Press Release
Exhibit 99.1
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| FOR IMMEDIATE RELEASE: |
|
Feb. 28, 2012 |
NW Natural Reports 2011 & Q4 Results
Issues 2012 EPS Guidance
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• |
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Consolidated earnings for fiscal year 2011 were $2.39 per share on net income of $63.9 million, compared to $2.73 per share on net income of $72.7
million in 2010. |
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• |
|
Utility results were strong despite an earnings decline due to special charges related to a repeal of utility tax legislation in Oregon.
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• |
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NW Natural continues to rank nationally as one of the top two gas utilities for customer satisfaction by J.D. Power & Associates.
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• |
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Successfully initiated a five-year $250 million investment with Encana Oil & Gas to acquire gas reserves for the company’s utility
customers over a 30-year period. |
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• |
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Oregon and Washington customers saw gas rates decline for the third year in a row due to lower natural gas commodity prices. Over the past three years,
rates have decreased more than 20 percent in both states. |
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• |
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The company raised its dividend by 4 percent in November, reflecting the 56th consecutive year of increasing dividends paid to shareholders. |
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• |
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NW Natural filed a general rate case in Oregon in late December, the first since 2002. |
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• |
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Established its 2012 earnings-per-share guidance range of $2.35 to $2.55. |
PORTLAND, ORE.—Northwest Natural Gas Company, dba NW Natural (NYSE: NWN), posted earnings per share of $2.39 on net income of $63.9 million, compared to $2.73 per share on net income of
$72.7 million in 2010, a 12 percent decrease year-over-year. Results for 2011 were negatively impacted by an after-tax charge of $4.4 million, equivalent to 17 cents per share, for the repeal of utility tax legislation (SB 408) which had been in
effect since 2006. Conversely, results for 2010 were positively impacted by an after-tax gain of $4.6 million, or 17 cents per share, for an earnings benefit from SB 408, and an after-tax gain of $3.6 million, or 14 cents per share, for the refund
of property taxes from an Oregon tax appeal ruling.
“Despite the regulatory and economic headwinds we faced, 2011 was a good year on
many fronts for NW Natural,” said Gregg Kantor, President and Chief Executive Officer. “In addition to passing along lower commodity prices to our customers and maintaining our high customer satisfaction ranking in the J.D. Power national
survey, the company completed a landmark gas reserves investment that will benefit our customers and shareholders in the years ahead,” Kantor noted.
Full-Year financial and operating highlights
Income and earnings per share
For the 12-months ended Dec. 31, 2011, NW Natural earnings were $2.39 per share on net income of $63.9 million. This compared to the
company’s results in 2010 of $2.73 per share on net income of $72.7 million. The decrease in earnings was primarily due to the 2011 charge, and the 2010 gain, related to utility tax legislation and the property tax settlement in 2010.
In 2011, utility operations provided earnings of $2.26 per share on net income of $60.5 million. This compared to $2.49 per share on net
income of $66.3 million in 2010. The major factor contributing to the change was an aggregate $14.9 million reduction in utility net operating revenues (utility margin), reflecting a $7.4 million write-off in 2011, plus a $7.7 million gain
recognized in 2010, for the repealed Oregon legislative rule on utility taxes paid. This utility margin loss was partially offset by an $11.3 million margin gain from residential and commercial customers, including the effects of weather
normalization and decoupling mechanisms.
1
In 2011, gas storage contributed 15 cents per share on net income of $4.1 million, compared to 2010 earnings
per share of 23 cents per share on net income of $6.1 million. The primary reason for the decline was lower storage pricing. Net income in 2011 from the company’s gas storage operations at Mist, Ore., including optimization revenues, was down
$2.3 million compared to 2010.
Operating results from other non-utility investments and activities were a net loss of 2 cents per share in
2011 compared to net income of 1 cent per share in 2010, primarily reflecting charges totaling $1.3 million pre-tax related to the partial write-down of the company’s investment in the Palomar pipeline project.
Operational results for full-year
The
utility’s total gas sales and transportation deliveries for 2011, excluding deliveries of gas stored for others, were up to 1.15 billion therms, compared to 1.06 billion therms in 2010. The 9 percent increase over last year was due mainly to
the effects of weather that was 9 percent colder than average and 12 percent colder than a year ago. Utility margin in 2011 decreased 1 percent, or $3.2 million, due primarily to the repeal of the tax legislation mentioned above, offset in part by
colder weather and customer growth.
Sales to residential and commercial customers in 2011 were 685 million therms, compared to
599 million therms in 2010. The 14 percent increase in consumption was due to colder weather and customer growth. Including the effects of the company’s Oregon rate mechanisms for weather and conservation, residential and commercial margin
was $315.7 million in 2011, compared to $304.4 million in 2010.
NW Natural’s weather normalization mechanism in Oregon adjusted margin
down by $13.1 million in 2011, based on weather that was 9 percent colder than average. This compared to a margin adjustment increase of $14 million in 2010, based on weather that was 2 percent warmer than average. The conservation/decoupling
mechanism in Oregon adjusted margin up by $19.3 million in 2011, compared to a margin adjustment increase of $15.5 million in 2010.
Gas
deliveries to industrial customers in 2011 were 468 million therms compared to 463 million in 2010, with margin increasing $0.2 million in 2011, or 1 percent.
Under the company’s regulatory incentive sharing mechanism in Oregon, lower gas costs contributed $2.1 million to margin in 2011, compared to $1.6 million in 2010. In addition, Oregon’s gas
utilities are subject to an annual earnings review to determine if the utility is earning above its allowed return on equity (ROE). In NW Natural’s case, if utility earnings exceed the allowed ROE threshold from the last rate case, the company
is required to defer 33 percent of the amount above that level for refund to customers. We are refunding $0.2 million to customers related to the 2010 earnings test. For 2011, the company has estimated $1.5 million for refund to customers.
Wyoming gas reserves update
In May 2011, NW Natural entered into an agreement with Encana Oil & Gas (USA) Inc. to acquire gas reserves on behalf of NW Natural’s utility
customers. NW Natural’s utility is expected to invest approximately $45-55 million a year over a five-year period, for a total investment of about $250 million. The investment will cover a portion of the expected drilling costs in exchange
for working interests in multiple sections of the Jonah Field in Wyoming. The drilling area includes both future and currently producing wells. Encana began drilling in May 2011, and the company is currently receiving gas from its interests in the
gas field. NW Natural’s investment in gas reserves was $51.9 million as of Dec. 31, 2011.
Gas storage results
NW Natural’s gas storage segment includes two underground natural gas storage facilities: the Mist gas storage facilities in Oregon, and the Gill
Ranch gas storage facilities in California. The Mist facilities serve both core utility customers and the interstate market in the Pacific Northwest. The Gill Ranch facilities serve the California intrastate market. NW Natural contracts with an
independent energy marketing firm to optimize available capacity not committed to storage customers at Mist and Gill Ranch. NW Natural’s gas storage segment contributed approximately 15 cents per share to consolidated 2011 results on net income
of $4.1 million, compared to 23 cents per share on net income of $6.1 million in 2010. The decline in gas storage results from 2010 to 2011 was mainly due to lower gas storage pricing, which negatively impacted fixed contract storage prices as well
as optimization revenues at both the Mist and Gill Ranch facilities. Net income from the company’s gas storage operations at Mist were $2.3 million lower than last year.
2
Gill Ranch’s assets include depleted natural gas reservoirs, injection and withdrawal wells, a
compressor station, gathering lines, an electric substation, a 27-mile pipeline, and other equipment. Gill Ranch expects to be operating at or near its full designed working gas capacity of 15 billion cubic feet (Bcf) by the end of 2012, a year
earlier than anticipated. The facility also has future expansion capability at Gill Ranch that may be pursued when warranted by market conditions.
Company continues to rank among the best gas utilities for customer satisfaction
For the
eighth consecutive year, NW Natural ranked among the top utilities for customer satisfaction, earning one of the highest overall scores in the U.S. among large utilities according to the J.D. Power and Associates Gas Utility Residential study. The
company also received the second highest score in the nation for satisfaction among commercial customers in a separate J.D. Power survey.
Customer growth
NW Natural’s
customer growth for the trailing 12-month period ending Dec. 31, 2011 was 0.8 percent, with the company serving approximately 680,000 customers, compared to a customer growth rate of 0.9 percent at Dec. 31, 2010. The company added about 5,500
customers in 2011, compared to 6,200 customers in 2010.
Regulatory adjustment for taxes paid
In the second quarter of 2011, the Governor of Oregon signed Senate Bill 967 (SB 967) into law to repeal existing statutes from Senate Bill 408 (SB 408),
which became law in 2005. SB 967 eliminated the adjustment for income taxes paid retroactive to the beginning of 2010. As a result, NW Natural recorded a one-time charge of $7.4 million in the second quarter of 2011 ($4.4 million after tax or 17
cents per share). The current law, SB 967, now requires the Public Utility Commission of Oregon (OPUC) to make decisions in general ratemaking proceedings on the amount of income taxes to be recovered in rates.
Operations and maintenance expense
Operations and maintenance expenses for the 12 months ended Dec. 31, 2011 were $125.3 million, compared to $121.0 million in 2010, for a 4 percent
increase. The primary reason for the increase was the first full-year operating costs at Gill Ranch Storage. Excluding Gill Ranch, utility operations and maintenance expenses increased $1.5 million, or 1 percent, from a year ago. Bad debt expense as
a percent of revenues remained well below 1 percent at 0.23 percent for the 12 months ended Dec. 31, 2011.
Income tax expense
Income taxes decreased $6.1 million in the 12 months ended Dec. 31, 2011 compared to 2010, primarily due to lower pre-tax income.
Cash flows and capital structure for 2011
Cash provided by operations in 2011 was $233.5 million, compared to $126.5 million in 2010. The increase was mainly due to gas cost savings, income tax benefits from bonus depreciation and insurance
recoveries related to environmental clean-up costs. Cash requirements for investing activities in 2011 totaled $153.1 million, compared to $212.9 million in 2010, with most of the decrease related to development costs at Gill Ranch in 2010. After
capital expenditures and dividends, the company generated $33.7 million of free cash flow in 2011.
Free cash flow note: Free cash flow is
not a Generally Accepted Accounting Principle (GAAP) financial measure, but we believe this supplemental information enables the reader to better understand our cash generating ability and to benefit from seeing cash flow results from
management’s perspective in addition to the traditional GAAP presentation. Provided below is reconciliation from cash provided by operating activities (GAAP basis) to our non-GAAP free cash flow noted above.
3
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| Thousands |
|
2011 |
|
|
2010 |
|
|
2009 |
|
| Cash provided by operating activities |
|
$ |
233,462 |
|
|
$ |
126,469 |
|
|
$ |
240,335 |
|
| Cash used in investing activities |
|
|
(153,065 |
) |
|
|
(212,871 |
) |
|
|
(162,141 |
) |
| Cash dividend payments on common stock |
|
|
(46,690 |
) |
|
|
(44,652 |
) |
|
|
(42,415 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
| Free cash flow |
|
$ |
33,707 |
|
|
$ |
(131,054 |
) |
|
$ |
35,779 |
|
|
|
|
|
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|
NW Natural’s consolidated capitalization at Dec. 31, 2011 reflected 46.5 percent common equity, 41.7 percent
long-term debt, and 11.8 percent short-term debt and current maturities of long-term debt. This compared to 44.7 percent common equity, 38.1 percent long-term debt, and 17.2 percent short-term debt and current maturities of long-term debt last year.
The company’s debt credit ratings are a factor in our liquidity, affecting our access to the capital markets and our cost of capital. NW Natural’s debt ratings from Standard & Poor’s are A-1 for short-term debt and A+ for
secured long-term debt, and from Moody Investment Services they are P-1 for short-term debt and A1 for secured long-term debt.
Fourth
quarter financial and operating highlights
Net income and earnings per share
In the three-month period ending Dec. 31, 2011, net income decreased 1 percent to $1.09 per share on net income of $29.2 million, compared to $1.11 per
share on net income of $29.6 million last year. The quarterly decrease was mainly due to higher fourth quarter utility O&M expenses due to utility expenses driven by added staffing and other non-labor cost increases. Weather for the quarter was
4 percent colder than average and 7 percent colder than last year.
Utility operations contributed net income of $28.8 million or $1.08 per
share, compared to $29.9 million ($1.12 per share) in the fourth quarter of 2010. Gas storage operations contributed net income of $0.9 million or 3 cents per share in the period, compared to a net loss of $0.3 million (1 cent per share) in 2010.
The increase in net income from gas storage operations was primarily due to higher revenues than a year ago because of storage contracts that went into effect earlier in 2011.
Operational results
NW Natural’s total gas sales and transportation deliveries in the
fourth quarter of 2011, excluding deliveries of gas stored for others, were 350 million therms, up 5 percent from 333 million therms delivered in 2010, due mainly to weather that was 7 percent colder than last year. Sales to residential
and commercial customers in the quarter were 226 million therms, compared to 210 million therms in the fourth quarter of 2010.
Total margin from utility operations was approximately $113 million in the quarter, compared to $112 million last year, with the increase mainly
resulting from colder weather and customer growth, partially offset by the regulatory adjustment for income taxes. NW Natural’s weather normalization mechanism in Oregon adjusted margin down by $2.5 million in the fourth quarter of 2011, based
on weather that was 4 percent colder than average. This compared to a margin adjustment increase of $2.4 million in the fourth quarter of 2010, based on weather that was 2 percent warmer than average. In addition, the decoupling mechanism in Oregon
adjusted margin up by $8.5 million in 2011, compared to a margin adjustment increase of $7.5 million in 2010.
Operations and maintenance
expense
O&M expenses for the quarter were 1 percent higher than in 2010, primarily due a 5 percent increase in utility expense as a
result of new field support personnel added in the fourth quarter and rate case expense, which was partially offset by a $1.1 million decrease at Gill Ranch in O&M expenses in 2011 due to the start-up costs in the fourth quarter of 2010.
4
Pension deferral
Effective Jan. 1, 2011, the OPUC authorized the use of a pension balancing account to allow for the deferral of differences between the annual pension costs included and recovered in customer rates from
the company’s last general rate case and the amount of actual pension expense each year. The regulatory deferral account will earn a carrying cost at the authorized cost of capital rate set by the OPUC in the company’s last general rate
case. The impact to utility O&M expense for 2011 was approximately $6 million.
General rate case filed
In late December, NW Natural filed a general rate case in Oregon with the OPUC, the first such case filed by the company since 2002. If approved as filed,
the request would result in an overall revenue increase of 6.2 percent, or $43.7 million. The request addresses higher costs associated with maintaining and operating the company’s pipeline system and serving customers, as well as employee
pension and other benefit costs. Results of the request would not affect customer bills this winter heating season, and are expected to become effective Nov. 1, 2012.
Separate from the revenue increase request, the company is also proposing a mechanism to address expenses related to clean-up of legacy manufactured gas plant operations. The proposal would collect in
rates the total costs minus insurance recoveries over a multi-year period to lessen the impact on customers. This mechanism could result in an additional 1 to 3 percent rate increase, depending upon insurance recovery collections and clean-up
project costs that occur between now and September 30, 2012.
Guidance established for 2012
NW Natural today initiated 2012 earnings guidance to be in the range of $2.35 to $2.55 per share. The company’s 2012 earnings guidance assumes a
continued weak economic recovery and customer growth, normal weather conditions, ongoing benefits from improvements to our cost structure, and no significant changes in prevailing legislative and regulatory policies or outcomes. The company
continues to target a long-term dividend payout ratio of 60 to 70 percent of earnings.
Dividend declaration
The board of directors of NW Natural declared a quarterly dividend of 44.5 cents a share on the company’s common stock. These dividends were paid
Feb. 15, 2012 to shareholders of record on Jan. 31, 2012. The company’s indicated annual dividend rate is $1.78 per share.
Presentation of results
In addition to
presenting results of operations and earnings amounts in total, NW Natural has expressed certain measures in this press release on an equivalent cents per share basis. These amounts reflect factors that directly impact the company’s earnings.
In calculating these financial measures, we allocate income tax expense based on the effective tax rate. NW Natural believes this per share information is useful because it enables readers to better understand the impact of these factors on its
earnings.
Conference call arrangements
As previously reported, NW Natural will conduct a conference call and web cast starting at 8 a.m. Pacific Time (11 a.m. Eastern Time) on Feb. 28, 2012 to review the company’s financial and operating
results for the three- and 12-months ended Dec. 31, 2011.
To hear the conference call live, dial 1-877-317-6789 within the United States and
1-866-605-3852 from Canada. International callers can dial 1-412-317-6789. To access the conference replay, please call 1-877-344-7529 and enter the conference identification pass code (10008888). To hear the replay from international locations,
please dial 1-412-317-0088. To hear the conference by webcast, log on to NW Natural’s corporate website at www.nwnatural.com.
5
Forward-looking statements
This report, and other presentations made by NW Natural from time to time, may contain forward-looking statements within the meaning of the U.S. Private Securities Litigation Reform Act of 1995.
Forward-looking statements can be identified by words such as “anticipates,” “intends,” “plans,” “seeks,” “believes,” “estimates,” “expects” and similar references to future
periods. Examples of forward-looking statements include, but are not limited to, statements regarding the following: plans, objectives, goals, strategies, future events, investments, estimated gas reserves and their financial value and benefit,
customer growth, refunds to customers, weather, commodity costs, customer rates, effects of financial derivatives, financial positions, revenues and earnings, dividends, performance, legislative actions and impact, rate case outcomes, regulatory
actions or approvals, and other statements that are other than statements of historical facts.
Forward-looking statements are based on our
current expectations and assumptions regarding our business, the economy and other future conditions. Because forward-looking statements relate to the future, they are subject to inherent uncertainties, risks and changes in circumstances that are
difficult to predict. Our actual results may differ materially from those contemplated by the forward-looking statements. We caution you therefore against relying on any of these forward-looking statements. They are neither statements of historical
fact nor guarantees or assurances of future performance. Important factors that could cause actual results to differ materially from those in the forward-looking statements are discussed by reference to the factors described in Part I, Item 1A
“Risk Factors”, and Part II, Item 7 and Item 7A “Management’s Discussion and Analysis of Financial Condition and Results of Operations”, and “Quantitative and Qualitative Disclosure about Market Risk” in
the company’s most recent Annual Report on Form 10-K, and in Part I, Items 2 and 3 “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and “Quantitative and Qualitative Disclosures About
Market Risk”, and Part II, Item 1A, “Risk Factors”, in the company’s quarterly reports filed thereafter.
All
forward-looking statements made in this report and all subsequent forward-looking statements, whether written or oral and whether made by or on behalf of the company, are expressly qualified by these cautionary statements. Any forward-looking
statement speaks only as of the date on which such statement is made, and we undertake no obligation to publicly update any forward-looking statement, whether as a result of new information, future developments or otherwise, except as may be
required by law. New factors emerge from time to time and it is not possible for the company to predict all such factors, nor can it assess the impact of each such factor or the extent to which any factor, or combination of factors, may cause
results to differ materially from those contained in any forward-looking statements.
About NW Natural
NW Natural (NYSE:NWN) is headquartered in Portland, Ore., and provides safe, reliable, cost-effective natural gas service to approximately 680,000
residential, commercial, and industrial customers through approximately 14,000 miles of mains and service lines in western Oregon and southwestern Washington. It is the largest independent natural gas utility in the Pacific Northwest. The company
has approximately $2.7 billion in total assets. The company operates and owns 16 Bcf of underground storage capacity in Mist, Ore., and also operates the designed 20 Bcf Gill Ranch underground storage facility in California, in which it owns a 75
percent undivided interest. Together, NW Natural and its subsidiaries currently own and operate underground gas storage facilities with designed storage capacity of approximately 31 Bcf in Oregon and California. Additional information is available
at www.nwnatural.com.
# # #
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| Investor Contact: |
|
Media Contact: |
| Bob Hess |
|
Kim Heiting |
| Phone: 503-220-2388 |
|
Phone: 503-220-2366 |
| Email: bob.hess@nwnatural.com |
|
Email: kah@nwnatural.com |
6
NORTHWEST NATURAL GAS COMPANY
Comparative Income Statement
(Consolidated - Unaudited)
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| |
|
Three Months Ended |
|
| (Thousands, except per share amounts) |
|
12/31/11 |
|
|
12/31/10 |
|
|
Change |
|
|
% Change |
|
| Gross Operating Revenues |
|
$ |
271,198 |
|
|
$ |
268,145 |
|
|
$ |
3,053 |
|
|
|
1 |
% |
| Net Income |
|
$ |
29,244 |
|
|
$ |
29,591 |
|
|
$ |
(347 |
) |
|
|
(1 |
%) |
| Diluted Average Shares of Common Stock Outstanding |
|
|
26,784 |
|
|
|
26,717 |
|
|
|
67 |
|
|
|
— |
|
| Basic Earnings Per Share of Common Stock |
|
$ |
1.09 |
|
|
$ |
1.11 |
|
|
$ |
(0.02 |
) |
|
|
(2 |
%) |
| Diluted Earnings Per Share of Common Stock |
|
$ |
1.09 |
|
|
$ |
1.11 |
|
|
$ |
(0.02 |
) |
|
|
(2 |
%) |
|
|
| |
|
Twelve Months Ended |
|
| (Thousands, except per share amounts) |
|
12/31/11 |
|
|
12/31/10 |
|
|
Change |
|
|
% Change |
|
| Gross Operating Revenues |
|
$ |
848,796 |
|
|
$ |
812,106 |
|
|
$ |
36,690 |
|
|
|
5 |
% |
| Net Income |
|
$ |
63,898 |
|
|
$ |
72,667 |
|
|
$ |
(8,769 |
) |
|
|
(12 |
%) |
| Diluted Average Shares of Common Stock Outstanding |
|
|
26,744 |
|
|
|
26,657 |
|
|
|
87 |
|
|
|
— |
|
| Basic Earnings Per Share of Common Stock |
|
$ |
2.39 |
|
|
$ |
2.73 |
|
|
$ |
(0.34 |
) |
|
|
(12 |
%) |
| Diluted Earnings Per Share of Common Stock |
|
$ |
2.39 |
|
|
$ |
2.73 |
|
|
$ |
(0.34 |
) |
|
|
(12 |
%) |
7
NORTHWEST NATURAL GAS COMPANY
Consolidated Balance Sheets (unaudited)
|
|
|
|
|
|
|
|
|
| Thousands |
|
December 31,
2011 |
|
|
December 31,
2010 |
|
| Assets: |
|
|
|
|
|
|
|
|
| Current assets: |
|
|
|
|
|
|
|
|
| Cash and cash equivalents |
|
$ |
5,833 |
|
|
$ |
3,457 |
|
| Restricted cash |
|
|
— |
|
|
|
924 |
|
| Accounts receivable |
|
|
77,449 |
|
|
|
67,969 |
|
| Accrued unbilled revenue |
|
|
61,925 |
|
|
|
64,803 |
|
| Allowance for uncollectible accounts |
|
|
(2,895 |
) |
|
|
(2,950 |
) |
| Regulatory assets |
|
|
94,673 |
|
|
|
52,714 |
|
| Derivative instruments |
|
|
2,853 |
|
|
|
2,245 |
|
| Inventories |
|
|
74,363 |
|
|
|
80,385 |
|
| Gas reserves |
|
|
4,463 |
|
|
|
— |
|
| Income taxes receivable |
|
|
7,045 |
|
|
|
41,066 |
|
| Other current assets |
|
|
22,980 |
|
|
|
19,652 |
|
|
|
|
|
|
|
|
|
|
| Total current assets |
|
|
348,689 |
|
|
|
330,265 |
|
|
|
|
|
|
|
|
|
|
| Non-current assets: |
|
|
|
|
|
|
|
|
| Property, plant and equipment |
|
|
2,661,102 |
|
|
|
2,576,402 |
|
| Less accumulated depreciation |
|
|
767,226 |
|
|
|
722,239 |
|
|
|
|
|
|
|
|
|
|
| Total property, plant and equipment - net |
|
|
1,893,876 |
|
|
|
1,854,163 |
|
| Gas reserves |
|
|
47,451 |
|
|
|
— |
|
| Regulatory assets |
|
|
371,392 |
|
|
|
348,897 |
|
| Derivative instruments |
|
|
— |
|
|
|
628 |
|
| Other investments |
|
|
68,263 |
|
|
|
69,094 |
|
| Restricted cash |
|
|
4,000 |
|
|
|
— |
|
| Other non-current assets |
|
|
12,903 |
|
|
|
13,569 |
|
|
|
|
|
|
|
|
|
|
| Total non-current assets |
|
|
2,397,885 |
|
|
|
2,286,351 |
|
|
|
|
|
|
|
|
|
|
| Total assets |
|
$ |
2,746,574 |
|
|
$ |
2,616,616 |
|
|
|
|
|
|
|
|
|
|
| Capitalization and liabilities: |
|
|
|
|
|
|
|
|
| Capitalization: |
|
|
|
|
|
|
|
|
| Common stock |
|
$ |
348,383 |
|
|
$ |
342,978 |
|
| Retained earnings |
|
|
373,905 |
|
|
|
356,727 |
|
| Accumulated other comprehensive income (loss) |
|
|
(7,800 |
) |
|
|
(6,604 |
) |
|
|
|
|
|
|
|
|
|
| Total common stock equity |
|
|
714,488 |
|
|
|
693,101 |
|
| Long-term debt |
|
|
641,700 |
|
|
|
591,700 |
|
|
|
|
|
|
|
|
|
|
| Total capitalization |
|
|
1,356,188 |
|
|
|
1,284,801 |
|
|
|
|
|
|
|
|
|
|
| Current liabilities: |
|
|
|
|
|
|
|
|
| Short-term debt |
|
|
141,600 |
|
|
|
257,435 |
|
| Current maturities of long-term debt |
|
|
40,000 |
|
|
|
10,000 |
|
| Accounts payable |
|
|
86,300 |
|
|
|
93,243 |
|
| Taxes accrued |
|
|
10,747 |
|
|
|
10,579 |
|
| Interest accrued |
|
|
5,857 |
|
|
|
5,182 |
|
| Regulatory liabilities |
|
|
31,046 |
|
|
|
17,828 |
|
| Derivative instruments |
|
|
57,317 |
|
|
|
38,437 |
|
| Other current liabilities |
|
|
41,597 |
|
|
|
35,457 |
|
|
|
|
|
|
|
|
|
|
| Total current liabilities |
|
|
414,464 |
|
|
|
468,161 |
|
|
|
|
|
|
|
|
|
|
| Deferred credits and other non-current liabilities: |
|
|
|
|
|
|
|
|
| Deferred tax liabilities |
|
|
413,209 |
|
|
|
373,409 |
|
| Regulatory liabilities |
|
|
278,382 |
|
|
|
258,031 |
|
| Pension and other postretirement benefit liabilities |
|
|
201,530 |
|
|
|
144,250 |
|
| Derivative instruments |
|
|
6,536 |
|
|
|
17,022 |
|
| Other non-current liabilities |
|
|
76,265 |
|
|
|
70,942 |
|
|
|
|
|
|
|
|
|
|
| Total deferred credits and other non-current liabilities |
|
|
975,922 |
|
|
|
863,654 |
|
|
|
|
|
|
|
|
|
|
| Total capitalization and liabilities |
|
$ |
2,746,574 |
|
|
$ |
2,616,616 |
|
|
|
|
|
|
|
|
|
|
8
NORTHWEST NATURAL GAS COMPANY
Consolidated Statements of Cash Flows (unaudited)
|
|
|
|
|
|
|
|
|
| Thousands (year ended December 31) |
|
2011 |
|
|
2010 |
|
| Operating activities: |
|
|
|
|
|
|
|
|
| Net income |
|
$ |
63,898 |
|
|
$ |
72,667 |
|
| Adjustments to reconcile net income to cash provided by operations: |
|
|
|
|
|
|
|
|
| Depreciation and amortization |
|
|
70,004 |
|
|
|
65,124 |
|
| Undistributed earnings from equity investments |
|
|
1,329 |
|
|
|
(588 |
) |
| Non-cash expenses related to qualified defined benefit pension plans |
|
|
7,191 |
|
|
|
8,009 |
|
| Contributions to qualified defined benefit pension plans |
|
|
(22,045 |
) |
|
|
(10,000 |
) |
| Deferred environmental expenditures, net of recoveries |
|
|
25,586 |
|
|
|
(7,826 |
) |
| Other |
|
|
(1,049 |
) |
|
|
(2,265 |
) |
| Changes in assets and liabilities: |
|
|
|
|
|
|
|
|
| Receivables |
|
|
(6,246 |
) |
|
|
15,830 |
|
| Inventories |
|
|
6,022 |
|
|
|
572 |
|
| Taxes accrued |
|
|
34,189 |
|
|
|
(51,524 |
) |
| Accounts payable |
|
|
148 |
|
|
|
(11,846 |
) |
| Interest accrued |
|
|
675 |
|
|
|
(253 |
) |
| Deferred gas costs |
|
|
8,565 |
|
|
|
(26,090 |
) |
| Deferred tax liabilities |
|
|
46,877 |
|
|
|
76,410 |
|
| Other - net |
|
|
(1,682 |
) |
|
|
(1,751 |
) |
|
|
|
|
|
|
|
|
|
| Cash provided by operating activities |
|
|
233,462 |
|
|
|
126,469 |
|
|
|
|
|
|
|
|
|
|
| Investing activities: |
|
|
|
|
|
|
|
|
| Capital expenditures |
|
|
(100,534 |
) |
|
|
(248,505 |
) |
| Utility gas reserves |
|
|
(50,597 |
) |
|
|
— |
|
| Restricted cash |
|
|
(3,076 |
) |
|
|
34,619 |
|
| Other |
|
|
1,142 |
|
|
|
1,015 |
|
|
|
|
|
|
|
|
|
|
| Cash used in investing activities |
|
|
(153,065 |
) |
|
|
(212,871 |
) |
|
|
|
|
|
|
|
|
|
| Financing activities: |
|
|
|
|
|
|
|
|
| Common stock issued - net |
|
|
3,040 |
|
|
|
4,598 |
|
| Long-term debt issued |
|
|
90,000 |
|
|
|
— |
|
| Long-term debt retired |
|
|
(10,000 |
) |
|
|
(35,000 |
) |
| Change in short-term debt |
|
|
(115,835 |
) |
|
|
155,435 |
|
| Cash dividend payments on common stock |
|
|
(46,690 |
) |
|
|
(44,652 |
) |
| Other |
|
|
1,464 |
|
|
|
1,046 |
|
|
|
|
|
|
|
|
|
|
| Cash provided by (used in) financing activities |
|
|
(78,021 |
) |
|
|
81,427 |
|
|
|
|
|
|
|
|
|
|
| Increase (decrease) in cash and cash equivalents |
|
|
2,376 |
|
|
|
(4,975 |
) |
| Cash and cash equivalents - beginning of period |
|
|
3,457 |
|
|
|
8,432 |
|
|
|
|
|
|
|
|
|
|
| Cash and cash equivalents - end of period |
|
$ |
5,833 |
|
|
$ |
3,457 |
|
|
|
|
|
|
|
|
|
|
| |
|
|
|
|
|
|
|
|
| Supplemental disclosure of cash flow information: |
|
|
|
|
|
|
|
|
| Interest paid |
|
$ |
41,413 |
|
|
$ |
41,037 |
|
| Income taxes paid |
|
$ |
1,756 |
|
|
$ |
22,600 |
|
9
NORTHWEST NATURAL GAS COMPANY
Financial Highlights
(Unaudited)
Fourth Quarter - 2011
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| |
|
3 Months Ended
December 31, |
|
|
|
|
|
12 Months Ended
December 31, |
|
|
|
|
| (Thousands, except per share amounts) |
|
2011 |
|
|
2010 |
|
|
Change |
|
|
2011 |
|
|
2010 |
|
|
Change |
|
| Gross Operating Revenues |
|
$ |
271,198 |
|
|
$ |
268,145 |
|
|
|
1 |
% |
|
$ |
848,796 |
|
|
$ |
812,106 |
|
|
|
5 |
% |
| Cost of Sales |
|
|
144,742 |
|
|
|
143,313 |
|
|
|
1 |
% |
|
|
458,622 |
|
|
|
424,534 |
|
|
|
8 |
% |
| Revenue Taxes |
|
|
6,546 |
|
|
|
6,581 |
|
|
|
(1 |
%) |
|
|
20,741 |
|
|
|
19,991 |
|
|
|
4 |
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| Net Operating Revenues |
|
|
119,910 |
|
|
|
118,251 |
|
|
|
1 |
% |
|
|
369,433 |
|
|
|
367,581 |
|
|
|
1 |
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| Operating Expenses: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| O&M |
|
|
35,385 |
|
|
|
34,995 |
|
|
|
1 |
% |
|
|
125,303 |
|
|
|
120,980 |
|
|
|
4 |
% |
| General Taxes |
|
|
6,943 |
|
|
|
6,421 |
|
|
|
8 |
% |
|
|
29,281 |
|
|
|
23,872 |
|
|
|
23 |
% |
| D&A |
|
|
17,700 |
|
|
|
17,194 |
|
|
|
3 |
% |
|
|
70,004 |
|
|
|
65,124 |
|
|
|
7 |
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| Total Operating Expenses |
|
|
60,028 |
|
|
|
58,610 |
|
|
|
2 |
% |
|
|
224,588 |
|
|
|
209,976 |
|
|
|
7 |
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| Income from Operations |
|
|
59,882 |
|
|
|
59,641 |
|
|
|
— |
|
|
|
144,845 |
|
|
|
157,605 |
|
|
|
(8 |
%) |
| Other Income and Expense - net |
|
|
406 |
|
|
|
1,133 |
|
|
|
(64 |
%) |
|
|
4,523 |
|
|
|
7,102 |
|
|
|
(36 |
%) |
| Interest Expense - net |
|
|
11,132 |
|
|
|
10,840 |
|
|
|
3 |
% |
|
|
42,088 |
|
|
|
42,578 |
|
|
|
(1 |
%) |
| Income Tax Expense |
|
|
19,912 |
|
|
|
20,343 |
|
|
|
(2 |
%) |
|
|
43,382 |
|
|
|
49,462 |
|
|
|
(12 |
%) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| Net Income |
|
$ |
29,244 |
|
|
$ |
29,591 |
|
|
|
(1 |
%) |
|
$ |
63,898 |
|
|
$ |
72,667 |
|
|
|
(12 |
%) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| Common Shares Outstanding: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| Average for Period - basic |
|
|
26,719 |
|
|
|
26,642 |
|
|
|
|
|
|
|
26,687 |
|
|
|
26,589 |
|
|
|
|
|
| Average for Period - diluted |
|
|
26,784 |
|
|
|
26,717 |
|
|
|
|
|
|
|
26,744 |
|
|
|
26,657 |
|
|
|
|
|
| End of Period |
|
|
26,756 |
|
|
|
26,668 |
|
|
|
|
|
|
|
26,756 |
|
|
|
26,668 |
|
|
|
|
|
| Earnings per Share: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| Basic |
|
$ |
1.09 |
|
|
$ |
1.11 |
|
|
|
(2 |
%) |
|
$ |
2.39 |
|
|
$ |
2.73 |
|
|
|
(12 |
%) |
| Diluted |
|
$ |
1.09 |
|
|
$ |
1.11 |
|
|
|
|
|
|
$ |
2.39 |
|
|
$ |
2.73 |
|
|
|
|
|
| Dividends Paid Per Share |
|
$ |
0.445 |
|
|
$ |
0.435 |
|
|
|
|
|
|
$ |
1.75 |
|
|
$ |
1.68 |
|
|
|
|
|
| Book Value Per Share - end of period |
|
$ |
26.70 |
|
|
$ |
25.99 |
|
|
|
|
|
|
$ |
26.70 |
|
|
$ |
25.99 |
|
|
|
|
|
| Market Closing Price - end of period |
|
$ |
47.93 |
|
|
$ |
46.47 |
|
|
|
|
|
|
$ |
47.93 |
|
|
$ |
46.47 |
|
|
|
|
|
| Balance Sheet Data - end of period: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| Total Assets |
|
$ |
2,746,574 |
|
|
$ |
2,616,616 |
|
|
|
|
|
|
$ |
2,746,574 |
|
|
$ |
2,616,616 |
|
|
|
|
|
| Common Stock Equity |
|
$ |
714,488 |
|
|
$ |
693,101 |
|
|
|
|
|
|
$ |
714,488 |
|
|
$ |
693,101 |
|
|
|
|
|
| Long-Term Debt |
|
$ |
681,700 |
|
|
$ |
601,700 |
|
|
|
|
|
|
$ |
681,700 |
|
|
$ |
601,700 |
|
|
|
|
|
| (including amounts due in one year) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| Operating Statistics: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| Total Customers - end of period |
|
|
679,543 |
|
|
|
673,997 |
|
|
|
0.8 |
% |
|
|
679,543 |
|
|
|
673,997 |
|
|
|
0.8 |
% |
| Gas Deliveries (therms) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| Res. & Comm. Customers |
|
|
225,673 |
|
|
|
210,021 |
|
|
|
|
|
|
|
684,814 |
|
|
|
598,878 |
|
|
|
|
|
| Industrial Firm |
|
|
10,388 |
|
|
|
10,228 |
|
|
|
|
|
|
|
37,344 |
|
|
|
37,085 |
|
|
|
|
|
| Industrial Interruptible |
|
|
15,735 |
|
|
|
16,015 |
|
|
|
|
|
|
|
59,308 |
|
|
|
58,387 |
|
|
|
|
|
| Transportation |
|
|
98,526 |
|
|
|
96,292 |
|
|
|
|
|
|
|
370,888 |
|
|
|
367,619 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| Total |
|
|
350,322 |
|
|
|
332,556 |
|
|
|
|
|
|
|
1,152,354 |
|
|
|
1,061,969 |
|
|
|
|
|
| Gas Revenues |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| Res. & Comm. Customers |
|
$ |
241,823 |
|
|
$ |
234,492 |
|
|
|
|
|
|
$ |
737,412 |
|
|
$ |
684,168 |
|
|
|
|
|
| Industrial Firm |
|
|
8,486 |
|
|
|
8,496 |
|
|
|
|
|
|
|
30,455 |
|
|
|
30,830 |
|
|
|
|
|
| Industrial Interruptible |
|
|
9,313 |
|
|
|
9,878 |
|
|
|
|
|
|
|
34,961 |
|
|
|
36,164 |
|
|
|
|
|
| Transportation |
|
|
3,880 |
|
|
|
3,751 |
|
|
|
|
|
|
|
15,419 |
|
|
|
13,833 |
|
|
|
|
|
| Regulatory adjustment for income taxes |
|
|
— |
|
|
|
2,747 |
|
|
|
|
|
|
|
(7,162 |
) |
|
|
7,721 |
|
|
|
|
|
| Other Revenues |
|
|
497 |
|
|
|
3,000 |
|
|
|
|
|
|
|
11,134 |
|
|
|
17,917 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| Total |
|
$ |
263,999 |
|
|
$ |
262,364 |
|
|
|
|
|
|
$ |
822,219 |
|
|
$ |
790,633 |
|
|
|
|
|
| Cost of Gas Sold - Utility |
|
$ |
144,727 |
|
|
$ |
143,305 |
|
|
|
|
|
|
$ |
458,508 |
|
|
$ |
424,494 |
|
|
|
|
|
| Revenue Taxes |
|
$ |
6,546 |
|
|
$ |
6,581 |
|
|
|
|
|
|
$ |
20,741 |
|
|
$ |
19,991 |
|
|
|
|
|
| Net Operating Revenues (Utility Margin) |
|
$ |
112,726 |
|
|
$ |
112,478 |
|
|
|
|
|
|
$ |
342,970 |
|
|
$ |
346,148 |
|
|
|
|
|
| Degree Days |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| Average (25-year average) |
|
|
1,614 |
|
|
|
1,614 |
|
|
|
|
|
|
|
4,265 |
|
|
|
4,265 |
|
|
|
|
|
| Actual |
|
|
1,684 |
|
|
|
1,577 |
|
|
|
|
|
|
|
4,652 |
|
|
|
4,171 |
|
|
|
|
|
| Colder (warmer) than Average |
|
|
4 |
% |
|
|
(2 |
%) |
|
|
|
|
|
|
9 |
% |
|
|
(2 |
%) |
|
|
|
|
10
