Market Overview

NW Natural Reports Second Quarter and Year-To-Date 2018 Results

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PORTLAND, Ore., Aug. 07, 2018 (GLOBE NEWSWIRE) -- Northwest Natural Gas Company, dba NW Natural (NYSE:NWN), reported financial results and highlights including:

  • Second quarter 2018 consolidated net loss of $0.03 per share, compared to net income of $0.10 per share for 2017
  • Year-to-date 2018 consolidated net income of $1.41 per share, compared to $1.50 per share for 2017
  • Results for the quarter and year-to-date period were affected by a variance from the timing of tax reform
  • Delivered strong natural gas utility results with 1.6% customer growth over the last 12 months
  • Continued constructing major elements of the North Mist gas storage expansion project
  • Reached agreement on key items in Oregon general rate case and filed an all-party settlement with the Commission
  • Advanced our regulated water strategy with plans to acquire two small utilities in Washington state
  • Signed an agreement to sell our interest in the Gill Ranch gas storage facility in California

"This was an important quarter marked by progress and achievements on several critical fronts. We continue to see economic growth in our service territory and a steady increase in our customer base, we came to an important all-party settlement in our Oregon rate case, and we made headway on our regulated water utility strategy," said David H. Anderson, president and chief executive officer of NW Natural. "All of these accomplishments and signing the agreement to sell Gill Ranch, underpin our focus on strong and stable returns from our regulated businesses."

Results for both the quarter and year-to-date periods were affected by a timing difference between the regulatory revenue deferral associated with tax reform and the tax expense benefit from the lower federal tax rate. On an annual basis we expect the deferral and tax benefit to largely offset; however, quarterly timing differences are expected throughout 2018. In the first quarter of 2018, the utility segment had a $4.3 million (or $0.15 per share) timing benefit related to the lower federal tax rate, of which $1.6 million (or $0.06 per share) reversed in the second quarter of 2018. The remaining $2.7 million (or $0.09 per share) benefit is expected to more than completely reverse in the third quarter of 2018 with an additional benefit in the fourth quarter of 2018 and little anticipated impact to annual utility results.

For the second quarter of 2018 consolidated net income decreased $3.7 million to a loss of $1.0 million (or $0.03 per share), compared to consolidated net income of $2.7 million (or $0.10 per share) for the same period in 2017. Results reflected lower utility margin largely as a consequence of the effects of the lower federal tax rate. Results were also affected by warmer than average weather in 2018 compared to cooler than average weather in 2017 and higher operations and maintenance costs, partially offset by customer growth.

Year-to-date 2018 consolidated net income decreased $2.5 million to $40.5 million (or $1.41 per share), compared to net income of $43.0 million (or $1.50 per share) for the same period in 2017. Results reflected lower utility margin from colder than average weather in 2017 partially offset by customer growth, higher operations and maintenance costs, and a benefit for the utility associated with the timing of the effects of the lower federal tax rate.

KEY INITIATIVES

Oregon Rate Case Settlement
In December 2017, NW Natural filed a request for a general rate increase (rate case) with the Public Utility Commission of Oregon (OPUC). In August 2018, NW Natural, OPUC Staff, Oregon Citizen's Utility Board, and the Alliance of Western Energy Customers, which comprise all of the parties to the rate case, filed a joint stipulation with the OPUC addressing all but three issues, discussed in more detail below, in the rate case (settlement). The settlement is subject to the review and approval of the OPUC.

The settlement provides for a $16 million increase over the Company's revenue from existing base rates. This increase includes approximately $12 million that would otherwise be recovered under the Company's conservation tariff deferral. The revenue requirement also reflects settlement of treatment of the impact of the 2017 federal tax reform on the Company's recoverable tax expenses included in rates for the period after the date the new rates take effect, which is expected to be Nov. 1, 2018. In the absence of the rate increases contemplated by the settlement, tax reform was expected to result in a rate reduction of approximately $11 million during the year following the effective date of the rates. Combined, the settlement would be expected to result in a net benefit to the Company of approximately $15 million in annual revenues. The revenue requirement is based upon the following agreements included in the settlement:

  • Capital structure of 50% debt and 50% equity;
  • Return on equity of 9.4%;
  • Cost of capital of 7.317%; and
  • Rate base of $1.192 billion, or an increase of $306 million since the last rate case in 2012.

The increase to revenue requirement is dependent upon the Company's completion of certain capital projects prior to the rate effective date, and the amounts could be adjusted downward in the event that these projects are not completed. The three issues not addressed in this settlement that the parties to the rate case expect to continue to litigate or continue to settle under a subsequent agreement are:

  • The impact of tax reform on the Company's accumulated deferred income tax and the Company's tax expense during the period prior to the date the new rates take effect, which is expected to be Nov. 1, 2018;
  • Matters relating to the future operation and timing of rate recovery of amounts reflected in the Company's pension balancing account; and
  • The sharing of revenues produced by the management of certain Company assets and interstate storage operations.

The OPUC's order regarding the rate case is expected to be issued by the end of October 2018, with new rates anticipated beginning Nov. 1, 2018.

"We're pleased to reach an all-party settlement on the majority of items in the Oregon rate case," said David H. Anderson. "This outcome reflects a collaborative process between parties and I believe it provides a foundation for the Company to continue operating safely and reliably and serve our growing customer base."

North Mist Expansion Project
We continue to target an in-service date during December 2018 for the North Mist expansion project. We began free-flow natural gas injections into the reservoir this past quarter and are currently assembling the compressor station in advance of compressed injections, which are expected to begin this fall. The estimated cost of the expansion is $132 million. The investment will be included in rate base under an established tariff when it is placed into service. The facility is under an initial 30-year contract with Portland General Electric with options to extend the contract totaling up to an additional 50 years upon mutual agreement.

The project is designed to provide long-term, no-notice underground gas storage service to support gas-fired electric generating facilities that are intended to facilitate the integration of wind power into the region's electric generation mix. Natural gas storage enables electric generation to adjust quickly when renewable energy, such as wind and solar, rises and falls. Our no-notice service is designed to allow the local electric company to draw on our North Mist facility to meet its fueling needs and rapidly respond to natural variability in wind generation.

Tax Reform
In December 2017, federal tax reform was enacted. Tax reform, among other things, lowered the federal corporate income tax rate to 21% from the previous maximum rate of 35%. Changes in deferred taxes within our regulated operations as a result of tax reform are recorded as adjustments to regulatory liability accounts. As of Dec. 31, 2017, we estimated the utility's regulatory liability for historical deferred taxes was $213.3 million. The majority of this liability will likely be returned to customers over an amortization period in compliance with Internal Revenue Service tax normalization rules.

Until customer rates can be reset, we will defer the estimated effect of tax reform on customer rates. In the second quarter and first six months of 2018 we deferred revenues and interest of $2.9 million and $9.4 million pre-tax (or $2.1 million and $6.9 million after-tax, respectively, based on a 26.5% statutory tax rate) into a regulatory liability to be returned to customers. We currently estimate the deferral for 2018 will be $8 to $12 million pre-tax. The revenue deferral is based primarily on the estimated benefit to customers for the year using forecasted utility earnings considering average weather and associated volumes. The deferral methodology, among other matters, is currently being determined through the open Oregon general rate case and the separate tax docket.

We continue working with the OPUC to determine the treatment of these historical and interim deferred taxes for periods prior to Nov. 1, 2018. We expect to address tax reform with the Washington Utilities and Transportation Commission (WUTC) in our next Washington general rate case.

The all-party settlement in the Oregon rate case incorporates the effect of tax reform on future rates beginning Nov. 1, 2018.

Gill Ranch Sale Agreement
During the second quarter of 2018, we moved forward with our long-term strategy, which includes a shift away from merchant gas storage operations. In June 2018 the Company entered into an agreement to sell its wholly-owned subsidiary Gill Ranch for an initial cash purchase price of $25 million, with an earn out provision and subject to a working capital adjustment. The agreement follows a comprehensive review process that concluded Gill Ranch was no longer core to NW Natural's strategy.

We own a 75% interest or about 15 Bcf in the Gill Ranch natural gas storage facility located near Fresno, California. Pacific Gas and Electric Company (PG&E) owns the remaining 25% interest in the facility.

We expect the transaction to close within 12 months of the signing and in 2019. The closing is subject to approval by the California Public Utilities Commission and other customary closing conditions.

As a result of our strategic shift away from merchant gas storage and the significance of Gill Ranch's financial results in 2017, we are presenting the Gill Ranch operations in discontinued operations in our financial statements and the discussion of results for the second quarter and first six months of 2018 below.

Additionally, we reevaluated our reportable segments given our strategic shift and concluded we will no longer present a gas storage segment. Our non-utility Mist gas storage operations are now reported in other activities along with results from our natural gas appliance retail center operations, costs associated with our regulated water strategy and formation of a holding company, as well as other non-utility business development activities and investments. All prior periods have been reclassified to reflect these changes.

Water Strategy
In May 2018, we entered into agreements to acquire two privately owned water utilities that combined serve about 1,100 customers in Washington state. The transactions are subject to certain conditions, including approval by the WUTC.

In July 2018, we received approval from the Idaho Public Utilities Commission for our acquisition of the Falls Water Company in Falls, Idaho that serves about 5,500 customers. We expect the transaction to close in the third quarter of 2018.

Since announcing our regulated water strategy in December 2017, we have entered into agreements to acquire four privately owned water utilities that combined serve nearly 7,600 customers. Although these initial acquisitions and their ongoing operations are not expected to have a material impact on our financial results, they mark NW Natural's continued commitment to building a regulated water utility platform and provide investors with a risk profile and regulated business model that is similar to our core gas utility.

SECOND QUARTER RESULTS

Segment Results
The following financial comparisons are between the second quarter of 2018 and the same period in 2017 with individual quarter-over-quarter drivers below presented on an after-tax basis using a statutory tax rate of 26.5% unless otherwise noted.

The second quarter results are summarized by business segment in the table below:

  Three Months Ended June 30,
  2018   2017   Change
In thousands, except per share data Amount Per Share   Amount Per Share   Amount Per Share
Net income (loss) from continuing operations:                
Utility segment $ (2,970 ) $ (0.10 )   $ 2,137   $ 0.07     $ (5,107 ) $ (0.17 )
Other 2,631   0.09     1,938   0.07     693   0.02  
Net income (loss) from continuing operations $ (339 ) $ (0.01 )   $ 4,075   $ 0.14     $ (4,414 ) $ (0.15 )
Loss from discontinued operations, net of tax (659 ) (0.02 )   (1,346 ) (0.04 )   687   0.02  
Consolidated net income (loss) $ (998 ) $ (0.03 )   $ 2,729   $ 0.10     $ (3,727 ) $ (0.13 )
Diluted Shares 28,791       28,717       74    
                       

Gas Utility
Gas utility net income decreased $5.1 million (or $0.17 per share). Utility margin decreased $3.5 million largely due to deferring $2.1 million of revenues associated with the decline in the federal tax rate. While customer growth of 1.6% over the last 12 months contributed $0.5 million to utility margin, this was more than offset by lower margins from customers not covered by a weather normalization mechanism primarily as a result of colder than average weather in 2017. Weather was 38 percent warmer than average for the second quarter of 2018, compared to 14 percent colder than average for the same period in 2017.

Operations and maintenance expense increased $1.8 million reflecting higher compensation and benefits expense. Depreciation and property tax expense increased $1.0 million as we continue to invest in our infrastructure for customer growth, safety, and facility upgrades. Tax expense decreased $0.5 million due to the lower federal income tax rate as a result of tax reform.

We estimate tax reform reduced utility net income by $1.6 million (or $0.06 per share) as a result of the $2.1 million revenue deferral more than offsetting the $0.5 million tax benefit.

Other
Other net income increased $0.7 million (or $0.02 per share) reflecting higher asset management revenues from our Mist gas storage facility, partially offset by higher costs from regulated water and holding company formation activities.

Discontinued Operations
The net loss from discontinued operations at Gill Ranch decreased $0.7 million (or $0.02 per share) primarily due to lower depreciation expense after an impairment of the facility was taken in December 2017 and depreciation ceased in June when a sale agreement was signed and Gill Ranch was moved to discontinued operations.

YEAR-TO-DATE RESULTS

Segment Results
The following financial comparisons are between the first six months of 2018 and the same period in 2017 with individual year-over-year drivers below presented on an after-tax basis using a statutory tax rate of 26.5% unless otherwise noted.

The year-to-date results are summarized by business segment in the table below:

  Six Months Ended June 30,
  2018   2017   Change
In thousands, except per share data Amount Per Share   Amount Per Share   Amount Per Share
Net income from continuing operations:                
Utility segment $ 36,913   $ 1.28     $ 42,329   $ 1.47     $ (5,416 ) $ (0.19 )
Other 4,759   0.17     3,143   0.11     1,616   0.06  
Net income from continuing operations $ 41,672   $ 1.45     $ 45,472   $ 1.58     $ (3,800 ) $ (0.13 )
Loss from discontinued operations, net of tax (1,133 ) (0.04 )   (2,433 ) (0.08 )   1,300   0.04  
Consolidated net income $ 40,539   $ 1.41     $ 43,039   $ 1.50     $ (2,500 ) $ (0.09 )
Diluted Shares 28,825       28,722       103    
                       

Gas Utility
Gas utility net income decreased $5.4 million (or $0.19 per share). Utility margin decreased $10.4 million largely due to deferring $6.8 million of revenues associated with the decline in the federal tax rate. While customer growth of 1.6% over the last 12 months contributed $1.7 million to utility margin, this was more than offset by lower margins from customers not covered by a weather normalization mechanism as weather was colder than average in 2017. Weather was 11 percent warmer than average for the first six months of 2018, compared to 24 percent colder than average for the same period in 2017.

Operations and maintenance expense increased $2.7 million reflecting higher compensation and benefits expense and professional service costs. Depreciation and property tax expense increased $2.3 million as we continue to invest in our infrastructure for customer growth, safety, and facility upgrades. Tax expense decreased $9.5 million due to the lower federal income tax rate as a result of tax reform.

We estimate tax reform increased utility net income by $2.7 million (or $0.09 per share) as a result of the $9.5 million tax expense benefit more than offsetting the $6.8 million revenue deferral. We expect this $2.7 million benefit to more than completely reverse in the third quarter of 2018 with an additional benefit in the fourth quarter and little anticipated impact to annual results.

Other
Other net income increased $1.6 million (or $0.06 per share) reflecting higher asset management revenues from our Mist gas storage facility, partially offset by higher costs from regulated water and holding company formation activities.

Discontinued Operations
The net loss from discontinued operations at Gill Ranch decreased $1.3 million (or $0.04 per share) primarily to lower depreciation expense after an impairment of the facility was taken in December 2017 and depreciation ceased in June when a sale agreement was signed and Gill Ranch was moved to discontinued operations.

CASH FLOWS
During the first six months of 2018, we generated $162.7 million in operating cash flow and invested $102.4 million in capital expenditures to support growth, safety, and our North Mist Expansion Project. Cash provided by operations decreased $31.6 million due to changes in working capital and deferred gas costs as well as higher taxes paid. Cash outflow from investing activities increased $7.7 million primarily due to higher capital expenditures, and cash outflow from financing activities decreased $27.3 million primarily due to lower debt repayments.

2018 EARNINGS GUIDANCE REAFFIRMED
The Company reaffirmed 2018 guidance today in the range of $2.10 to $2.30 per share. This guidance assumes continued customer growth from our utility segment, average weather conditions, and no significant changes in prevailing regulatory policies, mechanisms, or outcomes, or significant laws or regulations.

We continue to expect capital expenditures for 2018 to be in the range of $190 to $220 million to support core gas utility customer growth and safety and reliability, as well as the completion of the North Mist Expansion Project. We expect to finance our capital needs in 2018 using a combination of cash flow from operations and debt. Our total capital investment plan for the five-year period from 2018 to 2022 is approximately $750 to $850 million, with a majority supporting continued customer growth, distribution system maintenance and improvements, technology investments, and utility gas storage facility maintenance.

DIVIDEND DECLARED

In July 2018, NW Natural's Board of Directors declared a quarterly dividend of 47.25 cents per share on the Company's common stock. The dividend will be payable on Aug. 15, 2018 to shareholders of record on July 31, 2018, reflecting an annual indicated dividend rate of $1.89 per share.

CONFERENCE CALL AND WEBCAST
As previously reported, NW Natural will host a conference call and webcast today to discuss its second quarter and year-to-date 2018 financial and operating results.

Date and Time: Tuesday, August 7
8 a.m. PT (11 a.m. ET)
Phone Numbers: United States:  1-866-267-6789
Canada:  1-855-669-9657
International:  1-412-902-4110

The call will also be webcast in a listen-only format for the media and general public and can be accessed at nwnatural.com under the Investor Relations tab. A replay of the conference call will be available on our website and by dialing 1-877-344-7529 (U.S.), 1-855-669-9658 (Canada), and 1-412-317-0088 (international). The replay access code is 10121789.

ABOUT NW NATURAL

NW Natural (NYSE:NWN) is a 159-year-old regulated natural gas utility company serving Oregon and southwest Washington with one of the most modern pipeline systems in the nation. It is the largest stand-alone local gas distributor in the Pacific Northwest with more than 740,000 customers, 14,000 miles of pipeline, and $3 billion in assets. NW Natural consistently leads the industry with high J.D. Power & Associates customer satisfaction scores in the West and the nation. The Company also owns and operates 16 Bcf of underground gas storage capacity primarily for utility customers and is currently constructing a 2.5 Bcf regulated gas storage expansion to support renewables. NW Natural is expanding into the regulated water utility business with four pending acquisitions of privately owned companies. Additional information is available at nwnatural.com.

Investor Contact:
Nikki Sparley
Phone: 503-721-2530
Email: n1s@nwnatural.com

Media Contact:
Melissa Moore
Phone: 503-220-2436
Email: msm@nwnatural.com

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," "assumes," "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, risks, capital expenditures and allocations, stability, acquisitions and integration thereof, dispositions and outcome thereof, customer growth, weather, commodity and other costs, customer rates or rate recovery, customer preference, growth, adoption of renewable energy and our ability to provide effective supporting resources, infrastructure availability and development, our water utility strategy, financing plans, environmental remediation cost recoveries, levels and pricing of gas storage contracts, gas storage development or costs or timing related thereto, financial positions, revenues, liquidity, returns, and earnings and the timing thereof, earnings guidance, dividends, performance, timing or effects of future regulatory proceedings or future regulatory approvals, regulatory prudence reviews, effects of regulatory mechanisms, expectations and treatment with respect to the rate case, pension balancing account, interstate storage or treatment of federal tax reform, anticipated regulatory actions or filings, effects of changes in laws or regulations, including federal tax reform, 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 operational, economic or financial 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.

Presentation of Non-GAAP Results
In addition to presenting the results of operations and earnings amounts in total, certain financial measures are expressed in cents per share, which are non-GAAP financial measures. Financial measures are expressed in cents per share as these amounts reflect factors that directly impact earnings, including income taxes. All references to EPS herein are on the basis of diluted shares.

We use such non-GAAP financial measures to analyze our financial performance because we believe they provide useful information to our investors and creditors in evaluating our financial condition and results of operations.


NORTHWEST NATURAL
Consolidated Income Statement and Financial Highlights (Unaudited)
Second Quarter 2018
    Three Months Ended   Six Months Ended   Twelve Months Ended  
In thousands, except per share amounts, customer, and degree day data June 30,   June 30,   June 30,  
2018   2017 Change 2018   2017 Change 2018   2017 Change
Operating revenues $ 124,567     $ 134,476   (7 )% $ 388,202     $ 430,200   (10 )% $ 713,039     $ 747,363   (5 )%
                         
Operating expenses:                  
  Cost of gas 42,053     53,005   (21 ) 150,159     196,616   (24 ) 278,338     327,923   (15 )
  Operations and maintenance 38,028     34,997   9   77,551     72,443   7   157,465     139,521   13  
  Environmental remediation 1,882     2,611   (28 ) 6,506     9,565   (32 ) 12,232     15,941   (23 )
  General taxes 7,729     7,204   7   17,203     15,883   8   31,959     29,606   8  
  Revenue taxes 4,780       NM 17,209       NM 17,209       NM
  Depreciation and amortization 21,147     20,224   5   42,022     40,177   5   82,898     79,402   4  
  Other operating expenses 679       NM 1,532       NM 1,532       NM
  Total operating expenses 116,298     118,041   (1 ) 312,182     334,684   (7 ) 581,633     592,393   (2 )
Income from operations 8,269     16,435   (50 ) 76,020     95,516   (20 ) 131,406     154,970   (15 )
Other income (expense), net 7     (340 ) (102 ) (827 )   (763 ) 8   (359 )   (3,747 ) (90 )
Interest expense, net 8,771     9,473   (7 ) 18,045     19,103   (6 ) 36,468     38,283   (5 )
Income (loss) before income taxes (495 )   6,622   (107 ) 57,148     75,650   (24 ) 94,579     112,940   (16 )
Income tax expense (benefit) (156 )   2,547   (106 ) 15,476     30,178   (49 ) 26,306     45,352   (42 )
Net income (loss) from continuing operations (339 )   4,075   (108 ) 41,672     45,472   (8 ) 68,273     67,588   1  
Loss from discontinued operations, net of tax (659 )   (1,346 ) (51 ) (1,133 )   (2,433 ) (53 ) (126,396 )   (4,314 ) 2,830  
Net income (loss) $ (998 )   $ 2,729   (137 ) $ 40,539     $ 43,039   (6 ) $ (58,123 )   $ 63,274   (192 )
                         
Common shares outstanding:                        
  Average diluted for period 28,791     28,717     28,825     28,722     28,734     28,322    
  End of period 28,800     28,662     28,800     28,662     28,800     28,662    
                           
Per share information:                        
Diluted earnings (loss) per share from continuing operations $ (0.01 )   $ 0.14     $ 1.45     $ 1.58     $ 2.38     $ 2.39    
Diluted loss per share from discontinued operations, net of tax (0.02 )   (0.04 )   (0.04 )   (0.08 )   (4.40 )   (0.16 )  
Diluted earnings (loss) per share (0.03 )   0.10     1.41     1.50     (2.02 )   2.23    
Dividends declared per share of common stock 0.4725     0.4700     0.9450     0.9400     1.8875     1.8775    
Book value per share, end of period 26.37     30.19     26.37     30.19     26.37     30.19    
Market closing price, end of period 63.80     59.85     63.80     59.85     63.80     59.85    
                         
Capital structure, end of period:                        
  Common stock equity 48.5 %   54.6 %   48.5 %   54.6 %   48.5 %   54.6 %  
  Long-term debt 43.7     41.5     43.7     41.5     43.7     41.5    
  Short-term debt (including amounts due in one year) 7.8     3.9     7.8     3.9     7.8     3.9    
  Total 100.0 %   100.0 %   100.0 %   100.0 %   100.0 %   100.0 %  
                           
Utility segment operating statistics:                        
Customers - end of period 742,667     730,968   1.6 % 742,667     730,968   1.6 % 742,667     730,968   1.6 %
Utility volumes - therms:                        
  Residential and commercial sales 103,637     113,869     381,656     441,392     680,633     725,115    
  Industrial sales and transportation 113,756     120,774     242,690     260,890     481,724     496,681    
Total utility volumes sold and delivered 217,393     234,643     624,346     702,282     1,162,357     1,221,796    
Utility operating revenues:                        
  Residential and commercial sales $ 106,526     $ 117,296     $ 352,110     $ 397,573     $ 638,751     $ 681,782    
  Industrial sales and transportation 13,403     14,791     30,792     33,694     61,023     64,444    
  Other revenues (1,414 )   1,168     (6,454 )   2,543     (5,125 )   3,842    
  Less: Revenue taxes     3,160         10,989     8,080     19,009    
Total utility operating revenues 118,515     130,095     376,448     422,821     686,569     731,059    
  Less: Cost of gas 42,107     53,005     150,271     196,616     278,674     327,922    
  Environmental remediation expense 1,882     2,611     6,506     9,565     12,232     15,941    
  Revenue taxes 4,780         17,209         17,209        
Utility margin, net $ 69,746     $ 74,479     $ 202,462     $ 216,640     $ 378,454     $ 387,196    
Degree days:                        
  Average (25-year average) 311     311     1,627     1,627     2,705     2,705    
  Actual 193     356   (46 )% 1,449     2,023   (28 )% 2,540     2,967   (14 )%
Percent (warmer) colder than average weather (38 )%   14 %   (11 )%   24 %   (6 )%   10 %  
                           
  NM = Not Meaningful calculation                        
                           


NORTHWEST NATURAL        
Consolidated Balance Sheets (Unaudited)   June 30,
In thousands   2018   2017
Assets:        
Current assets:        
  Cash and cash equivalents   $ 8,755     $ 20,854  
  Accounts receivable   31,512     30,778  
  Accrued unbilled revenue   13,995     13,896  
  Allowance for uncollectible accounts   (657 )   (845 )
  Regulatory assets   41,092     37,504  
  Derivative instruments   2,044     1,530  
  Inventories   43,109     57,264  
  Gas reserves   16,579     16,072  
  Other current assets   11,672     13,028  
  Discontinued operations current assets   12,743     1,923  
    Total current assets   180,844     192,004  
Non-current assets:        
  Property, plant, and equipment   3,298,856     3,098,112  
  Less: Accumulated depreciation   984,998     942,558  
    Total property, plant, and equipment, net   2,313,858     2,155,554  
  Gas reserves   75,362     92,020  
  Regulatory assets   339,177     348,284  
  Derivative instruments   1,077     162  
  Other investments   64,854     68,885  
  Other non-current assets   11,588     3,164  
  Discontinued operations non-current assets       205,081  
    Total non-current assets   2,805,916     2,873,150  
    Total assets   $ 2,986,760     $ 3,065,154  
Liabilities and equity:        
Current liabilities:        
  Short-term debt   $ 47,100     $  
  Current maturities of long-term debt   74,785     61,991  
  Accounts payable   70,551     95,126  
  Taxes accrued   6,916     6,906  
  Interest accrued   6,652     5,966  
  Regulatory liabilities   34,275     28,041  
  Derivative instruments   11,744     4,734  
  Other current liabilities   32,935     31,015  
  Discontinued operations current liablities   12,922     1,303  
    Total current liabilities   297,880     235,082  
Long-term debt   683,895     658,118  
Deferred credits and other non-current liabilities:        
  Deferred tax liabilities   281,028     577,176  
  Regulatory liabilities   602,294     359,205  
  Pension and other postretirement benefit liabilities   218,061     219,718  
  Derivative instruments   3,913     3,466  
  Other non-current liabilities   140,163     134,793  
  Discontinued operations non-current liabilities       12,167  
    Total deferred credits and other non-current liabilities   1,245,459     1,306,525  
Equity:        
  Common stock   452,195     444,058  
  Retained earnings   315,462     428,049  
  Accumulated other comprehensive loss   (8,131 )   (6,678 )
    Total equity   759,526     865,429  
    Total liabilities and equity   $ 2,986,760     $ 3,065,154  


         
NORTHWEST NATURAL        
Consolidated Statements of Cash Flows (Unaudited)   Six Months Ended June 30,
In thousands   2018   2017
Operating activities:        
  Net income   $ 40,539     $ 43,039  
  Adjustments to reconcile net income to cash provided by operations:        
    Depreciation and amortization   42,022     40,177  
    Regulatory amortization of gas reserves   7,816     8,031  
    Deferred income taxes   11,227     22,170  
    Qualified defined benefit pension plan expense   2,876     2,615  
    Contributions to qualified defined benefit pension plans   (5,570 )   (7,250 )
    Deferred environmental expenditures, net   (7,330 )   (6,817 )
    Amortization of environmental remediation   6,506     9,565  
    Regulatory revenue deferral from Tax Cuts and Jobs Act   9,212      
    Other   810     1,128  
    Changes in assets and liabilities:        
      Receivables, net   79,332     85,250  
      Inventories   4,803     (3,501 )
      Income taxes   (11,967 )   (5,243 )
      Accounts payable   (26,613 )   (21,849 )
      Interest accrued   (121 )    
      Deferred gas costs   4,787     15,325  
      Other, net   3,623     8,243  
    Discontinued operations   700     3,348  
    Cash provided by operating activities   162,652     194,231  
Investing activities:        
  Capital expenditures   (102,370 )   (94,333 )
  Other   195     (404 )
  Discontinued operations   (283 )   15  
    Cash used in investing activities   (102,458 )   (94,722 )
Financing activities:        
  Repurchases related to stock-based compensation       (2,034 )
  Proceeds from stock options exercised   45     1,309  
  Long-term debt retired   (22,000 )    
  Change in short-term debt   (7,100 )   (53,300 )
  Cash dividend payments on common stock   (25,577 )   (26,919 )
  Other   (279 )   (1,232 )
    Cash used in financing activities   (54,911 )   (82,176 )
Increase in cash and cash equivalents   5,283     17,333  
Cash and cash equivalents, beginning of period   3,472     3,521  
Cash and cash equivalents, end of period   $ 8,755     $ 20,854  
               
Supplemental disclosure of cash flow information:        
  Interest paid, net of capitalization   $ 17,117     $ 18,011  
  Income taxes paid   13,347     9,081  
               

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