the process of settlement of obligations tailored to the plans' expected cash flows by matching the plans' cash flows to the coupons and expected maturity values of individually selected bonds. The yield curve was developed for a universe containing the majority of U.S.-issued Aa-graded corporate bonds, all of which were non callable (or callable with make-whole provisions). Historically, for each plan, the discount rate was developed as the level equivalent rate that would produce the same present value as that using spot rates aligned with the projected benefit payments.

The expected long-term rate of return on plan assets is based on historical and projected rates of return for current and planned asset classes in the plans' investment portfolios. Assumed projected rates of return for each of the plans' projected asset classes were selected after analyzing historical experience and future expectations of the returns and volatility of the various asset classes. Based on the target asset allocation for each asset class, the overall expected rate of return for the portfolio was developed, adjusted for historical and expected experience of active portfolio management results compared to the benchmark returns and for the effect of expenses paid from plan assets. The Company's pension expense increases as the expected return on assets decreases.

Assumed health care cost trend rates have a significant effect on the amounts reported for the other postretirement benefit plans. The health care cost trend rate is based on historical rates and expected market conditions. A one-percentage-point change in assumed health care cost trend rates would have the following effects:

	One- Percentage- Point Increase		One- Percentage- Point Decrease
Effect on total of service and interest cost components	$	7,145	$	5,838
Effect on other postretirement benefit obligation	$	83,456	$	69,318

The following table provides the components of net periodic benefit costs for the years ended December 31:

	2011			2010			2009
Components of net periodic pension benefit cost
Service cost	$	33,641		$	30,675		$	28,426
Interest cost		69,047			67,602			62,919
Expected return on plan assets		(72,109	)		(56,751	)		(42,224	)
Amortization of:
Prior service cost (credit)		722			322			182
Actuarial (gain) loss		18,551			17,902			23,968
Net periodic pension benefit cost	$	49,852		$	59,750		$	73,271
Other changes in plan assets and benefit obligations recognized in other comprehensive income, net of tax
Amortization of prior service credit (cost)	$	(175	)	$	(79	)	$	(46	)
Current year actuarial (gain) loss		30,497			11,836			(9,981	)
Amortization of actuarial gain (loss)		(4,504	)		(4,368	)		(5,994	)
Total recognized in other comprehensive income	$	25,818		$	7,389		$	(16,021	)
Total recognized in net periodic benefit cost and comprehensive income	$	75,670		$	67,139		$	57,250
Components of net periodic other postretirement benefit cost
Service cost	$	13,938		$	14,663		$	13,172
Interest cost		31,219			32,149			29,180
Expected return on plan assets		(28,779	)		(24,372	)		(18,638	)
Amortization of:
Transition obligation (asset)		0			173			173
Prior service cost (credit)		(1,924	)		(1,180	)		(1,180	)
Actuarial (gain) loss		7,133			8,159			9,155
Net periodic other postretirement benefit cost	$	21,587		$	29,592		$	31,862

The Company's policy is to recognize curtailments when the total expected future service of plan participants is reduced by greater than 10% due to an event that results in terminations and/or retirements.

The estimated amounts that will be amortized from accumulated other comprehensive income and regulatory assets into net periodic benefit cost in 2012 are as follows:

	Pension Benefits		Other Benefits
Actuarial (gain) loss	$	29,923	$	9,537
Prior service cost (credit)		722		(1,914	)
Total	$	30,645	$	7,623

Savings Plans for Employees

The Company maintains 401(k) savings plans that allow employees to save for retirement on a tax-deferred basis. Employees can make contributions that are invested at their direction in one or more funds. The Company makes matching contributions based on a percentage of an employee's contribution, subject to certain limitations. Due to the Company's discontinuing new entrants into the defined benefit pension plan, on January 1, 2006 the Company began providing an additional 5.25% of base pay defined contribution benefit for union employees hired on or after January 1, 2001 and non-union employees hired on or after January 1, 2006. The Company expensed contributions to the plans totaling $8,997 for 2011, $8,651 for 2010, and $8,082 for 2009, respectively. All of the Company's contributions are invested in one or more funds at the direction of the employee.

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Stockholders' Equity (Schedule Of Stock-Based Compensation Expense) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation in operation and maintenance expense	$ 10,008	$ 10,334	$ 7,602
Income tax benefit	(3,903)	(4,030)	(2,965)
After-tax stock-based compensation expense	6,105	6,304	4,637
Stock Option [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation in operation and maintenance expense	3,182	4,116	3,415
Restricted Stock Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation in operation and maintenance expense	6,340	5,863	3,799
Income tax benefit	(99)	(15)	2
Employee Stock Purchase Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation in operation and maintenance expense	$ 486	$ 355	$ 388

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Earnings (Loss) Per Common Share (Reconciliation Of Net Income (Loss) And Weighted Average Common Shares Outstanding For Calculating Basic Net Income (Loss) Per Share) (Details) (USD $) In Thousands, except Per Share data, unless otherwise specified	3 Months Ended								12 Months Ended
	Dec. 31, 2011	Sep. 30, 2011	Jun. 30, 2011	Mar. 31, 2011	Dec. 31, 2010	Sep. 30, 2010	Jun. 30, 2010	Mar. 31, 2010	Dec. 31, 2011		Dec. 31, 2010		Dec. 31, 2009
Earnings (Loss) Per Common Share [Abstract]
Income (loss) from continuing operations	$ 60,918	$ 128,495	$ 74,817	$ 40,699	$ 38,346	$ 119,327	$ 68,071	$ 29,328	$ 304,929		$ 255,072		$ (219,998)
Income (loss) from discontinued operations, net of tax									4,684		12,755		(13,085)
Net income (loss)	64,848	137,422	81,110	26,233	40,154	124,114	72,751	30,808	309,613		267,827		(233,083)
Less: Distributed earnings to common shareholders									158,708		150,724		137,597
Less: Distributed earnings to participating securities									68		51		0
Undistributed earnings									150,837		117,052		(370,680)
Undistributed earnings allocated to common shareholders									150,772		117,014		(370,680)
Undistributed earnings allocated to participating securities									65		38		0
Total income (loss) from continuing operations available to common shareholders, basic									304,796		254,983		(219,998)
Total income (loss) available to common shareholders, basic									$ 309,480		$ 267,738		$ (233,083)
Weighted average common shares outstanding, basic									175,484		174,833		168,164
Income (loss) from continuing operations	$ 0.35	$ 0.73	$ 0.43	$ 0.23	$ 0.22	$ 0.68	$ 0.39	$ 0.17	$ 1.74	[1]	$ 1.46	[1]	$ (1.31)	[1]
Income (loss) from discontinued operations, net of tax									$ 0.03	[1]	$ 0.07	[1]	$ (0.08)	[1]
Net income (loss)	$ 0.37	$ 0.78	$ 0.46	$ 0.15	$ 0.23	$ 0.71	$ 0.42	$ 0.18	$ 1.76	[1]	$ 1.53	[1]	$ (1.39)	[1]

[1] Amounts may not sum due to rounding.

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Consolidated Statements Of Cash Flows (Parenthetical) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Consolidated Statements Of Cash Flows [Abstract]
Proceeds from issuance of common stock, expenses			$ 7,824
Advances and contributions for construction, refunds	21,061	35,830	27,481
Income taxes, refunds	$ 812	$ 37,790	$ 2,754

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Consolidated Balance Sheets (Parenthetical) (USD $) In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2011	Dec. 31, 2010
Consolidated Balance Sheets [Abstract]
Utility plant, accumulated depreciation	$ 3,360,005	$ 3,134,094
Nonutility property, accumulated depreciation	$ 164,417	$ 137,483
Common stock, par value	$ 0.01	$ 0.01
Common stock, shares authorized	500,000	500,000
Common stock, shares outstanding	175,664	174,996

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Goodwill

12 Months Ended

Dec. 31, 2011

Goodwill [Abstract]

Goodwill

Note 8: Goodwill

The Company's annual impairment reviews are performed as of November 30 of each year, in conjunction with the completion of the Company's annual strategic business plan. At November 30, 2011, the Company's goodwill was $1,195,069. The Company also undertakes interim reviews when the Company determines that a triggering event that would more likely than not reduce the fair value of a reporting unit below its carrying value has occurred.

The Company uses a two-step impairment test to identify potential goodwill impairment and measure the amount of a goodwill impairment loss to be recognized (if any). The step 1 calculation used to identify potential impairment compares the calculated fair value for each of the Company's reporting units to their respective net carrying values (book values), including goodwill, on the measurement date. If the fair value of any reporting unit is less than such reporting unit's carrying value, then step 2 is performed to measure the amount of the impairment loss (if any) for such reporting unit.

The step 2 calculation of the impairment test compares, by reporting unit, the implied fair value of the goodwill to the carrying value of goodwill. The implied fair value of goodwill is equal to the excess of the fair value of each reporting unit above the fair value of such reporting unit's identified assets and liabilities. If the carrying value of goodwill exceeds the implied fair value of goodwill for any reporting unit, an impairment loss is recognized in an amount equal to the excess (not to exceed the carrying value of goodwill) for that reporting unit.

The determination of the fair value of each reporting unit and the fair value of each reporting unit's assets and liabilities is performed as of the measurement date using observable market data before and after the measurement date (if that subsequent information is relevant to the fair value on the measurement date).

For the November 30, 2011 impairment test, the estimated fair value of each reporting unit for step 1 was based on a combination of the following valuation techniques:

• observable trading prices of comparable equity securities considered to be the Company's peers; and

• discounted cash flow models developed from the Company's internal forecasts.

The first valuation technique applies average peer multiples to each reporting unit's historic and forecasted cash flows. The peer multiples are calculated using the average trading prices of comparable equity securities, their published cash flows and forecasts of market prices and cash flows for those peers.

The second valuation technique forecasts each reporting unit's five-year cash flows using an estimated long-term growth rate and discounts these cash flows at their respective estimated weighted average cost of capital.

The Company has completed its November 30, 2011 annual impairment review. Based on this review, the Company's goodwill balance was not impaired. The Company's fair value calculated in its 2011 impairment test period was greater than the aggregate carrying value of its reporting units.

However, there can be no assurances that the Company will not be required to recognize an impairment of goodwill in the future due to market conditions or other factors related to the Company's performance. These market events could include a decline over a period of time of the Company's stock price, a decline over a period of time in valuation multiples of comparable water utilities, the lack of an increase in the Company's market price consistent with its peer companies, or decreases in control premiums. A decline in the forecasted results in the Company's business plan, such as changes in rate case results or capital investment budgets or changes in the Company's interest rates, could also result in an impairment charge.

The Company also made certain assumptions, which it believes to be appropriate, that support the fair value of its reporting units. The Company considered, in addition to the listed trading price of the Company's shares, the applicability of a control premium to the Company's shares and certain other factors the Company deemed appropriate. As a result, the Company concluded that the Company's fair value exceeds what the Company might otherwise have concluded had it relied on market price alone.

The difference between the Company's calculated market capitalization (which approximates carrying value) and the aggregate fair value of reporting units resulted from an estimated control premium. The estimated control premium represents the incremental premium a buyer is willing to pay to acquire a controlling, majority interest in the Company. In estimating the control premium, management principally considered the current market conditions and historical premiums paid in utility acquisitions observed in the marketplace.

No impairment charge was recorded to the Company's continuing operations for the years ended December 31, 2011 and 2010, respectively. For the year ended December 31, 2009, the Company recorded impairment charges for goodwill in the amount of $428,036.

The change in the Company's goodwill assets, as allocated between the reporting units is as follows:

	Regulated Unit						Market-Based Units					Consolidated
	Cost			Accumulated Impairment			Cost		Accumulated Impairment			Cost			Accumulated Impairment			Total Net
Balance at January 1, 2010	$	3,399,848		$	(2,332,670	)	$	235,715	$	(107,619	)	$	3,635,563		$	(2,440,289	)	$	1,195,274
Reclassifications and other activity		36			0			275		0			311			0			311
Balance at December 31, 2010	$	3,399,884		$	(2,332,670	)	$	235,990	$	(107,619	)	$	3,635,874		$	(2,440,289	)	$	1,195,585
Reclassifications and other activity		(516	)		0			0		0			(516	)		0			(516	)
Balance at December 31, 2011	$	3,399,368		$	(2,332,670	)	$	235,990	$	(107,619	)	$	3,635,358		$	(2,440,289	)	$	1,195,069

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Employee Benefits (Schedule Of Significant Assumptions Of Pension And Postretirement Benefit Plans) (Details)	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Pension Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Weighted-average assumptions used to determine benefit obligations, Discount rate	5.02%	5.32%	5.93%
Weighted-average assumptions used to determine benefit obligations, Rate of compensation increase	3.25%	3.50%	4.00%
Weighted-average assumptions used to determine net periodic cost, Discount rate	5.32%	5.93%	6.12%
Weighted-average assumptions used to determine net periodic cost, Expected return on plan assets	7.90%	7.90%	7.90%
Weighted-average assumptions used to determine net periodic cost, Rate of compensation increase	3.50%	4.00%	4.00%
Postretirement Benefit Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Weighted-average assumptions used to determine benefit obligations, Discount rate	5.05%	5.27%	5.82%
Weighted-average assumptions used to determine benefit obligations, Rate of compensation increase
Weighted-average assumptions used to determine net periodic cost, Discount rate	5.27%	5.82%	6.09%
Weighted-average assumptions used to determine net periodic cost, Expected return on plan assets	7.60%	7.60%	7.60%
Weighted-average assumptions used to determine net periodic cost, Rate of compensation increase
Minimum [Member] | Pension Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Weighted-average assumptions used to determine benefit obligation and net periodic cost, Medical Trend Rate	8.00%	8.50%	8.00%
Minimum [Member] | Postretirement Benefit Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Weighted-average assumptions used to determine benefit obligation and net periodic cost, Medical Trend Rate	7.50%	8.00%	8.50%
Weighted-average assumptions used to determine benefit obligation and net periodic cost, Year Reaches Medical Trend Rate	2012	2011	2010
Maximum [Member] | Pension Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Weighted-average assumptions used to determine benefit obligation and net periodic cost, Medical Trend Rate	5.00%	5.00%	5.00%
Maximum [Member] | Postretirement Benefit Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Weighted-average assumptions used to determine benefit obligation and net periodic cost, Medical Trend Rate	5.00%	5.00%	5.00%
Weighted-average assumptions used to determine benefit obligation and net periodic cost, Year Reaches Medical Trend Rate	2019	2017	2017

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Income Taxes (Changes In Company Gross Liability Excluding Interest And Penalties For Unrecognized Tax Benefits) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010
Income Taxes [Abstract]
Beginning Balance	$ 118,314	$ 112,021
Increases in current period tax positions	46,961	7,434
Decreases due to lapse of statute of limitations	(6,697)	(1,141)
Ending Balance	$ 158,578	$ 118,314

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Income Taxes (Reconciliation Of Income Tax Expense From Continuing Operations) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Income Taxes [Abstract]
Income tax at statutory rate	$ 176,288	$ 150,298	$ (37,172)
State taxes, net of federal taxes	24,027	23,241	11,482
Change in valuation allowance	(160)	(533)	(6,578)
Flow through differences	2,895	2,807	2,760
Amortization of deferred investment tax credits	(1,542)	(1,561)	(1,413)
Subsidiary preferred dividends	668	675	680
Impairment charges	0	0	143,321
Other, net	(3,425)	(575)	712
Actual income tax expense	$ 198,751	$ 174,352	$ 113,792

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Document And Entity Information (USD $)	12 Months Ended
	Dec. 31, 2011	Feb. 21, 2012	Jun. 30, 2011
Document And Entity Information [Abstract]
Document Type	10-K
Amendment Flag	false
Document Period End Date	Dec. 31, 2011
Document Fiscal Year Focus	2011
Document Fiscal Period Focus	FY
Trading Symbol	awk
Entity Registrant Name	American Water Works Company, Inc.
Entity Central Index Key	0001410636
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		175,717,124
Entity Well-known Seasoned Issuer	Yes
Entity Public Float			$ 5,166,650,955
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No

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Stockholders' Equity

12 Months Ended

Dec. 31, 2011

Stockholders' Equity [Abstract]

Stockholders' Equity

Note 9: Stockholders' Equity

Common Stock

In March 2010, the Company established American Water Stock Direct, a dividend reinvestment and direct stock purchase plan (the "DRIP"). Under the DRIP, stockholders may reinvest cash dividends and purchase additional Company common stock, up to certain limits, through a transfer agent without commission fees. The Company's transfer agent may buy newly issued shares directly from the Company or shares held in the Company's treasury. The transfer agent may also buy shares in the public markets or in privately negotiated transactions. Purchases generally are made and credited to DRIP accounts once each week. As of December 31, 2011, there were 4,873 shares available for future issuance under the DRIP. The following table summarizes information regarding issuances under the DRIP for the years ended December 31, 2011 and 2010:

	2011		2010
Shares of common stock issued		64		63
Cash proceeds received	$	1,827	$	1,425

Cash dividend payments made during 2011 and 2010 were as follows:

	2011		2010
Dividends per share, three months ended:
March 31	$	0.22	$	0.21
June 30		0.22		0.21
September 30		0.23		0.22
December 31		0.23		0.22
Total dividends paid, three months ended:
March 31	$	38,525	$	36,679
June 30		38,580		36,689
September 30		40,358		38,457
December 31		40,392		38,476

On December 9, 2011, the Company declared a quarterly cash dividend payment of $0.23 per share payable on March 1, 2012 to all shareholders of record as of February 3, 2012. As of December 31, 2011, the Company had accrued dividends totaling $40,403 included in Other current liabilities in the accompanying Consolidated Balance Sheets.

Accumulated Other Comprehensive Loss

The following table presents accumulated other comprehensive loss:

	2011			2010
Employee benefit plans funded status adjustments	$	(101,457	)	$	(75,639	)
Foreign currency translation		3,780			4,193
Balance at December 31	$	(97,677	)	$	(71,446	)

Stock Based Compensation

The Company has granted stock option and restricted stock unit awards to non-employee directors, officers and other key employees of the Company pursuant to the terms of its 2007 Omnibus Equity Compensation Plan (the "Plan"). The total aggregate number of shares of common stock that may be issued under the Plan is 15,500. As of December 31, 2011, a total of 10,948 shares are available for grant under the Plan. Shares issued under the Plan may be authorized but unissued shares of Company stock or reacquired shares of Company stock, including shares purchased by the Company on the open market for purposes of the Plan.

The Company recognizes compensation expense for stock awards over the vesting period of the award. The following table presents stock-based compensation expense recorded in operation and maintenance expense in the accompanying Consolidated Statements of Operations and Comprehensive Income (Loss) for the years ended December 31, 2011, 2010 and 2009:

	2011			2010			2009
Stock options	$	3,182		$	4,116		$	3,415
Restricted stock units		6,340			5,863			3,799
Employee stock purchase plan		486			355			388
Stock-based compensation in operation and maintenance expense		10,008			10,334			7,602
Income tax benefit		(3,903	)		(4,030	)		(2,965	)
After-tax stock-based compensation expense	$	6,105		$	6,304		$	4,637

There were no significant stock-based compensation costs capitalized during the years ended December 31, 2011, 2010 and 2009.

The cost of services received from employees in exchange for the issuance of stock options and restricted stock awards is measured based on the grant date fair value of the awards issued. The value of stock options and restricted stock unit awards at the date of the grant is amortized through expense over the three-year service period. All awards granted in 2011, 2010 and 2009 are classified as equity.

The Company receives a tax deduction based on the intrinsic value of the award at the exercise date for stock options and the distribution date for restricted stock units. For each award, throughout the requisite service period, the Company recognizes the tax benefit related to compensation costs, which have been included in deferred tax assets. The tax deductions in excess of the benefits recorded throughout the requisite service period are recorded to shareholders' equity or the income statement and are included in the financing section of the statement of cash flows.

The Company stratified its grant populations and used historic employee turnover rates to estimate employee forfeitures. The estimated rate is compared to the actual forfeitures at the end of the period and adjusted as necessary.

Stock Options

In the first quarters of 2011, 2010 and 2009, the Company granted non-qualified stock options to certain employees under the Plan. The stock options vest ratably over the three-year service period beginning on January 1 of the year of grant. These awards have no performance vesting conditions and the grant date fair value is amortized through expense over the requisite service period using the straight-line method.

On August 15, 2010, the Company's board of directors elected a new President and Chief Executive Officer ("CEO") of the Company. In connection with his election to these offices, the Company's new CEO was granted non-qualified stock options that cliff vest two years from the date of grant. Additionally, the CEO was granted non-qualified stock options that vest ratably over a three-year period beginning January 1, 2010. These awards have no performance vesting conditions.

Also on August 15, 2010, the Company's former President and Chief Executive Officer resigned as an officer and director of the Company. Pursuant to his resignation, the Company cancelled options to purchase 33 shares of Company stock, accelerated the vesting of 247 options, extended the termination dates of vested options and recognized $315 additional expense related to the modifications that is recorded in operation and maintenance expense in the accompanying Consolidated Statements of Operations and Comprehensive Income (Loss) for the year ended December 31, 2010.

The following table presents the weighted average assumptions used in the pricing model for grants and the resulting weighted average grant date fair value of stock options granted in the years ended December 31, 2011, 2010 and 2009:

	2011			2010			2009
Dividend yield		3.25	%		3.83	%		3.86	%
Expected volatility		29.32	%		31.77	%		31.67	%
Risk-free interest rate		1.93	%		2.14	%		1.79	%
Expected life (years)		4.35			4.29			4.36
Exercise price	$	27.08		$	22.01		$	20.70
Grant date fair value per share	$	5.14		$	4.33		$	3.96

The Company utilized the "simplified method" to determine the expected stock option life due to insufficient historical experience to estimate the exercise patterns of the stock options granted. The Company began granting stock options at the time of the IPO in April 2008. Expected volatility is based on a weighted average of historic volatilities of traded common stock of peer companies (regulated water companies) over the expected term of the stock options and historic volatilities of the Company's common stock during the period it has been publicly traded. The dividend yield is based on the Company's expected dividend payments and the stock price on the date of grant. The risk-free interest rate is the market yield on U.S. Treasury strips with maturities similar to the expected term of the stock options. The exercise price of the stock options is equal to the fair market value of the underlying stock on the date of option grant. Stock options granted vest over periods ranging from one to three years and expire seven years from the effective date of the grant. The fair value of each option is estimated on the date of grant using the Black-Scholes option-pricing model.

The value of stock options at the date of the grant is amortized through expense over the requisite service period using the straight-line method. As of December 31, 2011, $3,389 of total unrecognized compensation costs related to the nonvested stock options is expected to be recognized over the remaining weighted-average period of 1.6 years. The total grant date fair value of stock options vested during the years ended December 31, 2011, 2010 and 2009 was $4,578, $4,505 and $92, respectively.

The table below summarizes stock option activity for the year ended December 31, 2011:

	Shares			Weighted Average Exercise Price (per share)		Weighted Average Remaining Life (years)		Aggregate Intrinsic Value
Options outstanding at January 1, 2011		2,870		$	21.38
Granted		736			27.08
Forfeited or expired		(71	)		23.27
Exercised		(423	)		21.27
Options outstanding at December 31, 2011		3,112		$	22.70		4.3	$	28,493
Exercisable at December 31, 2011		1,686		$	21.34		3.5	$	17,738

The following table summarizes additional information regarding stock options exercised during the years ended December 31, 2011, 2010 and 2009:

	2011		2010			2009
Intrinsic value	$	3,026	$	333		$	0
Exercise proceeds		8,991		3,010			0
Income tax benefit (shortfall)		511		(89	)		0

Restricted Stock Units

In the first quarters of 2011 and 2010 and August 2010, the Company granted restricted stock units to certain employees under the Plan. The restricted stock units vest ratably over the three-year performance period beginning January 1 of the year of grant (the "Performance Period"); however, distribution of the shares is contingent upon the achievement of internal performance measures and, separately, certain market thresholds over the Performance Period. In February 2009, the Company granted restricted stock units that vest ratably over the three year performance period beginning January 1, 2009 (the "2009 Performance Period"); however, distribution of the shares is contingent upon the achievement of certain market thresholds over the 2009 Performance Period.

During 2011, 2010 and 2009, the Company granted restricted stock units to certain non-employee directors under the Plan. The restricted stock units vested on the date of grant; however, distribution of the shares will be made within 30 days of the earlier of (a) 15 months after grant date or (b) the participant's separation from service. Because these restricted stock units vested on grant date, the total grant date fair value was recorded in operation and maintenance expense included in the expense table above on the grant date.

In August 2010, the Company accelerated the vesting of 12 restricted stock units granted in 2008 to the Company's former CEO. Additionally the Company cancelled 9 restricted stock units granted in 2009 and 2010; the remaining outstanding awards will be subject to the Company's achievement of internal performance measures and certain market thresholds over the applicable three-year performance periods as if he had remained in the employ of the Company during the entire performance periods. The net impact associated with these modifications was a reduction to operation and maintenance expense of $12 for the year ended December 31, 2010.

Restricted stock units generally vest over periods ranging from one to three years. Restricted stock units granted without market conditions are valued at the market value of the Company's common stock on the date of grant. Restricted stock units granted with market conditions are valued using a Monte Carlo model. Expected volatility is based on historical volatilities of traded common stock of the Company and comparative companies using daily stock prices over the past three years. The Company's volatility was calculated using a weighted average of eight companies for the 2011 and 2010 periods and nine companies for 2009, respectively, before the Company's stock was publicly traded. The expected term is three years and the risk-free interest rate is based on the three-year U.S. Treasury rate in effect as of the measurement date. The following table presents the weighted average assumptions used in the Monte Carlo simulation and the weighted average grant date fair values of restricted stock units granted during the years ended December 31, 2011, 2010 and 2009:

	2011			2010			2009
Expected volatility		29.50	%		30.74	%		32.00	%
Risk-free interest rate		1.24	%		1.50	%		1.30	%
Expected life (years)		3			3			3
Grant date fair value per share	$	29.95		$	23.23		$	21.75

The value of restricted stock awards at the date of the grant is amortized through expense over the requisite service period using the straight-line method for restricted stock units with service and/or performance vesting. The grant date fair value of restricted stock awards that have (a) market and/or performance and service conditions and (b) vest ratably is amortized through expense over the requisite service period using the graded-vesting method. As of December 31, 2011, $3,172 of total unrecognized compensation cost related to the nonvested restricted stock units is expected to be recognized over the weighted-average remaining life of 1.3 years. The total grant date fair value of restricted stock units vested during the years ended December 31, 2011, 2010 and 2009 was $2,040, $2,204 and $438, respectively.

The table below summarizes restricted stock unit activity for the year ended December 31, 2011:

	Shares			Weighted Average Grant Date Fair Value (per share)
Nonvested total at January 1, 2011		479		$	22.60
Granted		205			29.95
Vested		(89	)		22.88
Forfeited		(18	)		25.28
Nonvested total at December 31, 2011		577		$	25.09

The following table summarizes additional information regarding restricted stock units distributed during the years ended December 31, 2011, 2010 and 2009:

	2011		2010		2009
Intrinsic value	$	2,068	$	1,241	$	51
Income tax benefit (shortfall)		99		15		(2	)

If dividends are declared with respect to shares of the Company's common stock before the restricted stock units are distributed, the Company credits a liability for the value of the dividends that would have been paid if the restricted stock units were shares of Company common stock. When the restricted stock units are distributed, the Company pays the employee a lump sum cash payment equal to the value of the dividend equivalents accrued. The Company accrued dividend equivalents totaling $921, $474 and $279 to retained earnings during the years ended December 31, 2011, 2010 and 2009, respectively.

Employee Stock Purchase Plan

The Company's Nonqualified Employee Stock Purchase Plan ("ESPP") was effective as of July 1, 2008. Under the ESPP, employees can use payroll deductions to acquire Company stock at the lesser of 90% of the fair market value of (a) the beginning or (b) the end of each three-month purchase period. As of December 31, 2011 there were 1,592 shares of common stock reserved for issuance under the ESPP. The Company's ESPP is considered compensatory. Compensation costs of $486, $355 and $388 were recognized for the years ended December 31, 2011, 2010 and 2009, respectively. During the years ended December 31, 2011, 2010 and 2009, the Company issued 121, 119 and 129 shares, respectively, under the ESPP.

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Long-Term Debt (Long-Term Debt Retired) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2011
Debt Instrument [Line Items]
Total retirements and redemptions	$ 75,420
Non-cash redemption associated with cancelled sublease and capital lease arrangement	3,487
Private Activity Bonds And Government Funded Debt [Member] | Other Subsidiaries [Member]
Debt Instrument [Line Items]
Interest Rate, minimum	0.00%
Interest Rate, maximum	5.90%
Maturity Date Range, minimum	2011
Maturity Date Range, maximum	2034
Total retirements and redemptions	7,976
Mandatory Redeemable Preferred Stock [Member] | Other Subsidiaries [Member]
Debt Instrument [Line Items]
Interest Rate, minimum	4.60%
Interest Rate, maximum	9.18%
Maturity Date Range, minimum	2013
Maturity Date Range, maximum	2019
Total retirements and redemptions	1,888
Capital Leases And Other [Member]
Debt Instrument [Line Items]
Total retirements and redemptions	4,078
Fixed Rate [Member] | Senior Notes [Member] | American Water Capital Corp. ("AWCC") [Member]
Debt Instrument [Line Items]
Interest Rate, minimum	6.00%
Interest Rate, maximum	8.25%
Maturity Date Range, minimum	2011
Maturity Date Range, maximum	2039
Total retirements and redemptions	28,287
Fixed Rate [Member] | Mortgage Bonds [Member] | Other Subsidiaries [Member]
Debt Instrument [Line Items]
Interest Rate, minimum	8.21%
Interest Rate, maximum	9.71%
Maturity Date Range, minimum	2011
Maturity Date Range, maximum	2022
Total retirements and redemptions	$ 33,191
Fixed Rate [Member] | Private Activity Bonds And Government Funded Debt [Member] | Other Subsidiaries [Member]
Debt Instrument [Line Items]
Interest Rate, minimum	0.00%
Interest Rate, maximum	1.56%

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Income Taxes (Components Of Income Tax Expense From Continuing Operations) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Income Taxes [Abstract]
State income taxes, Current	$ (7,440)	$ 24,653	$ (19,582)
State income taxes, Deferred, Current	(171)	78	(1,661)
State income taxes, Deferred, Non-current	44,576	11,024	38,908
State income taxes	36,965	35,755	17,665
Federal income taxes, Current	12,239	(1,500)	555
Federal income taxes, Deferred, Current	(314)	69	(16,189)
Federal income taxes, Deferred, Non-current	151,403	141,589	113,174
Amortization of deferred investment tax credits	(1,542)	(1,561)	(1,413)
Federal income taxes	161,786	138,597	96,127
Actual income tax expense	$ 198,751	$ 174,352	$ 113,792

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Consolidated Statements Of Operations And Comprehensive Income (Loss) (USD $) In Thousands, except Per Share data, unless otherwise specified	12 Months Ended
	Dec. 31, 2011		Dec. 31, 2010		Dec. 31, 2009
Consolidated Statements Of Operations And Comprehensive Income (Loss) [Abstract]
Operating revenues	$ 2,666,236		$ 2,555,035		$ 2,290,446
Operating expenses
Operation and maintenance	1,301,794		1,290,941		1,182,376
Depreciation and amortization	351,821		330,264		309,874
General taxes	210,478		205,597		186,620
(Gain) loss on asset dispositions and purchases	(993)		111		(295)
Impairment charge	0		0		428,036
Total operating expenses, net	1,863,100		1,826,913		2,106,611
Operating income	803,136		728,122		183,835
Other income (expenses)
Interest, net	(312,415)		(313,765)		(296,623)
Allowance for other funds used during construction	13,131		9,644		8,342
Allowance for borrowed funds used during construction	5,923		5,225		5,529
Amortization of debt expense	(5,055)		(4,516)		(6,609)
Other, net	(1,040)		4,714		(680)
Total other income (expenses)	(299,456)		(298,698)		(290,041)
Income (loss) from continuing operations before income taxes	503,680		429,424		(106,206)
Provision for income taxes	198,751		174,352		113,792
Income (loss) from continuing operations	304,929		255,072		(219,998)
Income (loss) from discontinued operations, net of tax	4,684		12,755		(13,085)
Net income (loss)	309,613		267,827		(233,083)
Other comprehensive income, net of tax:
Change in employee benefit plan funded status, net of tax of $(19,498), $(7,567) and $6,381, respectively	(30,497)		(11,836)		9,981
Pension plan amortized to periodic benefit cost:
Prior service cost, net of tax of $112, $50 and $29, respectively	175		79		46
Actuarial loss, net of tax of $2,879, $2,793 and $3,832, respectively	4,504		4,368		5,994
Foreign currency translation adjustment	(413)		620		1,553
Other comprehensive income	(26,231)		(6,769)		17,574
Comprehensive income (loss)	$ 283,382		$ 261,058		$ (215,509)
Basic earnings per common share: (a)
Income (loss) from continuing operations	$ 1.74	[1]	$ 1.46	[1]	$ (1.31)	[1]
Income (loss) from discontinued operations, net of tax	$ 0.03	[1]	$ 0.07	[1]	$ (0.08)	[1]
Net income (loss)	$ 1.76	[1]	$ 1.53	[1]	$ (1.39)	[1]
Diluted earnings per common share: (a)
Income (loss) from continuing operations	$ 1.73	[1],[2]	$ 1.46	[1],[2]	$ (1.31)	[1],[2]
Income (loss) from discontinued operations, net of tax	$ 0.03	[1],[2]	$ 0.07	[1],[2]	$ (0.08)	[1],[2]
Net income (loss)	$ 1.75	[1],[2]	$ 1.53	[1],[2]	$ (1.39)	[1],[2]
Average common shares outstanding during the period:
Basic	175,484		174,833		168,164
Diluted	176,531		175,124		168,164
Dividends per common share	$ 1.13		$ 0.86		$ 0.82

[1] Amounts may not sum due to rounding.

[2] Amounts may not sum due to rounding

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Acquisitions And Divestitures

12 Months Ended

Dec. 31, 2011

Acquisitions And Divestitures [Abstract]

Acquisitions And Divestitures

Note 3: Acquisitions and Divestitures

Acquisitions

During 2011, the Company closed on nine acquisitions of regulated water and wastewater systems for an aggregate purchase price of $7,220. The purchase price for each acquisition was allocated to the net tangible and intangible assets based upon their estimated fair values at the acquisition date. Assets acquired totaled $12,919, of which $12,814 was utility plant. Liabilities assumed totaled $4,945, including contributions in aid of construction of $3,847. The Company recorded gains on acquisitions during 2011 totaling $754.

In July of 2011, the Company entered into an agreement to purchase seven regulated water systems in New York for approximately $71,000, adding approximately fifty thousand customers to its regulated operations. This transaction is subject to customary closing conditions including regulatory approval in New York and is expected to close in the first half of 2012.

During 2010, the Company closed on six acquisitions of regulated water and wastewater systems for an aggregate purchase price of $1,642. The purchase price for each acquisition was allocated to the net tangible and intangible assets based upon their estimated fair values at the acquisition date. Assets acquired consisted of plant and equipment of $3,064. Liabilities assumed totaled $1,422, including contributions in aid of construction of $1,109 and regulatory liabilities of $313.

During 2009, the Company closed on seven acquisitions (six regulated water and wastewater systems, and one in its Market-Based Operations segment) for an aggregate purchase price of $18,144. The purchase price for each acquisition was allocated to the net tangible and intangible assets based upon their estimated fair values at the acquisition date. Assets acquired totaled $29,462, including plant and equipment of $17,843, current assets of $5,857, goodwill of $606, and long-lived assets of $5,156. Liabilities assumed totaled $11,318, including debt of $3,990, current liabilities of $5,732, long-term liabilities of $970, and contributions in aid of construction of $626.

Divestitures

As part of the Company's strategic review of its business investments, it has entered into agreements to sell assets or stock of certain subsidiaries.

In June 2011, the Company completed the sale of the assets of its Texas regulated subsidiary for proceeds of $6,245. A gain on the sale of the assets has been recognized for $142 ($87 after tax). In the first quarter of 2011, the Company recognized a pretax impairment charge of $561 for the goodwill associated with the Texas subsidiary.

In January of 2012, the Company received approximately $461,000 in proceeds as a result of completing the sale of its Arizona and New Mexico subsidiaries. The sale is subject to certain post-closing adjustments. In the first quarter of 2011, the Company evaluated the pending sale and recorded an impairment charge totaling $21,428 pretax and $21,099 after tax to reduce parent company goodwill associated with these subsidiaries to their net realizable value.

The Company has also entered into an agreement to sell the stock of its Ohio subsidiary. The sale price is currently estimated at approximately $89,000, plus assumed liabilities, for an estimated enterprise value of approximately $120,000. The sale is subject to certain closing adjustments. In February 2012, the Ohio public utility commission approved the sale. Closing of this sale is expected during the first half of 2012. In the second quarter of 2011, the Company updated its evaluation of the pending sale and recorded an impairment charge totaling $3,510 pretax and $3,456 after tax to reduce parent company goodwill associated with this subsidiary to its net realizable value.

In December 2011, the Company completed the sale of its Applied Water Management subsidiary, part of its Market-Based Operations segment. Proceeds from the sale totaled $2,923. The Company recorded a pre- and post-tax loss on sale of $3,126 and $2,032, respectively.

The Company plans to use the majority of the proceeds from the above sales to reduce debt financing.

Charges recorded in connection with the discontinued operations and disposals of businesses include estimates that are subject to subsequent adjustments.

Operating results and the financial position of the five subsidiaries named above are included in the accompanying financial statements as discontinued operations.

A summary of discontinued operations presented in the Consolidated Statements of Operations and Comprehensive Income follows:

	Years Ended December 31,
	2011			2010		2009
Operating revenues	$	173,447		$	155,642	$	150,257
Total operating expenses, net		147,012			135,673		160,483
Operating income (loss)		26,435			19,969		(10,226	)
Other income (expense), net		(270	)		43		4,767
Income (loss) from discontinued operations before income taxes		26,165			20,012		(5,459	)
Provision for income taxes		21,481			7,257		7,626
Income (loss) from discontinued operations, net of tax	$	4,684		$	12,755	$	(13,085	)

Operating expenses were lower in 2011 due to the cessation of depreciation for assets held for sale totaling $24,807 for the year ended December 31, 2011. Operating expenses in 2009 include an allocated impairment charge of $21,964.

Assets and liabilities of discontinued operations in the accompanying Consolidated Balance Sheets include the following:

	December 31, 2011		December 31, 2010
Assets:
Total property, plant and equipment	$	833,023	$	819,977
Current assets		21,906		20,710
Regulatory assets		43,849		39,833
Goodwill		29,608		55,107
Other		1,472		2,078
Total assets of discontinued operations	$	929,858	$	937,705
Liabilities:
Long-term debt	$	11,697	$	17,272
Current portion of long-term debt		12,839		8,668
Other current liabilities		29,530		39,505
Advances for construction		205,034		214,045
Regulatory liabilities		4,617		7,622
Other		15,540		(4,058	)
Contributions in aid of construction		102,961		90,906
Total liabilities of discontinued operations	$	382,218	$	373,960

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Significant Accounting Policies

12 Months Ended

Dec. 31, 2011

Significant Accounting Policies [Abstract]

Significant Accounting Policies

Note 2: Significant Accounting Policies

Principles of Consolidation

The accompanying consolidated financial statements include the accounts of AWW and its subsidiaries. Intercompany balances and transactions between subsidiaries have been eliminated. The Company uses the equity method to report its investments in two joint venture investments in each of which the Company holds a 50% voting interest and cannot exercise control over the operations and policies of the investments. Under the equity method, the Company records its interests as an investment and its percentage share of earnings as earnings or losses of investee.

Use of Estimates

The preparation of consolidated financial statements in conformity with accounting principles generally accepted in the United States requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosures of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from these estimates. The Company considers benefit plan assumptions; the carrying values of goodwill and other long-lived assets, including regulatory assets; revenue recognition; and accounting for income taxes to be its critical accounting estimates. The Company's significant estimates that are particularly sensitive to change in the near term are amounts reported for pension and other postemployment benefits, contingency-related obligations and goodwill.

Regulation

The Company's regulated utilities are subject to economic regulation by the public utility commissions and the local governments of the states in which they operate (the "Regulators"). These Regulators have allowed recovery of costs and credits which the Company has recorded as regulatory assets and liabilities. Accounting for future recovery of costs and credits as regulatory assets and liabilities is in accordance with authoritative guidance applicable to those companies whose rates are established by or are subject to approval by an independent third-party regulator. Regulated utilities defer costs and credits on the balance sheet as regulatory assets and liabilities when it is probable that those costs and credits will be recognized in the rate making process in a period different from the period in which they would have been reflected in operations by a market-based company. These deferred regulatory assets and liabilities are then reflected in the statement of operations in the period in which the costs and credits are reflected in the rates charged for service. (See Note 7)

Property, Plant and Equipment

Property, plant and equipment consist primarily of utility plant. Additions to utility plant and replacements of retirement units of property are capitalized. Costs include material, direct labor and such indirect items as engineering and supervision, payroll taxes and benefits, transportation and an allowance for funds used during construction. The costs incurred to acquire and internally develop computer software for internal use are capitalized as a unit of property. The carrying value of these costs amounted to $49,241 and $60,408 at December 31, 2011 and 2010, respectively. The cost of repairs; maintenance, including planned major maintenance activities; and minor replacements of property is charged to maintenance expense as incurred.

When units of property are replaced, retired or abandoned, the recorded value thereof is credited to the asset account and charged to accumulated depreciation. To the extent the Company recovers cost of removal or other retirement costs through rates after the retirement costs are incurred, a regulatory asset is recorded. In some cases, the Company recovers retirement costs through rates during the life of the associated asset and before the costs are incurred. These amounts result in a regulatory liability being reported based on the amounts previously recovered through customer rates, until the costs to retire those assets are incurred.

The cost of property, plant and equipment is depreciated using the straight-line average remaining life method.

Nonutility property consists primarily of buildings and equipment utilized by the Company for internal operations. This property is stated at cost, net of accumulated depreciation calculated using the straight-line method over the estimated useful lives of the assets, ranging from three to 50 years.

Cash and Cash Equivalents

Substantially all cash is invested in interest-bearing accounts. All highly liquid investments with a maturity of three months or less when purchased are considered to be cash equivalents.

The Company had book overdrafts for certain of its disbursement accounts of $34,002 and $50,881 at December 31, 2011 and 2010, respectively. A book overdraft represents transactions that have not cleared the bank accounts at the end of the period. The Company transfers cash on an as-needed basis to fund these items as they clear the bank. The balance of the book overdraft is reported as short-term debt and the change in the book overdraft balance is reported as cash flows from financing activities.

Restricted Funds

Restricted funds primarily represent proceeds from financings for the construction and capital improvement of facilities and deposits for future services under operation and maintenance projects. The proceeds of these financings are held in escrow until the designated expenditures are incurred. Restricted funds expected to be released within 12 months subsequent to year end are classified as current.

Utility Customer Accounts Receivable

Regulated utility customer accounts receivable represent amounts billed to water and wastewater customers on a cycle basis. Credit is extended based on the guidelines of the applicable Regulators and collateral is generally not required.

Allowance for Uncollectible Accounts

Allowances for uncollectible accounts are maintained for estimated probable losses resulting from the Company's inability to collect receivables from customers. Accounts that are outstanding longer than the payment terms are considered past due. A number of factors are considered in determining the allowance for uncollectible accounts, including the length of time receivables are past due and previous loss history. The Company writes off accounts when they become uncollectible. (See Note 5)

Other Receivables, Net

Other receivables, net consists of market-based trade accounts receivable and market-based unbilled revenues, net of a reserve for doubtful accounts, and non-utility customer receivables of the regulated subsidiaries. In determining the reserve for uncollectible market-based accounts, the Company considers the length of time the trade accounts receivable are past due and the customers' current ability to pay their obligations. Unbilled receivables are accrued when service has been provided but has not been billed to customers. (See Note 6)

Materials and Supplies

Materials and supplies are stated at the lower of cost or net realizable value. Cost is determined using the average cost method.

Goodwill

Goodwill is primarily associated with the acquisitions of AWW in 2003 and E'town Corporation in 2001 (the "Acquisitions") and has been assigned to reporting units based on the fair values at the date of the Acquisitions. The Regulated Businesses segment is a single reporting unit. In the Market-Based Operations segment, the business is organized into seven reporting units for its market-based services. Goodwill is reviewed annually, or more frequently if changes in circumstances indicate the carrying value may not be recoverable. Annual impairment reviews are performed in the fourth quarter of the calendar year, in conjunction with the timing of the completion of the Company's annual strategic business plan.

The Company considers the carrying value of goodwill to be one of its critical accounting estimates. The Company believes the assumptions and other considerations used to value goodwill to be appropriate. However, if experience differs from the assumptions and considerations used in its analysis, the resulting change could have a material adverse impact on the consolidated financial statements.

No impairment charge was recorded in the Company's continuing operations for the years ended December 31, 2011 and 2010, respectively. For the year ended December 31, 2009, the Company recorded goodwill impairment charges to continuing operations of $428,036. (See Note 8)

Long-Lived Assets

Long-lived assets include land, buildings, equipment and long-term investments. Long-lived assets, other than investments and land, are depreciated over their estimated useful lives, and are reviewed for impairment whenever changes in circumstances indicate the carrying value of the asset may not be recoverable. Such circumstances would include items such as a significant decrease in the market value of a long-lived asset, a significant adverse change in the manner the asset is being used or planned to be used or in its physical condition, or a history of operating or cash flow losses associated with the use of the asset. In addition, changes in the expected useful life of these long-lived assets may also be an impairment indicator. When such events or changes occur, the Company estimates the fair value of the asset from future cash flows expected to result from the use and, if applicable, the eventual disposition of the assets and compares that to the carrying value of the asset. If the carrying value is greater than the fair value, an impairment loss is recorded.

The Company considers the carrying value of long-lived assets to be one of its critical accounting estimates. The Company believes the assumptions and other considerations used to evaluate the carrying value of long-lived assets to be appropriate. However, if actual experience differs from the assumptions and considerations used in its estimates, the resulting change could have a material adverse impact on the consolidated financial statements.

The key variables to determine value include assumptions regarding sales volume, rates, operating costs, labor and other benefit costs, capital additions, assumed discount rates and other economic factors. These variables require significant management judgment and include inherent uncertainties since they are forecasting future events. If such assets are considered impaired, an impairment loss is recognized equal to the amount by which the asset's carrying value exceeds its fair value.

The long-lived assets of the regulated utility subsidiaries are grouped on a separate entity basis for impairment testing as they are integrated state-wide operations that do not have the option to curtail service and generally have uniform tariffs. A regulatory asset is charged to earnings if and when future recovery in rates of that asset is no longer probable.

The Company holds other investments including investments in privately held companies and investments in joint ventures accounted for using the equity method. The Company's investments in privately held companies and joint ventures are classified as other long-term assets.

The fair values of long-term investments are dependent on the financial performance and solvency of the entities in which the Company invests, as well as volatility inherent in the external markets. If such assets are considered impaired, an impairment loss is recognized equal to the amount by which the asset's carrying value exceeds its fair value.

Advances and Contributions in Aid of Construction

Regulated utility subsidiaries may receive advances and contributions from customers, home builders and real estate developers to fund construction necessary to extend service to new areas. Advances for construction are refundable for limited periods of time as new customers begin to receive service or other contractual obligations are fulfilled. Included in other current liabilities at December 31, 2011 and 2010 in the accompanying Consolidated Balance Sheets are estimated refunds of $18,681 and $22,451, respectively. Those amounts represent expected refunds during the next 12-month period. Advances that are no longer refundable are reclassified to contributions in aid of construction. Contributions in aid of construction are permanent collections of plant assets or cash for a particular construction project. For ratemaking purposes, the amount of such contributions generally serves as a rate base reduction since the contributions represent non-investor supplied funds.

Generally, the Company depreciates utility plant funded by contributions and amortizes its contributions balance as a reduction to depreciation expense, producing a result which is functionally equivalent to reducing the original cost of the utility plant for the contributions. Certain of the Company's subsidiaries do not depreciate contributed property, based on regulatory guidelines. Amortization of contributions in aid of construction was $18,327, $17,423 and $16,371 for the years ended December 31, 2011, 2010 and 2009, respectively.

Recognition of Revenues

Revenues of the regulated utility subsidiaries are recognized as water and wastewater services are provided and include amounts billed to customers on a cycle basis and unbilled amounts based on estimated usage from the date of the latest meter reading to the end of the accounting period.

The Company has agreements with the United States Government to operate and maintain water and wastewater systems at various military bases pursuant to 50-year contracts ("military agreements"). These contracts also include construction components that are accounted for separately from the operations and management components. The military agreements are subject to periodic price redetermination adjustments and modifications for changes in circumstance. Additionally, the Company has agreements ranging in length from two to 40 years with various industries and municipalities to operate and maintain water and wastewater systems ("O&M agreements"). Revenue from operations and management services are recognized as services are provided. (See Note 16)

Construction Contracts

Revenues from construction projects are recognized over the contract term based on the estimated percentage of completion during the period compared to the total estimated services to be provided over the entire contract. Losses on contracts are recognized during the period in which the loss first becomes probable and estimable. Revenues recognized during the period in excess of billings on construction contracts are recorded as unbilled revenue. Billings in excess of revenues recognized on construction contracts are recorded as other current liabilities until the recognition criteria are met. Changes in contract performance and related estimated contract profitability may result in revisions to costs and revenues and are recognized in the period in which revisions are determined.

Income Taxes

AWW and its subsidiaries participate in a consolidated federal income tax return for U.S. tax purposes. Members of the consolidated group are charged with the amount of federal income tax expense determined as if they filed separate returns.

Certain income and expense items are accounted for in different time periods for financial reporting than for income tax reporting purposes. The Company provides deferred income taxes on the difference between the tax basis of assets and liabilities and the amounts at which they are carried in the financial statements. These deferred income taxes are based on the enacted tax rates expected to be in effect when these temporary differences are projected to reverse. In addition, the regulated utility subsidiaries recognize regulatory assets and liabilities for the effect on revenues expected to be realized as the tax effects of temporary differences, previously flowed through to customers, reverse.

Investment tax credits have been deferred by the regulated utility subsidiaries and are being amortized to income over the average estimated service lives of the related assets.

The Company recognizes accrued interest and penalties related to tax positions as a component of income tax expense and accounts for sales tax collected from customers and remitted to taxing authorities on a net basis.

Allowance for Funds Used During Construction ("AFUDC")

AFUDC is a non-cash credit to income with a corresponding charge to utility plant that represents the cost of borrowed funds or a return on equity funds devoted to plant under construction. The regulated utility subsidiaries record AFUDC to the extent permitted by the Regulators.

Environmental Costs

The Company's water and wastewater operations are subject to federal, state, local and foreign requirements relating to environmental protection, and as such, the Company periodically becomes subject to environmental claims in the normal course of business. Environmental expenditures that relate to current operations or provide a future benefit are expensed or capitalized as appropriate. Remediation costs that relate to an existing condition caused by past operations are accrued, on an undiscounted basis, when it is probable that these costs will be incurred and can be reasonably estimated. Remediation costs accrued amounted to $5,500 and $6,630 at December 31, 2011 and 2010, respectively. At December 31, 2011, the entire accrual relates to a conservation agreement entered into by a subsidiary of the Company with the National Oceanic and Atmospheric Administration ("NOAA") requiring the Company to, among other provisions, implement certain measures to protect the steelhead trout and its habitat in the Carmel River watershed in the state of California. The Company paid and expensed $3,500 related to this agreement during 2009, and has agreed to pay $1,100 annually from 2010 to 2016. The Company pursues recovery of incurred costs through all appropriate means, including regulatory recovery through customer rates. The Company's regulatory assets at December 31, 2011 and 2010 include $9,187 and $10,642, respectively, related to the NOAA agreement, including an additional $3,500 granted in 2010 for recovery of the 2009 payment.

Derivative Financial Instruments

The Company uses derivative financial instruments for purposes of hedging exposures to fluctuations in interest rates. These derivative contracts are entered into for periods consistent with the related underlying exposures and do not constitute positions independent of those exposures. The Company does not enter into derivative contracts for speculative purposes and does not use leveraged instruments.

All derivatives are recognized on the balance sheet at fair value. On the date the derivative contract is entered into, the Company may designate the derivative as a hedge of the fair value of a recognized asset or liability (fair-value hedge) or a hedge of a forecasted transaction or of the variability of cash flows to be received or paid related to a recognized asset or liability (cash-flow hedge).

Changes in the fair value of a fair-value hedge, along with the gain or loss on the underlying hedged item, are recorded in current-period earnings. The effective portion of gains and losses on cash-flow hedges are recorded in other comprehensive income (loss), until earnings are affected by the variability of cash flows. Any ineffective portion of designated hedges is recognized in current-period earnings.

Cash flows from derivative contracts are included in net cash provided by operating activities.

New Accounting Standards

The following recently announced accounting standards have been adopted by the Company and have been included in the consolidated results of operations, financial position or footnotes of the accompanying Consolidated Financial Statements:

Revenue Arrangements with Multiple Deliverables

In October 2009, the Financial Accounting Standards Board ("FASB") issued authoritative guidance that amends existing guidance for identifying separate deliverables in a revenue-generating transaction where multiple deliverables exist, and provides guidance for allocating and recognizing revenue based on those separate deliverables. The guidance is expected to result in more multiple-deliverable arrangements being separable than under current guidance. This guidance is effective for the Company beginning on January 1, 2011 and is required to be applied prospectively to new or significantly modified revenue arrangements. The adoption of this guidance did not have a significant impact on the Company's results of operations, financial position or cash flows.

Business Combinations

In December 2010, the FASB clarified the requirements for reporting of pro forma revenue and earnings disclosures for business combinations. The accounting update specifies that if a public entity presents comparative financial statements, the entity should disclose revenue and earnings of the combined entity as though the business combination(s) that occurred during the current year had occurred as of the beginning of the comparable prior annual reporting period only. The amendments also expand the supplemental pro forma disclosures to include a description of the nature and amount of material, nonrecurring pro forma adjustments directly attributable to the business combination included in the reported pro forma revenue and earnings. The amendments are effective for the Company for business combinations finalized after January 1, 2011. As this guidance clarifies and provides for additional disclosure requirements only, the adoption of this guidance has not had an impact on the Company's results of operations, financial position or cash flows.

Intangibles—Goodwill

In December 2010, the FASB issued authoritative guidance that modifies step 1 of the goodwill impairment test for reporting units with zero or negative carrying amounts. The update requires that for those reporting units, an entity is required to perform step 2 of the goodwill impairment test if it is more likely than not that a goodwill impairment exists. In determining whether it is more likely than not that a goodwill impairment exists, an entity should consider whether there are any adverse qualitative factors indicating that impairment may exist. Existing authoritative guidance requires that goodwill of a reporting unit be tested for impairment between annual tests if an event occurs or circumstances change that would more likely than not reduce the fair value of a reporting unit below its carrying amount. This guidance is effective for the Company beginning on January 1, 2011. The adoption of this update did not have a significant impact on the Company's results of operations, financial position or cash flows.

The following recently issued accounting standards are not yet required to be adopted by the Company or included in the consolidated results of operations or financial position of the Company:

Fair Value Measurements

In May 2011, the FASB issued updated accounting guidance related to fair value measurements and disclosures that result in common fair value measurements and disclosures between U.S. GAAP and International Financial Reporting Standards. This new guidance amends current fair value measurement and disclosure guidance to increase transparency around valuation inputs and investment categorization. This guidance is effective for interim and annual periods beginning after December 15, 2011. The new guidance is to be adopted prospectively and early adoption is not permitted. The Company does not expect the adoption of this guidance to have a significant impact on the Company's results of operations, financial position or cash flows.

Comprehensive Income

In June 2011, the FASB issued guidance on the presentation of comprehensive income. The new guidance allows an entity to present components of net income and other comprehensive income in one continuous statement or in two separate, but consecutive statements. The new guidance eliminates the current option to report other comprehensive income and its components in the statement of changes in equity. While the new guidance changes the presentation of comprehensive income, there are no changes to the components that are recognized in net income or other comprehensive income under current accounting guidance. In December 2011, the FASB deferred the requirement to present reclassification adjustments of other comprehensive income on the face of the income statement. The new guidance is effective for fiscal years and interim periods beginning after December 15, 2011. As the Company already presents the components of net income and other comprehensive income in one continuous statement, the adoption of the new guidance will not have an impact on its results of operations, financial position or cash flows.

Testing Goodwill for Impairment

In September 2011, the FASB updated the accounting guidance related to testing goodwill for impairment. This update permits an entity to first assess qualitative factors to determine whether it is necessary to perform the two-step quantitative goodwill impairment test that is currently in place. Under the new guidance, an entity will not be required to calculate the fair value of a reporting unit unless the entity determines, based on the qualitative assessment, that it is more likely than not that its fair value is less than its carrying amount. This update is effective for annual and interim goodwill impairment tests performed in fiscal years beginning after December 15, 2011; however, early adoption is permitted. The Company is evaluating the specific provisions of the updated guidance, but does not expect the adoption of this guidance to have a significant impact on the Company's results of operations, financial position or cash flows.

Reclassifications

Certain reclassifications for discontinued operations (see Note 3) have been made to conform previously reported data to the current presentation.

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Income Taxes

12 Months Ended

Dec. 31, 2011

Income Taxes [Abstract]

Income Taxes

Note 14: Income Taxes

Components of income tax expense from continuing operations for the years ended December 31 are as follows:

	2011			2010			2009
State income taxes
Current	$	(7,440	)	$	24,653		$	(19,582	)
Deferred
Current		(171	)		78			(1,661	)
Non-current		44,576			11,024			38,908
		36,965			35,755			17,665
Federal income taxes
Current		12,239			(1,500	)		555
Deferred
Current		(314	)		69			(16,189	)
Non-current		151,403			141,589			113,174
Amortization of deferred investment tax credits		(1,542	)		(1,561	)		(1,413	)
		161,786			138,597			96,127
	$	198,751		$	174,352		$	113,792

A reconciliation of income tax expense from continuing operations at the statutory federal income tax rate to actual income tax expense for the years ended December 31 is as follows:

	2011			2010			2009
Income tax at statutory rate	$	176,288		$	150,298		$	(37,172	)
Increases (decreases) resulting from:
State taxes, net of federal taxes		24,027			23,241			11,482
Change in valuation allowance		(160	)		(533	)		(6,578	)
Flow through differences		2,895			2,807			2,760
Amortization of deferred investment tax credits		(1,542	)		(1,561	)		(1,413	)
Subsidiary preferred dividends		668			675			680
Impairment charges		0			0			143,321
Other, net		(3,425	)		(575	)		712
Actual income tax expense	$	198,751		$	174,352		$	113,792

The following table provides the components of the net deferred tax liability from continuing operations at December 31:

	2011			2010
Deferred tax assets:
Advances and contributions	$	475,280		$	463,694
Deferred investment tax credits		11,202			11,789
Other postretirement benefits		101,258			92,620
Tax losses and credits		284,636			327,128
Pension benefits		132,972			141,530
Unamortized debt discount, net		23,872			22,889
Other		13,308			8,429
		1,042,528			1,068,079
Valuation allowance		(20,701	)		(22,733	)
		1,021,827			1,045,346
Deferred tax liabilities:
Utility plant, principally due to depreciation differences		1,958,044			1,846,338
Income taxes recoverable through rates		94,331			93,495
Deferred security costs		1,982			3,065
Deferred business services project expenses		4,573			4,566
Deferred other postretirement benefits		58,238			48,155
Deferred pension benefits		97,899			78,972
Other		95,557			81,005
		2,310,624			2,155,596
	$	(1,288,797	)	$	(1,110,250	)

At December 31, 2011 and 2010, the Company recorded federal net operating loss ("NOL") carryforwards of $1,187,427 and $1,185,337, respectively. The Company believes the federal NOL carryforwards are more likely than not to be recovered and require no valuation allowance. The Company evaluated its ability to fully utilize the existing federal NOL carryforwards in light of the RWE divestiture in November 2009. Under Internal Revenue Code ("I.R.C.") Section 382, an ownership change occurs if there is a greater than fifty percent (50%) change in equity ownership of a company over a three-year period determined by reference to the ownership of persons holding five percent (5%) or more of that company's equity securities. If a company undergoes an ownership change as defined by I.R.C. Section 382, the company's ability to utilize its pre-change NOL carryforwards to offset post-change income may be limited.

The Company believes that the limitation imposed by I.R.C. Section 382 generally should not preclude use of its federal NOL carryforwards, assuming the Company has sufficient taxable income in future carryforward periods to utilize those NOL carryforwards. The Company's federal NOL carryforwards do not begin expiring until 2024.

At December 31, 2011 and 2010, the Company had state NOLs of $739,804 and $714,674, respectively, a portion of which are offset by a valuation allowance because the Company does not believe these NOLs are more likely than not to be realized. The state NOL carryforwards will expire between 2012 and 2031.

At December 31, 2011 and 2010, the Company had Canadian NOL carryforwards of $6,198 and $5,398, respectively. The majority of these carryforwards are offset by a valuation allowance because the Company does not believe these NOLs are more likely than not to be realized. The Canadian NOL carryforwards will expire between 2014 and 2030.

At December 31, 2011 and 2010, the Company had capital loss carryforwards for federal income tax purposes of $4,357 and $0, respectively. The Company has recognized a full valuation allowance for the capital loss carryforwards because the Company does not believe these losses are more likely than not to be recovered.

The Company files income tax returns in the United States federal jurisdiction and various state and foreign jurisdictions. With few exceptions, the Company is no longer subject to U.S. federal, state or local or non-U.S income tax examinations by tax authorities for years before 2005.

In March 2010, the Company filed refund claims of $25,314. The refund claims are attributable to the carry back of Alternative Minimum Tax NOLs generated in 2008. These claims procedurally require approval by the Joint Committee of Taxation ("JCT"). The Company received the refund in April 2010. In August 2010, the IRS notified the Company that additional audit procedures were necessary to support the filing of the JCT report. The audit has not been concluded at December 31, 2011, and no adjustments have been proposed so far.

The Company has state income tax examinations in progress and does not expect material adjustments to result.

The Patient Protection and Affordable Care Act (the "PPACA") became law on March 23, 2010, and the Health Care and Education Reconciliation Act of 2010 became law on March 30, 2010, which makes various amendments to certain aspects of the PPACA (together, the "Acts"). The PPACA effectively changes the tax treatment of federal subsidies paid to sponsors of retiree health benefit plans that provide a benefit that is at least actuarially equivalent to the benefits under Medicare Part D. As a result of the Acts, these subsidy payments will effectively become taxable in tax years beginning after December 31, 2012.

Although this change does not take effect immediately, companies are required to recognize the full accounting impact in their financial statements in the period in which the legislation was enacted. As a result, the Company followed its original accounting for the underfunded status of the other postretirement benefits for the Medicare Part D adjustment and recorded a reduction in deferred tax assets and an increase in its regulatory assets amounting to $16,979.

The following table summarizes the changes in the Company's gross liability, excluding interest and penalties, for unrecognized tax benefits:

Balance at January 1, 2010	$	112,021
Increases in current period tax positions		7,434
Decreases due to lapse of statute of limitations		(1,141	)
Balance at December 31, 2010		118,314
Increases in current period tax positions		46,961
Decreases in prior period measurement of tax positions		(6,697	)
Balance at December 31, 2011	$	158,578

The liability balance as of December 31, 2011 and 2010 does not include interest and penalties of $214 and $80, respectively, which is recorded as a component of income tax expense. The majority of the increased tax position is attributable to temporary differences. The increase in 2011 current period tax positions relates primarily to the Company's change in tax accounting method filed in 2008 for repair and maintenance costs on its utility assets. The Company does not anticipate material changes to its unrecognized tax benefits within the next year. If the Company sustains all of its positions at December 31, 2011 and 2010, an unrecognized tax benefit of $6,644 and $6,644, respectively, excluding interest and penalties, would impact the Company's effective tax rate.

The following table summarizes the changes in the Company's valuation allowance:

Balance at January 1, 2009	$	28,862
Increases in current period tax positions		2,778
Decreases in current period tax positions		(5,698	)
Decreases in prior period tax positions		(321	)
Balance at December 31, 2009	$	25,621
Increases in current period tax positions		907
Decreases in current period tax positions		(2,740	)
Balance at December 31, 2010	$	23,788
Increases in current period tax positions		1,525
Decreases in current period tax positions		(3,734	)
Balance at December 31, 2011	$	21,579

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Preferred Stock Without Mandatory Redemption Requirements

12 Months Ended

Dec. 31, 2011

Preferred Stock Without Mandatory Redemption Requirements [Abstract]

Preferred Stock Without Mandatory Redemption Requirements

Note 10: Preferred Stock Without Mandatory Redemption Requirements

Certain preferred stock agreements do not require annual sinking fund payments or redemption except at the option of the subsidiaries and are as follows:

Dividend Yield	Balance at December 31,
	2011		2010
4.50%	$	1,720	$	1,720
5.00%		1,952		1,952
5.50%		486		486
5.75%		389		389
	$	4,547	$	4,547

The Company reflects its subsidiaries' preferred stock without mandatory redemption requirements, which represents the Company's noncontrolling interest, in the total stockholders' equity section of the accompanying Consolidated Balance Sheets. The dividends on these preferred shares have not been reflected as income attributable to noncontrolling interest in the Consolidated Statements of Operations and Comprehensive Income (Loss) as the total amount of these dividends is not considered material. The dividends issued were $224 for 2011 and 2010, respectively, and $225 for 2009. The amounts have been included as a component of other income (expenses) in the accompanying Consolidated Statements of Operations and Comprehensive Income (Loss).

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Short-Term Debt (Components Of Short-Term Debt) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2011	Dec. 31, 2010
Short-Term Debt [Abstract]
Revolving credit lines	$ 0	$ 2,734
Commercial paper, net of $10 and $5 discount at 2010 and 2009, respectively	481,048	175,290
Book overdraft	34,002	50,881
Total short-term debt	515,050	228,905
Commercial paper, discount	$ 52	$ 10

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Other Receivables, Net

12 Months Ended

Dec. 31, 2011

Other Receivables, Net [Abstract]

Other Receivables, Net

Note 6: Other Receivables, Net

Components of the Company's other receivables, net at December 31 are as follows:

	2011			2010
Market-based trade accounts receivable	$	26,734		$	36,357
Allowance for doubtful accounts—market-based trade accounts receivable		(3,067	)		(3,015	)
Market-based unbilled revenue		14,367			14,273
Other		22,379			23,974
	$	60,413		$	71,589

The following table summarizes the changes in the Company's market-based allowances for uncollectible accounts:

	2011			2010			2009
Balance at January 1	$	(3,015	)	$	(3,520	)	$	(4,622	)
Amounts charged to (expense) income		(3,583	)		(223	)		796
Amounts written off		2,886			748			476
Recoveries of amounts written off		645			(20	)		(170	)
Balance at December 31	$	(3,067	)	$	(3,015	)	$	(3,520	)

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Regulatory Assets And Liabilities (Components Of Regulatory Assets) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2011	Dec. 31, 2010
Regulatory Assets [Line Items]
Regulatory assets	$ 1,079,661	$ 976,174
Income Taxes Recoverable Through Rates [Member]
Regulatory Assets [Line Items]
Regulatory assets	252,570	247,104
Debt And Preferred Stock Expense [Member]
Regulatory Assets [Line Items]
Regulatory assets	73,096	76,278
Deferred Pension Expense [Member]
Regulatory Assets [Line Items]
Regulatory assets	256,858	207,633
Deferred Other Postretirement Benefit Expense [Member]
Regulatory Assets [Line Items]
Regulatory assets	149,393	126,894
Deferred Security Costs [Member]
Regulatory Assets [Line Items]
Regulatory assets	4,837	7,479
Deferred Business Services Project Expense [Member]
Regulatory Assets [Line Items]
Regulatory assets	8,776	10,670
Deferred Tank Painting Costs [Member]
Regulatory Assets [Line Items]
Regulatory assets	29,500	26,924
Deferred Rate Case Expense [Member]
Regulatory Assets [Line Items]
Regulatory assets	14,553	9,322
Purchase Premium Recoverable Through Rates [Member]
Regulatory Assets [Line Items]
Regulatory assets	60,635	60,647
Environmental Remediation Recoverable Through Rates [Member]
Regulatory Assets [Line Items]
Regulatory assets	9,187	10,642
Coastal Water Project Costs [Member]
Regulatory Assets [Line Items]
Regulatory assets	24,419	27,084
San Clemente Dam Project Costs [Member]
Regulatory Assets [Line Items]
Regulatory assets	22,890	18,723
Removal Costs Recoverable Through Rates [Member]
Regulatory Assets [Line Items]
Regulatory assets	80,402	59,317
Other [Member]
Regulatory Assets [Line Items]
Regulatory assets	$ 92,545	$ 87,457

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Earnings (Loss) Per Common Share (Schedule Of Potentially Dilutive Common Stock Equivalents Not Included In Earnings (Loss) Per Share Calculations) (Details) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Stock excluded from calculation of shares			21
Stock Options [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Stock excluded from calculation of shares	711	1,781	2,265
Stock Options Performance Conditions Not Met [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Stock excluded from calculation of shares	0	0	459
Restricted Stock Units [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Stock excluded from calculation of shares	0	0	258
Restricted Stock Units Performance Conditions Not Met [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Stock excluded from calculation of shares	22	69	144
Employee Stock Purchase Plan [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Stock excluded from calculation of shares	0	0	32

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Utility Plant

12 Months Ended

Dec. 31, 2011

Utility Plant [Abstract]

Utility Plant

Note 4: Utility Plant

The components of utility plant by category at December 31 are as follows:

	Range of Remaining Useful Lives		2011		2010
Water plant
Land and other non-depreciable assets			$	128,286	$	125,648
Sources of supply		20 to 127 Years		565,301		527,552
Treatment and pumping facilities		3 to 101 Years		2,665,525		2,524,241
Transmission and distribution facilities		9 to 127 Years		6,632,828		6,333,032
Services, meters and fire hydrants		6 to 96 Years		2,539,696		2,402,038
General structures and equipment		3 to 112 Years		693,880		643,973
Wastewater plant		4 to 86 Years		546,002		519,219
Construction work in progress				460,529		299,733
				14,232,047		13,375,436
Less accumulated depreciation				3,360,005		3,134,094
			$	10,872,042	$	10,241,342

Utility plant depreciation expense of continuing operations amounted to $268,987 in 2011, $250,107 in 2010 and $237,741 in 2009. The Company's regulated utility subsidiaries record depreciation in conformity with amounts approved by state regulators after regulatory review of information the Company submits to support its estimates of the assets' remaining useful lives.

The provision for depreciation expressed as a percentage of the aggregate average depreciable asset balances was 2.68% in 2011, and 2.62% in 2010 and 2009, respectively.

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Allowance For Uncollectible Accounts

12 Months Ended

Dec. 31, 2011

Allowance For Uncollectible Accounts [Abstract]

Allowance For Uncollectible Accounts

Note 5: Allowance for Uncollectible Accounts

The following table summarizes the changes in the Company's allowances for uncollectible accounts:

	2011			2010			2009
Balance at January 1	$	(17,474	)	$	(18,148	)	$	(16,859	)
Amounts charged to expense		(16,178	)		(17,973	)		(20,999	)
Amounts written off		21,855			22,124			23,104
Recoveries of amounts written off		(3,522	)		(3,477	)		(3,394	)
Balance at December 31	$	(15,319	)	$	(17,474	)	$	(18,148	)

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Regulatory Assets And Liabilities

12 Months Ended

Dec. 31, 2011

Regulatory Assets And Liabilities [Abstract]

Regulatory Assets And Liabilities

Note 7: Regulatory Assets and Liabilities

The regulatory assets represent costs that are expected to be fully recovered from customers in future rates. Except for income taxes, regulatory assets are excluded from the Company's rate base and generally do not earn a return. The components of regulatory assets at December 31 are as follows:

	2011		2010
Income taxes recoverable through rates	$	252,570	$	247,104
Debt and preferred stock expense		73,096		76,278
Deferred pension expense		256,858		207,633
Deferred other postretirement benefit expense		149,393		126,894
Deferred security costs		4,837		7,479
Deferred business services project expense		8,776		10,670
Deferred tank painting costs		29,500		26,924
Deferred rate case expense		14,553		9,322
Purchase premium recoverable through rates		60,635		60,647
Environmental remediation recoverable through rates		9,187		10,642
Coastal water project costs		24,419		27,084
San Clemente Dam project costs		22,890		18,723
Removal costs recoverable through rates		80,402		59,317
Other		92,545		87,457
	$	1,079,661	$	976,174

The Company has recorded a regulatory asset for the additional revenues expected to be realized as the tax effects of temporary differences previously flowed through to customers reverse. These temporary differences are primarily related to the difference between book and tax depreciation on property placed in service before the adoption by the regulatory authorities of full normalization for rate making purposes. Full normalization requires no flow through of tax benefits to customers. The regulatory asset for income taxes recoverable through rates is net of the reduction expected in future revenues as deferred taxes previously provided, attributable to the difference between the state and federal income tax rates under prior law and the current statutory rates, reverse over the average remaining service lives of the related assets.

Debt expense is amortized over the lives of the respective issues. Call premiums on the redemption of long-term debt, as well as unamortized debt expense, are deferred and amortized to the extent they will be recovered through future service rates. Expenses of preferred stock issues without sinking fund provisions are amortized over 30 years from date of issue; expenses of issues with sinking fund provisions are charged to operations as shares are retired.

Pension expense in excess of the amount contributed to the pension plans is deferred by certain subsidiaries. These costs will be recovered in future service rates as contributions are made to the pension plan. The Company also has regulatory assets of $243,926 and $180,200 at December 31, 2011 and 2010, respectively, which is the portion of the underfunded status that is probable of recovery through rates in future periods.

Postretirement benefit expense in excess of the amount recovered in rates through 1997 has been deferred by certain subsidiaries. These costs are recognized in the rates charged for water service and will be recovered as authorized by the Company's regulatory authorities. The Company also has regulatory assets of $147,441 and $121,665 at December 31, 2011 and 2010, respectively, which is the portion of the underfunded status that is probable of recovery through rates in future periods.

The costs of additional security measures that were implemented to protect facilities after the terrorist attacks on September 11, 2001 have been deferred by certain subsidiaries. These costs are recognized in the rates charged for water service by certain subsidiaries. These costs are being recovered over periods ranging from five to ten years from the time of regulatory approval.

Business services project expenses consist of reengineering and start-up activities for consolidated customer and shared administrative service centers that began operations in 2001. These costs are recognized in the rates charged for water service by certain subsidiaries.

Tank painting costs are generally deferred and amortized to current operations on a straight-line basis over periods ranging from two to 15 years, as authorized by the regulatory authorities in their determination of rates charged for service.

The Company amortizes rate case expenditures over regulatory approved amortization periods, typically three years. Rate case proceeding expenditures probable of future recovery are deferred.

Purchase premium recoverable through rates is primarily the recovery of the acquisition premiums related to an asset acquisition by the Company's California subsidiary during 2002, and acquisitions in 2007 by the Company's New Jersey subsidiary. As authorized for recovery by the California and New Jersey Regulators, these costs are being amortized to operations through November 2048.

Environmental remediation recoverable through rates is the recovery of costs incurred by the Company's California subsidiary under a settlement agreement entered into with NOAA to improve habitat conditions in the Carmel River Watershed.

Coastal water project costs include preliminary costs associated with the studying, testing and design of alternatives to help solve water supply shortages in Monterey, California. Coastal water project costs incurred through December 31, 2009 have been reviewed and approved for recovery through a surcharge. Costs deferred during 2011 and 2010 totaled $2,528 and $7,677, respectively. The Company believes it is probable that the costs incurred since the last rate review will also be recoverable.

San Clemente Dam project costs include deferred costs for the Company's California subsidiary to investigate alternatives to strengthen or remove the San Clemente Dam due to potential earthquake or flood safety concerns. In November 2011, a Proposed Decision ("PD") was issued by the Administrative Law Judge ("ALJ") assigned to the matter. In the PD, the ALJ recommended that recovery of virtually all of the historical costs should be disallowed. The Company's California subsidiary has filed comments with the California Public Utility Commission ("CPUC") contending that the PD is unreasonable, unsupported by and contrary to the evidence, and contrary to law and policy. The PD is currently under review by the CPUC, which has delayed issuing a decision on several occasions and most recently has indicated that it will not vote on a decision until April 2012. The Company believes there are sound reasons for the CPUC to modify the PD to permit recovery of the historical costs. These costs are not yet in rates; however, the Company believes it is probable that the costs incurred will be recoverable.

Other regulatory assets include certain deferred employee benefit costs, deferred treatment facility costs, as well as various regulatory balancing accounts.

The components of regulatory liabilities at December 31 are as follows:

	2011		2010
Removal costs recovered through rates	$	272,618	$	260,947
Other		53,211		35,174
	$	325,829	$	296,121

Removal costs recovered through rates are retirement costs recovered during the life of the associated assets. In December 2008, the Company's subsidiary in New Jersey, at the direction of the New Jersey Regulator, began to amortize $48,000 of the total balance into operations via straight line amortization through November 2048.

Other regulatory liabilities include legal settlement proceeds, deferred gains, future customer refunds, and various regulatory balancing accounts. The Company's increased pension contributions in 2011 resulted in increased pension balancing accounts.

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Stockholders' Equity (Narrative) (Details) (USD $) Share data in Thousands, except Per Share data, unless otherwise specified	0 Months Ended	12 Months Ended					12 Months Ended			1 Months Ended	12 Months Ended
	Aug. 15, 2010	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009	Dec. 09, 2011	May 31, 2009	Dec. 31, 2011 Stock Option [Member] years	Dec. 31, 2010 Stock Option [Member]	Dec. 31, 2009 Stock Option [Member]	Aug. 31, 2010 Restricted Stock Units [Member]	Dec. 31, 2011 Restricted Stock Units [Member] years	Dec. 31, 2010 Restricted Stock Units [Member]	Dec. 31, 2009 Restricted Stock Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares available for issue		4,873
Declared dividends per share					$ 0.23
Dividends accrued		$ 40,403,000
Total shares authorized for grant						15,500
Shares available for grant		10,948
Common stock cancelled	33						71
Options vested	247									12
Additional expense related to modifications in operations and maintenance expense	315											12
Total grant date fair value of stock options							4,578	4,505	92		2,040	2,204	438
Restricted stock units, cancelled										9	18
Unrecognized compensation cost							3,389				3,172
Weighted-average period in years, unrecognized compensation cost							1.6				1.3
Dividends payable											921	474	279
Lesser of fair market value		90.00%
Shares reserved for issuance		1,592
Shares issued		121	119	129
Compensation costs		$ 486	$ 355	$ 388
Stock options and restricted stock unit awards amortized, service period (years)		three-year

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Short-Term Debt (Schedule Of Available Capacity Under Commercial Paper Program) (Details) (Commercial Paper Program [Member], USD $) In Thousands, unless otherwise specified	Dec. 31, 2011	Dec. 31, 2010
Commercial Paper Program [Member]
Short-term Debt [Line Items]
Commercial paper program	$ 700,000	$ 700,000
Commercial paper program available capacity	$ 218,900	$ 524,700

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Stockholders' Equity (Cash Dividend Payment During Period) (Details) (USD $) In Thousands, except Per Share data, unless otherwise specified	3 Months Ended
	Dec. 31, 2011	Sep. 30, 2011	Jun. 30, 2011	Mar. 31, 2011	Dec. 31, 2010	Sep. 30, 2010	Jun. 30, 2010	Mar. 31, 2010
Stockholders' Equity [Abstract]
Dividends per share	$ 0.23	$ 0.23	$ 0.22	$ 0.22	$ 0.22	$ 0.22	$ 0.21	$ 0.21
Total dividends paid	$ 40,392	$ 40,358	$ 38,580	$ 38,525	$ 38,476	$ 38,457	$ 36,689	$ 36,679

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Employee Benefits (Schedule Of Expected Benefit Payments) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2011
Pension Plan Assets [Member] | Expected Benefit Payments [Member]
Defined Benefit Plan Disclosure [Line Items]
2012	$ 47,139
2013	53,268
2014	59,412
2015	65,742
2016	72,373
2017-2021	458,798
Postretirement Benefit Plan Assets [Member] | Expected Benefit Payments [Member]
Defined Benefit Plan Disclosure [Line Items]
2012	26,188
2013	28,794
2014	31,641
2015	34,618
2016	37,581
2017-2021	228,379
Postretirement Benefit Plan Assets [Member] | Expected Federal Subsidy Payments [Member]
Defined Benefit Plan Disclosure [Line Items]
2012	1,814
2013	1,994
2014	2,161
2015	2,328
2016	2,515
2017-2021	$ 15,770

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Goodwill (Summary Of Changes In Goodwill Assets) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Nov. 30, 2011
Goodwill [Line Items]
Cost, beginning balance	$ 3,635,874	$ 3,635,563
Accumulated Impairment, beginning balance	(2,440,289)	(2,440,289)
Total Net, beginning balance	1,195,585	1,195,274	1,195,069
Reclassifications and other activity, cost	(516)	311
Reclassifications and other activity, accumulated impairment	0	0
Cost, ending balance	3,635,358	3,635,874
Accumulated Impairment, ending balance	(2,440,289)	(2,440,289)
Total Net, ending balance	1,195,069	1,195,585	1,195,069
Regulated Businesses [Member]
Goodwill [Line Items]
Cost, beginning balance	3,399,884	3,399,848
Accumulated Impairment, beginning balance	(2,332,670)	(2,332,670)
Reclassifications and other activity, cost	(516)	36
Reclassifications and other activity, accumulated impairment	0	0
Cost, ending balance	3,399,368	3,399,884
Accumulated Impairment, ending balance	(2,332,670)	(2,332,670)
Market Based Units [Member]
Goodwill [Line Items]
Cost, beginning balance	235,990	235,715
Accumulated Impairment, beginning balance	(107,619)	(107,619)
Reclassifications and other activity, cost	0	275
Reclassifications and other activity, accumulated impairment	0	0
Cost, ending balance	235,990	235,990
Accumulated Impairment, ending balance	$ (107,619)	$ (107,619)

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Income Taxes (Components Of The Net Deferred Tax Liability From Continuing Operations) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2011	Dec. 31, 2010
Income Taxes [Abstract]
Advances and contributions	$ 475,280	$ 463,694
Deferred investment tax credits	11,202	11,789
Other postretirement benefits	101,258	92,620
Tax losses and credits	284,636	327,128
Pension benefits	132,972	141,530
Unamortized debt discount, net	23,872	22,889
Other	13,308	8,429
Deferred tax assets, Gross	1,042,528	1,068,079
Valuation allowance	(20,701)	(22,733)
Deferred tax assets, Net	1,021,827	1,045,346
Utility plant, principally due to depreciation differences	1,958,044	1,846,338
Income taxes recoverable through rates	94,331	93,495
Deferred security costs	1,982	3,065
Deferred business services project expenses	4,573	4,566
Deferred other postretirement benefits	58,238	48,155
Deferred pension benefits	97,899	78,972
Other	95,557	81,005
Deferred Tax Liabilities, Total	2,310,624	2,155,596
Deferred Tax Assets (Liabilities), Net, Total	$ (1,288,797)	$ (1,110,250)

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Utility Plant (Tables)

12 Months Ended

Dec. 31, 2011

Utility Plant [Abstract]

Components Of Utility Plant By Category

	Range of Remaining Useful Lives		2011		2010
Water plant
Land and other non-depreciable assets			$	128,286	$	125,648
Sources of supply		20 to 127 Years		565,301		527,552
Treatment and pumping facilities		3 to 101 Years		2,665,525		2,524,241
Transmission and distribution facilities		9 to 127 Years		6,632,828		6,333,032
Services, meters and fire hydrants		6 to 96 Years		2,539,696		2,402,038
General structures and equipment		3 to 112 Years		693,880		643,973
Wastewater plant		4 to 86 Years		546,002		519,219
Construction work in progress				460,529		299,733
				14,232,047		13,375,436
Less accumulated depreciation				3,360,005		3,134,094
			$	10,872,042	$	10,241,342

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Acquisitions And Divestitures (Narrative) (Details) (USD $)	1 Months Ended		12 Months Ended			1 Months Ended	3 Months Ended	1 Months Ended	3 Months Ended		12 Months Ended
	Dec. 31, 2011	Jul. 31, 2011 customers	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009	Jan. 31, 2012 Arizona And New Mexico Subsidiaries [Member]	Mar. 31, 2011 Arizona And New Mexico Subsidiaries [Member]	Jun. 30, 2011 Texas Subsidiary [Member]	Mar. 31, 2011 Texas Subsidiary [Member]	Jun. 30, 2011 Ohio Subsidiary [Member]	Dec. 31, 2011 Ohio Subsidiary [Member]	Dec. 31, 2009 Regulated Water And Wastewater Systems [Member]	Dec. 31, 2009 Market-Based Operations Segment [Member]
Business Acquisition [Line Items]
Purchase price	$ 7,220,000	$ 71,000,000	$ 7,220,000	$ 1,642,000	$ 18,144,000
Business acquisition, number of companies acquired		7	9	6	7							6	1
Business acquisition, number of customers acquired		50,000
Purchase price allocation, assets acquired	12,919,000		12,919,000		29,462,000
Purchase price allocation, plant and equipment	12,814,000		12,814,000	3,064,000	17,843,000
Purchase price allocation, current assets					5,857,000
Purchase price allocation, goodwill					606,000
Purchase price allocation, long-lived assets					5,156,000
Purchase price allocation, liabilities assumed	4,945,000		4,945,000	1,422,000	11,318,000
Purchase price allocation, debt					3,990,000
Purchase price allocation, current liabilities					5,732,000
Purchase price allocation, long-term liabilities					970,000
Purchase price allocation, contributions in aid of construction	3,847,000		3,847,000	1,109,000	626,000
Gain on acquisition			754,000
Purchase price allocation regulatory liabilities				313,000
Gain (loss) on sale of assets included in discontinued operation	(3,126,000)						(21,428,000)	142,000		(3,510,000)
Gain (loss) on sale of assets, net of tax, included in discontinued operation	(2,032,000)						(21,099,000)	87,000		(3,456,000)
Impairment charges				0	428,036,000				561,000
Sale price of stock											89,000,000
Proceeds from sale of stock						461,000,000
Estimated value of assumed liabilities											120,000,000
Sale price of assets	2,923,000							6,245,000
Depreciation for assets held for sale			24,807,000
Operating expenses for allocation of impairment changes					$ 21,964

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Short-Term Debt

12 Months Ended

Dec. 31, 2011

Short-Term Debt [Abstract]

Short-Term Debt

Note 12: Short-Term Debt

The components of short-term debt at December 31 are as follows:

	2011		2010
Revolving credit lines	$	0	$	2,734
Commercial paper, net of $52 and $10 discount at 2011 and 2010, respectively		481,048		175,290
Book overdraft		34,002		50,881
Total short-term debt	$	515,050	$	228,905

AWCC had the following available capacity under its commercial paper program at December 31:

	2011		2010
Commercial paper program	$	700,000	$	700,000
Commercial paper program available capacity		218,900		524,700

AWCC has entered into an $840,000 senior unsecured credit facility syndicated among a group of 10 banks with JPMorgan Chase Bank, N.A. acting as administrative agent.

This revolving credit facility is principally used to support the commercial paper program at AWCC and to provide up to $150,000 in letters of credit. On September 15, 2008, a majority of the banks agreed to further extend $685,000 of commitments under this revolving credit facility to September 15, 2013. On December 18, 2008, The Bank of New York Mellon joined the credit facility syndicate with a commitment amount of $40,000 through September 15, 2012. If any lender defaults in its obligation to fund advances, the Company may request the other lenders to assume the default lender's commitment or replace such defaulting lender by designating an assignee willing to assume the commitment, however the remaining lenders have no obligation to assume a defaulting lender's commitment and we can provide no assurances that we will replace a defaulting lender.

At December 31, AWCC had the following sub-limits and available capacity under the credit facility.

	2011		2010
Letter of credit sublimit	$	150,000	$	150,000
Letter of credit available capacity		113,548		113,203

At December 31, 2011, the Company had $36,830 of outstanding letters of credit, $36,452 of which was issued under the revolving credit facility noted above.

The following table presents the short-term borrowing activity for AWCC for the years ended December 31, 2011 and 2010:

	2011			2010
Average borrowings	$	362,615		$	164,782
Maximum borrowings outstanding		494,900			263,500
Weighted average interest rates, computed on a daily basis		0.41	%		0.42	%
Weighted average interest rates, at December 31		0.56	%		0.46	%

Interest rates on advances under the credit facility are based on either prime or the London Interbank Offering Rate ("LIBOR") plus an applicable margin based upon credit ratings of the Company, as well as total outstanding amounts under the agreement at the time of the borrowing. The maximum LIBOR margin is 55 basis points.

The credit facility requires the Company to maintain a ratio of consolidated debt to consolidated capitalization of not more than 0.70 to 1.00. The ratio at December 31, 2011 was 0.58 to 1.00.

None of the Company's borrowings are subject to default or prepayment as a result of a downgrading of securities, although such a downgrading could increase fees and interest charges under the Company's credit facilities.

As part of the normal course of business, the Company routinely enters contracts for the purchase and sale of water, energy, fuels and other services. These contracts either contain express provisions or otherwise permit the Company and its counterparties to demand adequate assurance of future performance when there are reasonable grounds for doing so. In accordance with the contracts and applicable contract law, if the Company is downgraded by a credit rating agency, especially if such downgrade is to a level below investment grade, it is possible that a counterparty would attempt to rely on such a downgrade as a basis for making a demand for adequate assurance of future performance. Depending on the Company's net position with a counterparty, the demand could be for the posting of collateral. In the absence of expressly agreed provisions that specify the collateral that must be provided, the obligation to supply the collateral requested will be a function of the facts and circumstances of the Company's situation at the time of the demand. If the Company can reasonably claim that it is willing and financially able to perform its obligations, it may be possible to successfully argue that no collateral should be posted or that only an amount equal to two or three months of future payments should be sufficient. The Company does not expect to post any collateral which will have a material adverse impact on the Company's results of operations, financial position or cash flows.

AWCC had entered into a one year $10,000 committed revolving line of credit with PNC Bank, N.A. Outstanding borrowings against this line totaled $0 and $2,734 at December 31, 2011 and 2010, respectively. This line of credit was terminated without renewal on December 31, 2011.

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Related Party Transactions (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended	12 Months Ended
	Mar. 31, 2010	Dec. 31, 2009
Related Party Transactions [Abstract]
Purchase of services from subsidiaries	$ 3,225	$ 8,558

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Earnings (Loss) Per Common Share

12 Months Ended

Dec. 31, 2011

Earnings (Loss) Per Common Share [Abstract]

Earnings (Loss) Per Common Share

Note 17: Earnings (Loss) per Common Share

Earnings per share is calculated using the two-class method. The two-class method is an earnings allocation formula that determines earnings per share for each class of common stock and participating security. The Company has participating securities related to restricted stock units, granted under the Company's 2007 Omnibus Equity Compensation Plan, that earn dividend equivalents on an equal basis with common shares. In applying the two-class method, undistributed earnings are allocated to both common shares and participating securities. There were 21 participating securities that were not included in the basic net loss per common share calculation at December 31, 2009 because they were anti-dilutive. The following is a reconciliation of the Company's income (loss) from continuing operations, income (loss) from discontinued operations and net income (loss) and weighted average common shares outstanding for calculating basic net earnings (loss) per share:

	Years Ended December 31,
	2011		2010		2009
Basic
Income (loss) from continuing operations	$	304,929	$	255,072	$	(219,998	)
Income (loss) from discontinued operations, net of tax		4,684		12,755		(13,085	)
Net income (loss)		309,613		267,827		(233,083	)
Less: Distributed earnings to common shareholders		158,708		150,724		137,597
Less: Distributed earnings to participating securities		68		51		0
Undistributed earnings		150,837		117,052		(370,680	)
Undistributed earnings allocated to common shareholders		150,772		117,014		(370,680	)
Undistributed earnings allocated to participating securities		65		38		0
Total income (loss) from continuing operations available to common shareholders, basic	$	304,796	$	254,983	$	(219,998	)
Total income (loss) available to common shareholders, basic	$	309,480	$	267,738	$	(233,083	)
Weighted average common shares outstanding, basic		175,484		174,833		168,164
Basic earnings (loss) per share: (a)
Income (loss) from continuing operations	$	1.74	$	1.46	$	(1.31	)
Income (loss) from discontinued operations, net of tax	$	0.03	$	0.07	$	(0.08	)
Net income (loss)	$	1.76	$	1.53	$	(1.39	)

(a) Amounts may not sum due to rounding.

Diluted earnings (loss) per common share is based on the weighted average number of common shares outstanding adjusted for the dilutive effect of common stock equivalents related to the restricted stock units, stock options, and employee stock purchase plan. The dilutive effect of the common stock equivalents is calculated using the treasury stock method and expected proceeds on vesting of the restricted stock units, exercise of the stock options and purchases under the employee stock purchase plan. The following is a reconciliation of the Company's income (loss) from continuing operations, income (loss) from discontinued operations and net income (loss) and weighted average common shares outstanding for calculating diluted earnings (loss) per share:

	Years Ended December 31,
	2011		2010		2009
Diluted
Total income (loss) from continuing operations available to common shareholders, basic	$	304,796	$	254,983	$	(219,998	)
Income (loss) from discontinued operations, net of tax		4,684		12,755		(13,085	)
Total income (loss) available to common shareholders, basic		309,480		267,738		(233,083	)
Undistributed earnings allocated to participating securities		65		38		0
Total income (loss) from continuing operations available to common shareholders, diluted	$	304,861	$	255,021	$	(219,998	)
Total income (loss) available to common shareholders, diluted	$	309,545	$	267,776	$	(233,083	)
Weighted average common shares outstanding, basic		175,484		174,833		168,164
Restricted stock units		556		264		0
Stock options		490		26		0
Employee stock purchase plan		1		1		0
Weighted average common shares outstanding, diluted		176,531		175,124		168,164
Diluted earnings per share: (a)
Income (loss) from continuing operations	$	1.73	$	1.46	$	(1.31	)
Income (loss) from discontinued operations, net of tax	$	0.03	$	0.07	$	(0.08	)
Net income (loss)	$	1.75	$	1.53	$	(1.39	)

(a) Amounts may not sum due to rounding.

The following potentially dilutive common stock equivalents were not included in the earnings (loss) per share calculations for the years ended December 31 because they were anti-dilutive:

	2011		2010		2009
Stock options		711		1,781		2,265
Stock options where certain performance conditions were not met		0		0		459
Restricted stock units		0		0		258
Restricted stock units where certain performance conditions were not met		22		69		144
Employee stock purchase plan		0		0		32

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Employee Benefits (Narrative) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Defined Benefit Plan Disclosure [Line Items]
Base pay rate of contribution plan	5.25%
Contribution percentage on current liabilities	100.00%
Funding status of current liabilities	80.00%
Minimum reduction of expected future service of plan participants	10.00%
Cost of contribution plan	$ 8,997	$ 8,651	$ 8,082
Collateralized Mortgage Obligations [Member]
Defined Benefit Plan Disclosure [Line Items]
Percentage of Plan Assets, Fixed Income	20.00%
Pension Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Employer contributions	32,931
Postretirement Benefit Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Employer contributions	$ 7,496

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Unaudited Quarterly Data (Tables)

12 Months Ended

Dec. 31, 2011

Unaudited Quarterly Data [Abstract]

Schedule Of Unaudited Quarterly Data

2011	First Quarter		Second Quarter		Third Quarter		Fourth Quarter
	(In thousands, except per share data)
Operating revenues	$	596,715	$	668,873	$	760,869	$	639,779
Operating income		143,250		201,395		281,408		177,083
Income from continuing operations		40,699		74,817		128,495		60,918
Net income		26,233		81,110		137,422		64,848
Basic earnings per common share:
Income from continuing operations	$	0.23	$	0.43	$	0.73	$	0.35
Net income	$	0.15	$	0.46	$	0.78	$	0.37
Diluted earnings per common share:
Income from continuing operations	$	0.23	$	0.42	$	0.73	$	0.34
Net income	$	0.15	$	0.46	$	0.78	$	0.37

2010	First Quarter		Second Quarter		Third Quarter		Fourth Quarter
	(In thousands, except per share data)
Operating revenues	$	554,205	$	630,761	$	744,296	$	625,773
Operating income		123,831		188,367		266,480		149,444
Income from continuing operations		29,328		68,071		119,327		38,346
Net income		30,808		72,751		124,114		40,154
Basic earnings per common share:
Income from continuing operations	$	0.17	$	0.39	$	0.68	$	0.22
Net income	$	0.18	$	0.42	$	0.71	$	0.23
Diluted earnings per common share:
Income from continuing operations	$	0.17	$	0.39	$	0.68	$	0.22
Net income	$	0.18	$	0.42	$	0.71	$	0.23

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Employee Benefits (Schedule Of Net Periodic Benefit Cost Components) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service credit (cost)		$ (175)	$ (79)	$ (46)
Current year actuarial (gain) loss		30,497	11,836	(9,981)
Amortization of actuarial gain (loss)		(4,504)	(4,368)	(5,994)
Total recognized in other comprehensive income		25,818	7,389	(16,021)
Total recognized in net periodic benefit cost and comprehensive income		75,670	67,139	57,250
Pension Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost		33,641	30,675
Interest cost		69,047	67,602
Amortization of actuarial gain (loss)	(29,923)	(409,129)	(302,357)
Postretirement Benefit Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost		13,938	14,663	13,172
Interest cost		31,219	32,149	29,180
Expected return on plan assets		(28,779)	(24,372)	(18,638)
Amortization of Transition obligation (asset)		0	173	173
Amortization of Prior service cost (credit)		(1,924)	(1,180)	(1,180)
Amortization of actuarial (gain) loss		7,133	8,159	9,155
Net periodic benefit cost		21,587	29,592	31,862
Amortization of actuarial gain (loss)	(9,537)	(164,305)	(140,453)
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost		33,641	30,675	28,426
Interest cost		69,047	67,602	62,919
Expected return on plan assets		(72,109)	(56,751)	(42,224)
Amortization of Prior service cost (credit)		722	322	182
Amortization of actuarial (gain) loss		18,551	17,902	23,968
Net periodic benefit cost		$ 49,852	$ 59,750	$ 73,271

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Long-Term Debt (Tables)

12 Months Ended

Dec. 31, 2011

Long-Term Debt [Abstract]

Components Of Long-Term Debt

	Rate	Weighted Average Rate			Maturity Date	2011		2010
Long-term debt of American Water Capital Corp. ("AWCC")(a)
Private activity bonds and government funded debt
Fixed rate	4.85%-6.75%		5.72	%	2018-2040	$	322,610	$	322,610
Senior notes
Fixed rate	5.39%-10.00%		6.25	%	2013-2040		3,089,409		3,117,696
Long-term debt of other subsidiaries
Private activity bonds and government funded debt
Fixed rate	0.00%-6.20%		5.07	%	2012-2039		1,206,332		1,201,723
Mortgage bonds
Fixed rate	5.48%-9.71%		7.40	%	2012-2039		697,800		730,991
Mandatory redeemable preferred stock	4.60%-9.75%		8.43	%	2013-2036		22,101		22,844
Notes payable and other(b)	9.49%-13.96%		12.12	%	2013-2026		1,691		5,689
Long-term debt							5,339,943		5,401,553
Unamortized debt discount, net(c)							43,888		51,154
Fair value adjustment to interest rate hedge							6,111		(345	)
Total long-term debt						$	5,389,942	$	5,452,362

(a) AWCC, which is a wholly-owned subsidiary of the Company, has a strong support agreement with its parent that, under certain circumstances, is the functional equivalent of a guarantee.

(b) Includes capital lease obligations of $1,264 and $5,076 at December 31, 2011 and 2010, respectively.

(c) Includes fair value adjustments previously recognized in acquisition purchase accounting.

Future Sinking Fund Payments And Maturities

Year	Amount
2012	$	28,855
2013		112,594
2014		9,416
2015		49,568
2016		47,172
Thereafter		5,092,338

Long-Term Debt Issued

Company	Type	Interest Rate	Maturity		Amount
Other subsidiaries	Private activity bonds and government funded debt—fixed rate	0.00%-1.56%		2031	$	12,510
Total issuances					$	12,510

Long-Term Debt Retired

Company	Type	Interest Rate	Maturity		Amount
American Water Capital Corp.	Senior notes—fixed rate	6.00%-8.25%		2011-2039	$	28,287
Other subsidiaries	Private activity bonds and government funded debt—fixed rate	0.00%-5.90%		2011-2034		7,976
Other subsidiaries	Mortgage bonds—fixed rate	8.21%-9.71%		2011-2022		33,191
Other subsidiaries	Mandatory redeemable preferred stock	4.60%-9.18%		2013-2019		1,888
Other	Capital leases and other					4,078
Total retirements and redemptions					$	75,420

Derivative Fair Value Balance

Balance sheet classification	December 31, 2011		December 31, 2010
Regulatory and other long-term assets
Other	$	5,824	$	0
Regulatory and other long-term liabilities
Other		0		898
Long-term debt
Long-term debt		6,111		(345	)

Derivative And Hedged Items

Income Statement Classification	December 31, 2011			December 31, 2010
Interest, net
Gain (loss) on swap	$	6,722		$	(898	)
(Loss) gain on borrowing		(6,455	)		345
Hedge ineffectiveness		267			(553	)

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Commitments And Contingencies (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Unrecorded Unconditional Purchase Obligation [Line Items]
Loss contingency, estimate of possible loss	$ 2,900
Loss contingency, range of possible loss, maximum	9,700
Estimated capital expenditures under legal and binding contractual obligations	171,878
Expenses for purchase of water from regulated subsidiaries	104,384	103,898	96,053
Estimated annual commitment related to purchase of water in 2012	48,916
Estimated annual commitment related to purchase of water in 2013	47,576
Estimated annual commitment related to purchase of water in 2014	47,452
Estimated annual commitment related to purchase of water in 2015	47,404
Estimated annual commitment related to purchase of water in 2016	43,439
Estimated annual commitment related to purchase of water thereafter	448,920
Military Services Agreements [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Estimated remaining contract revenue	2,037,000
Operations And Maintenance [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Estimated remaining contract revenue	$ 1,076,000
Minimum [Member] | Military Services Agreements [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Agreements expiration period	2051
Minimum [Member] | Operations And Maintenance [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Agreements expiration period	2012
Maximum [Member] | Military Services Agreements [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Agreements expiration period	2060
Maximum [Member] | Operations And Maintenance [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Agreements expiration period	2048

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Consolidated Statements Of Operations And Comprehensive Income (Loss) (Parenthetical) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Consolidated Statements Of Operations And Comprehensive Income (Loss) [Abstract]
Change in employee benefit plan funded status, tax	$ (19,498)	$ (7,567)	$ 6,381
Prior service cost, tax	112	50	29
Actuarial loss, tax	$ 2,879	$ 2,793	$ 3,832

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General Taxes (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
General Tax Expense [Line Items]
General taxes	$ 210,478	$ 205,597	$ 186,620
Gross Receipts And Franchise [Member]
General Tax Expense [Line Items]
General taxes	90,674	86,063	79,410
Property And Capital Stock [Member]
General Tax Expense [Line Items]
General taxes	77,330	78,184	70,907
Payroll [Member]
General Tax Expense [Line Items]
General taxes	31,705	31,089	27,834
Other General [Member]
General Tax Expense [Line Items]
General taxes	$ 10,769	$ 10,261	$ 8,469

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Organization And Operation

12 Months Ended

Dec. 31, 2011

Organization And Operation [Abstract]

Organization And Operation

Note 1: Organization and Operation

American Water Works Company, Inc. ("AWW") and its subsidiaries (collectively referred to herein as the "Company") is the holding company for regulated and market-based subsidiaries throughout the United States of America and two Canadian provinces. The regulated subsidiaries included in continuing operations provide water and wastewater services as public utilities. These regulated subsidiaries are operationally segregated into 16 U.S. states in which the Company operates regulated utilities. The market-based subsidiaries include various lines of business including Homeowner Services, which provides water and sewer line protection plans for homeowners, and the Contract Operations group, which conducts operation and maintenance of water and wastewater facilities for the U.S. Military, municipalities and the food and beverage industry.

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Other Receivables, Net (Schedule Of Market Based Allowances For Uncollectible Accounts) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Valuation and Qualifying Accounts Disclosure [Line Items]
Balance at January 1	$ (17,474)	$ (18,148)	$ (16,859)
Amounts charged to (expense) income	(16,178)	(17,973)	(20,999)
Amounts written off	21,855	22,124	23,104
Recoveries of amounts written off	(3,522)	(3,477)	(3,394)
Balance at December 31	(15,319)	(17,474)	(18,148)
Allowance For Market Based Trade Accounts Receivable [Member]
Valuation and Qualifying Accounts Disclosure [Line Items]
Balance at January 1	(3,015)	(3,520)	(4,622)
Amounts charged to (expense) income	(3,583)	(223)	796
Amounts written off	2,886	748	476
Recoveries of amounts written off	645	(20)	(170)
Balance at December 31	$ (3,067)	$ (3,015)	$ (3,520)

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Long-Term Debt (Derivative And Hedged Items) (Details) (Interest, Net [Member], USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010
Interest, Net [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on swap	$ 6,722	$ (898)
(Loss) gain on borrowing	(6,455)	345
Hedge ineffectiveness	$ 267	$ (553)

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Employee Benefits (Schedule Of Estimated Amounts Amortized Accumulated Other Comprehensive Income) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009	Dec. 31, 2012 Pension Plan Assets [Member]	Dec. 31, 2011 Pension Plan Assets [Member]	Dec. 31, 2010 Pension Plan Assets [Member]	Dec. 31, 2012 Postretirement Benefit Plan Assets [Member]	Dec. 31, 2011 Postretirement Benefit Plan Assets [Member]	Dec. 31, 2010 Postretirement Benefit Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Net actuarial loss (gain)	$ 4,504	$ 4,368	$ 5,994	$ 29,923	$ 409,129	$ 302,357	$ 9,537	$ 164,305	$ 140,453
Prior service cost (credit)				722	5,858	6,580	(1,914)	(16,864)	(18,788)
Net amount recognized				$ 30,645	$ 414,987	$ 308,937	$ 7,623	$ 147,441	$ 121,665

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Stockholders' Equity (Weighted Average Assumptions) (Details) (Stock Option [Member], USD $)	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Stock Option [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Dividend yield	3.25%	3.83%	3.86%
Expected volatility	29.32%	31.77%	31.67%
Risk-free interest rate	1.93%	2.14%	1.79%
Expected life (years)	4.35	4.29	4.36
Exercise price	$ 27.08	$ 22.01	$ 20.70
Grant date fair value per share	$ 5.14	$ 4.33	$ 3.96

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Fair Values Of Financial Instruments

12 Months Ended

Dec. 31, 2011

Fair Values Of Financial Instruments [Abstract]

Fair Values Of Financial Instruments

Note 18: Fair Values of Financial Instruments

The following methods and assumptions were used by the Company in estimating its fair value disclosures for financial instruments:

Current assets and current liabilities: The carrying amounts reported in the Consolidated Balance Sheets for current assets and current liabilities, including revolving credit debt, due to the short-term maturities and variable interest rates, approximate their fair values.

Preferred stock with mandatory redemption requirements and long-term debt: The fair values of preferred stock with mandatory redemption requirements and long-term debt are determined by a valuation model which is based on a conventional discounted cash flow methodology and utilizes assumptions of current market rates. As a majority of the Company's debts do not trade in active markets, the Company calculated a base yield curve using a risk-free rate (a U.S. Treasury securities yield curve) plus a credit spread that is based on the following two factors: an average of the Company's own publicly-traded debt securities and the current market rates for U.S. Utility BBB+ debt securities. The Company used these yield curve assumptions to derive a base yield and then adjusted the base yield for specific features of the debt securities of call features, coupon tax treatment and collateral.

The carrying amounts (including fair value adjustments previously recognized in acquisition purchase accounting) and fair values of the financial instruments are as follows:

As of December 31, 2011	Carrying Amount		Fair Value
Preferred stocks with mandatory redemption requirements	$	22,036	$	26,458
Long-term debt (excluding capital lease obligations)		5,366,642		6,230,547

As of December 31, 2010	Carrying Amount		Fair Value
Preferred stocks with mandatory redemption requirements	$	22,794	$	25,475
Long-term debt (excluding capital lease obligations)		5,424,492		5,841,448

Fair Value Measurements

To increase consistency and comparability in fair value measurements, FASB guidance establishes a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value into three levels as follows:

• Level 1—quoted prices (unadjusted) in active markets for identical assets or liabilities that the Company has the ability to access as of the reporting date. Financial assets and liabilities utilizing Level 1 inputs include active exchange-traded equity securities, exchange-based derivatives, mutual funds and money market funds.

• Level 2—inputs other than quoted prices included within Level 1 that are directly observable for the asset or liability or indirectly observable through corroboration with observable market data. Financial assets and liabilities utilizing Level 2 inputs include fixed income securities, non-exchange-based derivatives, commingled investment funds not subject to purchase and sale restrictions and fair-value hedges.

• Level 3—unobservable inputs, such as internally-developed pricing models for the asset or liability due to little or no market activity for the asset or liability. Financial assets and liabilities utilizing Level 3 inputs include infrequently-traded non-exchange-based derivatives and commingled investment funds subject to purchase and sale restrictions.

Recurring Fair Value Measurements

The following table presents assets and liabilities measured and recorded at fair value on a recurring basis and their level within the fair value hierarchy as of December 31, 2011 and 2010, respectively:

	At Fair Value as of December 31, 2011
Recurring Fair Value Measures	Level 1		Level 2			Level 3		Total
Assets:
Restricted funds	$	57,941		—			—	$	57,941
Rabbi trust investments		—	$	518			—		518
Deposits		2,287		—			—		2,287
Mark-to-market derivative asset		—		5,824			—		5,824
Total assets		60,228		6,342			—		66,570
Liabilities:
Deferred compensation obligation		—		9,036			—		9,036
Total liabilities		—		9,036			—		9,036
Total net assets (liabilities)	$	60,228	$	(2,694	)		—	$	57,534

	At Fair Value as of December 31, 2010
Recurring Fair Value Measures	Level 1		Level 2			Level 3		Total
Assets:
Restricted funds	$	120,784		—			—	$	120,784
Rabbi trust investments		—	$	1,552			—		1,552
Deposits		1,381		—			—		1,381
Total assets		122,165		1,552			—	$	123,717
Liabilities:
Deferred compensation obligation		—		9,180			—		9,180
Mark-to-market derivative liability		—		898			—		898
Total liabilities		—		10,078			—		10,078
Total net assets (liabilities)	$	122,165	$	(8,526	)		—	$	113,639

Restricted funds—The Company's restricted funds primarily represent proceeds received from financings for the construction and capital improvement of facilities and from customers for future services under operations and maintenance projects. The proceeds of these financings are held in escrow until the designated expenditures are incurred. Restricted funds expected to be released within twelve months subsequent to year end are classified as current.

Rabbi trust investments—The Company's rabbi trust investments consist primarily of fixed income investments from which supplemental executive retirement plan benefits are paid. The Company includes these assets in other long-term assets.

Deposits—Deposits includes escrow funds and certain other deposits held in trust. The Company includes cash deposits in other current assets.

Deferred compensation obligations—The Company's deferred compensation plans allow participants to defer certain cash compensation into notional investment accounts. The Company includes such plans in other long-term liabilities. The value of the Company's deferred compensation obligations is based on the market value of the participants' notional investment accounts. The notional investments are comprised primarily of mutual funds, which are based on observable market prices.

Mark-to-market derivative asset and liability-The Company utilizes fixed-to-floating interest-rate swaps, typically designated as fair-value hedges, to achieve a targeted level of variable-rate debt as a percentage of total debt. The Company uses a calculation of future cash inflows and estimated future outflows, which are discounted, to determine the current fair value. Additional inputs to the present value calculation include the contract terms, counterparty credit risk, interest rates and market volatility.

See Note 15 for the Company's fair value of qualified pension and postretirement welfare plans' assets.

Non-recurring Fair Value Measurements

As discussed in Note 8, the Company recognized continuing operations goodwill impairment charges of $0, $0, and $428,036 for the years ended December 31, 2011, 2010 and 2009, respectively. The Company's goodwill valuation model includes significant unobservable inputs and falls within Level 3 of the fair value hierarchy.

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Unaudited Quarterly Data (Schedule Of Unaudited Quarterly Data) (Details) (USD $) In Thousands, except Per Share data, unless otherwise specified	3 Months Ended								12 Months Ended
	Dec. 31, 2011	Sep. 30, 2011	Jun. 30, 2011	Mar. 31, 2011	Dec. 31, 2010	Sep. 30, 2010	Jun. 30, 2010	Mar. 31, 2010	Dec. 31, 2011		Dec. 31, 2010		Dec. 31, 2009
Unaudited Quarterly Data [Abstract]
After-tax charge to reduce net asset values	$ 24,555
Write-downs for discontinued operations and net income			3,456	21,099
Operating revenues	639,779	760,869	668,873	596,715	625,773	744,296	630,761	554,205	2,666,236		2,555,035		2,290,446
Operating income	177,083	281,408	201,395	143,250	149,444	266,480	188,367	123,831	803,136		728,122		183,835
Income from continuing operations	60,918	128,495	74,817	40,699	38,346	119,327	68,071	29,328	304,929		255,072		(219,998)
Net income	$ 64,848	$ 137,422	$ 81,110	$ 26,233	$ 40,154	$ 124,114	$ 72,751	$ 30,808	$ 309,613		$ 267,827		$ (233,083)
Income from continuing operations, Basic	$ 0.35	$ 0.73	$ 0.43	$ 0.23	$ 0.22	$ 0.68	$ 0.39	$ 0.17	$ 1.74	[1]	$ 1.46	[1]	$ (1.31)	[1]
Net income, Basic	$ 0.37	$ 0.78	$ 0.46	$ 0.15	$ 0.23	$ 0.71	$ 0.42	$ 0.18	$ 1.76	[1]	$ 1.53	[1]	$ (1.39)	[1]
Income from continuing operations, Diluted	$ 0.34	$ 0.73	$ 0.42	$ 0.23	$ 0.22	$ 0.68	$ 0.39	$ 0.17	$ 1.73	[1],[2]	$ 1.46	[1],[2]	$ (1.31)	[1],[2]
Net income, Diluted	$ 0.37	$ 0.78	$ 0.46	$ 0.15	$ 0.23	$ 0.71	$ 0.42	$ 0.18	$ 1.75	[1],[2]	$ 1.53	[1],[2]	$ (1.39)	[1],[2]

[1] Amounts may not sum due to rounding.

[2] Amounts may not sum due to rounding

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Stockholders' Equity (Additional Information To Restricted Stock Activity) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Income tax benefit (shortfall)	$ 3,903	$ 4,030	$ 2,965
Restricted Stock Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Intrinsic value	2,068	1,241	51
Income tax benefit (shortfall)	$ 99	$ 15	$ (2)

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Goodwill (Tables)

12 Months Ended

Dec. 31, 2011

Goodwill [Abstract]

Summary Of Changes In Goodwill Assets

	Regulated Unit						Market-Based Units					Consolidated
	Cost			Accumulated Impairment			Cost		Accumulated Impairment			Cost			Accumulated Impairment			Total Net
Balance at January 1, 2010	$	3,399,848		$	(2,332,670	)	$	235,715	$	(107,619	)	$	3,635,563		$	(2,440,289	)	$	1,195,274
Reclassifications and other activity		36			0			275		0			311			0			311
Balance at December 31, 2010	$	3,399,884		$	(2,332,670	)	$	235,990	$	(107,619	)	$	3,635,874		$	(2,440,289	)	$	1,195,585
Reclassifications and other activity		(516	)		0			0		0			(516	)		0			(516	)
Balance at December 31, 2011	$	3,399,368		$	(2,332,670	)	$	235,990	$	(107,619	)	$	3,635,358		$	(2,440,289	)	$	1,195,069

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Long-Term Debt

12 Months Ended

Dec. 31, 2011

Long-Term Debt [Abstract]

Long-Term Debt

Note 11: Long-Term Debt

The Company primarily incurs long-term debt to fund capital expenditures of the regulated subsidiaries. The components of long-term at December 31 are:

	Rate	Weighted Average Rate			Maturity Date	2011		2010
Long-term debt of American Water Capital Corp. ("AWCC")(a)
Private activity bonds and government funded debt
Fixed rate	4.85%-6.75%		5.72	%	2018-2040	$	322,610	$	322,610
Senior notes
Fixed rate	5.39%-10.00%		6.25	%	2013-2040		3,089,409		3,117,696
Long-term debt of other subsidiaries
Private activity bonds and government funded debt
Fixed rate	0.00%-6.20%		5.07	%	2012-2039		1,206,332		1,201,723
Mortgage bonds
Fixed rate	5.48%-9.71%		7.40	%	2012-2039		697,800		730,991
Mandatory redeemable preferred stock	4.60%-9.75%		8.43	%	2013-2036		22,101		22,844
Notes payable and other(b)	9.49%-13.96%		12.12	%	2013-2026		1,691		5,689
Long-term debt							5,339,943		5,401,553
Unamortized debt discount, net(c)							43,888		51,154
Fair value adjustment to interest rate hedge							6,111		(345	)
Total long-term debt						$	5,389,942	$	5,452,362

(a) AWCC, which is a wholly-owned subsidiary of the Company, has a strong support agreement with its parent that, under certain circumstances, is the functional equivalent of a guarantee.

(b) Includes capital lease obligations of $1,264 and $5,076 at December 31, 2011 and 2010, respectively.

(c) Includes fair value adjustments previously recognized in acquisition purchase accounting.

All $697,800 of the subsidiaries' mortgage bonds and $1,150,003 of the $1,206,332 total subsidiaries' private activity bonds and government funded debt are collateralized by utility plant.

Long-term debt indentures contain a number of covenants that, among other things, limit, subject to certain exceptions, the Company from issuing debt secured by the Company's assets. Certain long term notes require the Company to maintain a ratio of consolidated total indebtedness to consolidated total capitalization of not more than 0.70 to 1.00. The ratio at December 31, 2011 was 0.58 to 1.00. In addition, the Company has $1,701,322 of notes which include the right to redeem the notes in whole or in part from time to time subject to certain restrictions.

The future sinking fund payments and maturities are as follows:

Year	Amount
2012	$	28,855
2013		112,594
2014		9,416
2015		49,568
2016		47,172
Thereafter		5,092,338

The following long-term debt was issued in 2011:

Company	Type	Interest Rate	Maturity		Amount
Other subsidiaries	Private activity bonds and government funded debt—fixed rate	0.00%-1.56%		2031	$	12,510
Total issuances					$	12,510

The following long-term debt was retired through optional redemption or payment at maturity during 2011:

Company	Type	Interest Rate	Maturity		Amount
American Water Capital Corp.	Senior notes—fixed rate	6.00%-8.25%		2011-2039	$	28,287
Other subsidiaries	Private activity bonds and government funded debt—fixed rate	0.00%-5.90%		2011-2034		7,976
Other subsidiaries	Mortgage bonds—fixed rate	8.21%-9.71%		2011-2022		33,191
Other subsidiaries	Mandatory redeemable preferred stock	4.60%-9.18%		2013-2019		1,888
Other	Capital leases and other					4,078
Total retirements and redemptions					$	75,420

Included in the capital lease redemptions above is a non-cash redemption of $3,487 associated with a cancelled sublease and a capital lease arrangement.

Interest, net includes interest income of approximately $10,942, $10,320 and $10,397 in 2011, 2010 and 2009, respectively.

One of the principal market risks to which the Company is exposed is changes in interest rates. In order to manage the exposure, the Company follows risk management policies and procedures, including the use of derivative contracts such as swaps. The Company uses a combination of fixed-rate and variable-rate debt to manage interest rate exposure. The Company does not enter into derivative contracts for speculative purposes and does not use leveraged instruments. The derivative contracts entered into are for periods consistent with the related underlying exposures. The Company is exposed to the risk that counterparties to derivative contracts will fail to meet their contractual obligations. The Company minimizes the counterparty credit risk on these transactions by dealing only with leading, credit-worthy financial institutions having long-term credit ratings of "A" or better.

On July 12, 2010, the Company entered into an interest rate swap to hedge $100,000 of its 6.085% fixed-rate debt maturing 2017. The Company will pay variable interest of six-month LIBOR plus 3.422%. The swap is accounted for as a fair-value hedge, and matures with the fixed-rate debt in 2017. The Company uses a combination of fixed-rate and variable-rate debt to manage interest rate exposure.

At December 31, 2011 and 2010, the Company had a $100,000 notional amount variable interest rate swap fair-value hedge outstanding, respectively. The following table provides a summary of the derivative fair value balance recorded by the Company as of December 31, 2011 and 2010 and the line item in the Consolidated Balance Sheet in which such amount is recorded:

Balance sheet classification	December 31, 2011		December 31, 2010
Regulatory and other long-term assets
Other	$	5,824	$	0
Regulatory and other long-term liabilities
Other		0		898
Long-term debt
Long-term debt		6,111		(345	)

For derivative instruments that are designated and qualify as fair-value hedges, the gain or loss on the hedge instrument as well as the offsetting loss or gain on the hedged item attributable to the hedged risk are recognized in current net income (loss). The Company includes the gain or loss on the derivative instrument and the offsetting loss or gain on the hedged item in interest expense as follows:

Income Statement Classification	December 31, 2011			December 31, 2010
Interest, net
Gain (loss) on swap	$	6,722		$	(898	)
(Loss) gain on borrowing		(6,455	)		345
Hedge ineffectiveness		267			(553	)

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Employee Benefits (Schedule Of Expected Cash Flows For Pension And Postretirement Benefit Plans) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2011
Pension Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Expected employer contributions, 2012	$ 32,931
Pension Plan Assets [Member] | To Plan Trusts [Member]
Defined Benefit Plan Disclosure [Line Items]
Expected employer contributions, 2012	126,700
Pension Plan Assets [Member] | To Plan Participants [Member]
Defined Benefit Plan Disclosure [Line Items]
Expected employer contributions, 2012	1,909
Postretirement Benefit Plan Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Expected employer contributions, 2012	7,496
Postretirement Benefit Plan Assets [Member] | To Plan Trusts [Member]
Defined Benefit Plan Disclosure [Line Items]
Expected employer contributions, 2012	29,983
Postretirement Benefit Plan Assets [Member] | To Plan Participants [Member]
Defined Benefit Plan Disclosure [Line Items]
Expected employer contributions, 2012	$ 33