ONEOK Announces 11% Increase in Second-quarter 2019 Net Income
TULSA, Okla., July 30, 2019 /PRNewswire/ -- ONEOK, Inc. (NYSE: OKE) today announced higher second-quarter 2019 financial results, compared with the second quarter 2018, and maintained 2019 financial guidance.
Higher Second-quarter 2019 Results, Compared With the Second Quarter 2018:
-- 11% increase in net income to $312.0 million, or 75 cents per diluted
share.
-- 5% increase in adjusted EBITDA to $632.4 million.
-- 1.51 times dividend coverage ratio.
-- 11% increase in NGL raw feed throughput volumes.
-- 8% increase in natural gas volumes processed.
SECOND-QUARTER 2019 FINANCIAL HIGHLIGHTS
Three Months Ended Six Months Ended
June 30,
June 30,
2019 2018 2019 2018
(Millions of dollars, except per share and dividend coverage
ratio amounts)
Net income $
312.0 $
282.2 $
649.2 $
548.2
Net income per
diluted share $
0.75 $
0.68 $
1.56 $
1.32
Adjusted EBITDA
(a) $
632.4 $
601.8 $
1,269.9 $
1,172.2
DCF (a) $
540.5 $
453.5 $
1,047.3 $
885.5
DCF in excess of
dividends paid
(a) $
183.2 $
126.5 $
335.8 $
242.0
Dividend coverage
ratio (a) 1.51 1.39 1.47 1.38
---
Operating income $
476.1 $
448.4 $
944.9 $
868.1
Operating costs $
237.7 $
230.2 $
478.4 $
440.4
Depreciation and
amortization $
115.0 $
106.3 $
229.1 $
210.5
Equity in net
earnings from
investments $
34.1 $
36.6 $
77.6 $
76.8
Capital
expenditures $
830.5 $
350.9 $
1,720.2 $
615.4
---
(a) Adjusted earnings before
interest, taxes, depreciation and
amortization (adjusted EBITDA),
distributable cash flow (DCF) and
dividend coverage ratio are non-
GAAP measures. Reconciliations to
relevant GAAP measures are included
in this news release.
"The southern section of our Elk Creek NGL Pipeline is now complete, and we expect it to provide a significant earnings uplift in the second half of 2019," said Terry K. Spencer, ONEOK president and chief executive officer.
"Our capital-growth program remains on schedule and on budget, including multiple projects that will add critical natural gas and NGL infrastructure to significantly reduce flaring in the Williston Basin," added Spencer. "With solid results and volumes so far in 2019 and the benefit of additional projects still being placed in service this year, we feel confident in achieving our 2019 financial guidance and our positioning for strong growth in 2020."
SECOND-QUARTER 2019 FINANCIAL PERFORMANCE
ONEOK's net income and adjusted earnings before interest, taxes, depreciation and amortization (adjusted EBITDA) increased 11% and 5%, respectively, in the second quarter 2019, compared with the second quarter 2018. Higher results were driven primarily by natural gas liquids (NGL) and natural gas volume growth, higher average fee rates in both the natural gas liquids and natural gas gathering and processing segments and increased transportation services in the natural gas pipelines segment. Net income also increased due to higher allowance for equity funds used during construction (AFUDC) related to ONEOK's capital-growth projects.
Results were offset partially by lower earnings from optimization and marketing due to narrower location price differentials, and higher rail transportation and third-party fractionation costs in the natural gas liquids segment and higher employee-related costs due to the growth of ONEOK's operations. Net income also was offset partially by increased depreciation expense due to capital-growth projects being placed in service.
HIGHLIGHTS:
-- Second quarter 2019 operating income and adjusted EBITDA exceeded first
quarter 2019 excluding the $20 million earnings benefit realized in the
first quarter 2019 related to purity NGLs held in inventory at year end
2018;
-- Completing on July 15, 2019, the southern section of the Elk Creek
Pipeline that extends from the Powder River Basin in eastern Wyoming to
ONEOK's existing Mid-Continent NGL facilities;
-- Announcing in July 2019 NGL and natural gas growth projects to
accommodate customer needs including:
-- A 200 million cubic feet per day (MMcf/d) expansion of ONEOK's Bear
Creek natural gas processing facility in the Williston Basin
expected to be completed in the first quarter 2021.
-- A 40,000 barrel per day (bpd) additional expansion of the West Texas
LPG pipeline in the Permian Basin, expected to be completed in the
first quarter 2021.
-- Mid-Continent NGL fractionation facility expansions totaling
approximately 65,000 bpd, with 15,000 bpd expected to be completed
in the third quarter 2020 and 50,000 bpd expected to be completed in
the first quarter 2021, and additional NGL infrastructure to
increase capacity between the Elk Creek and Arbuckle II pipelines.
-- Declaring in July 2019 a quarterly dividend of 89 cents per share, or
$3.56 per share on an annualized basis;
-- Distributable cash flow (DCF) in excess of dividends paid of $183.2
million;
-- Net debt-to-EBITDA ratio on a trailing 12-month basis of 4.2 times as of
June 30, 2019; and
-- Having $2.5 billion of borrowing capacity available under its credit
agreement and $273.4 million of cash and cash equivalents as of June 30,
2019.
BUSINESS-SEGMENT RESULTS:
Natural Gas Liquids Segment
Second-quarter 2019 NGL raw feed throughput volumes increased 11%, compared with the same period in 2018, driven primarily by higher volumes in the Rocky Mountain region, STACK and SCOOP areas and the Permian Basin.
The segment connected three third-party natural gas processing plants to its system in the second quarter 2019, two in the Mid-Continent region and one in the Permian Basin.
Three Months Ended Six Months Ended
June 30, June 30,
Natural Gas
Liquids Segment 2019 2018 2019 2018
---
(Millions of dollars)
Adjusted EBITDA $
346.8 $
352.1 $
724.4 $
694.1
Capital
expenditures $
591.8 $
216.9 $
1,231.1 $
341.9
---
The decrease in second-quarter 2019 adjusted EBITDA, compared with the second quarter 2018, primarily reflects:
-- A $36.9 million decrease in optimization and marketing due to lower
optimization of $29.7 million related primarily to narrower location
price differentials and lower marketing of $8.0 million related
primarily to the timing of purity NGL inventory sales and changes in the
value of NGLs held in inventory; and
-- A $17.2 million increase in operating costs due primarily to higher
employee-related costs and the timing of routine maintenance projects;
offset partially by
-- A $50.7 million increase in exchange services due to $43.5 million from
higher volumes primarily in the Rocky Mountain region, STACK and SCOOP
areas and the Permian Basin, $20.6 million in higher average fee rates
primarily in the Permian Basin and Barnett Shale and $12.6 million
related to lower unfractionated NGL inventory levels, offset partially
by $20.5 million in higher rail transportation and third-party
fractionation costs.
The increase in adjusted EBITDA for the six-month 2019 period, compared with the same period last year, primarily reflects:
-- An $81.2 million increase in exchange services due to $88.3 million from
higher volumes primarily in the Rocky Mountain region, STACK and SCOOP
areas and the Permian Basin, $42.2 million in higher average fee rates
primarily in the Permian Basin and Barnett Shale and $7.9 million
related to lower unfractionated NGL inventory levels, offset partially
by $42.2 million in higher rail transportation and third-party
fractionation costs and $11.3 million due primarily to narrower product
price differentials; offset partially by
-- A $36.0 million increase in operating costs due primarily to higher
employee-related costs and the timing of routine maintenance projects;
and
-- A $10.4 million decrease in optimization and marketing due to $33.9
million in narrower location price differentials, offset partially by
$8.6 million in increased optimization volume, higher marketing of $7.7
million related primarily to the sale of NGL purity products previously
held in inventory offset partially by changes in the value of NGLs
currently held in inventory, and $7.2 million in higher earnings related
primarily to product price differentials.
Natural Gas Gathering and Processing Segment
The natural gas gathering and processing segment's second-quarter 2019 adjusted EBITDA increased 12%, compared with the same period in 2018.
Volume growth in the Williston Basin and STACK and SCOOP areas of the Mid-Continent contributed to an 8% increase in natural gas volumes processed compared with the same period in 2018.
The segment also continues to benefit from higher fee-based earnings, with an average fee rate of 93 cents per Million British thermal units (MMBtu) in the second quarter 2019, compared with 89 cents per MMBtu in the second quarter 2018.
Three Months Ended Six Months Ended
June 30, June 30,
Natural Gas
Gathering and
Processing
Segment 2019 2018 2019 2018
---
(Millions of dollars)
Adjusted EBITDA $
186.6 $
166.9 $
338.9 $
297.4
Capital
expenditures $
213.2 $
108.8 $
428.4 $
220.6
---
Second-quarter 2019 adjusted EBITDA increased, compared with the second quarter 2018, which primarily reflects:
-- A $27.5 million increase due primarily to natural gas volume growth in
the Williston Basin and STACK and SCOOP areas, offset partially by
natural production declines; and
-- A $6.5 million decrease in operating costs due primarily to lower
materials, supplies and outside services expenses, offset partially by
higher employee-related costs due to operational growth; offset
partially by
-- An $8.2 million decrease due to favorable contract settlements in the
second quarter 2018; and
-- A $4.8 million decrease due primarily to lower realized natural gas and
NGL prices, net of hedges.
The increase in adjusted EBITDA for the six-month 2019 period, compared with the same period last year, primarily reflects:
-- A $51.8 million increase due primarily to natural gas volume growth in
the Williston Basin and STACK and SCOOP areas, offset partially by
natural production declines; and
-- A $2.7 million decrease in operating costs due primarily to lower
materials, supplies and outside services expenses, offset partially by
higher employee-related costs due to operational growth; offset
partially by
-- An $8.2 million decrease due to favorable contract settlements in the
second quarter 2018.
Natural Gas Pipelines Segment
The natural gas pipelines segment's adjusted EBITDA increased 18% in the second quarter 2019, compared with the same period in 2018, due primarily to higher firm transportation capacity contracted due to completed expansion projects.
Three Months Ended Six Months Ended
June 30, June 30,
Natural Gas
Pipelines
Segment 2019 2018 2019 2018
---
(Millions of dollars)
Adjusted EBITDA $
100.5 $
85.4 $
207.2 $
179.0
Capital
expenditures $
21.4 $
20.5 $
50.1 $
40.4
---
The increase in adjusted EBITDA for the second quarter 2019, compared with the second quarter 2018, primarily reflects:
-- A $19.0 million increase from higher transportation services due
primarily to firm transportation capacity contracted due to completed
expansion projects; offset partially by
-- A $2.4 million increase in operating costs due primarily to higher
employee-related costs.
The increase in adjusted EBITDA for the six-month 2019 period, compared with the same period last year, primarily reflects:
-- A $34.7 million increase from higher transportation services due
primarily to firm transportation capacity contracted due to completed
expansion projects; and
-- A $4.0 million increase due primarily to higher equity in net earnings
from investments due to increased seasonal transportation capacity
contracted on Northern Border Pipeline in the first quarter 2019 and
increased firm transportation capacity contracted on Roadrunner Gas
Transmission; offset partially by
-- A $5.7 million decrease from lower net retained fuel and the timing of
equity gas sales; and
-- A $4.8 million increase in operating costs due primarily to higher
employee-related costs.
EARNINGS CONFERENCE CALL AND WEBCAST:
ONEOK executive management will conduct a conference call at 11 a.m. Eastern Daylight Time (10 a.m. Central Daylight Time) on July 31, 2019. The call also will be carried live on ONEOK's website.
To participate in the telephone conference call, dial 800-353-6461, pass code 3421896, or log on to www.oneok.com.
If you are unable to participate in the conference call or the webcast, the replay will be available on ONEOK's website, www.oneok.com, for 30 days. A recording will be available by phone for seven days. The playback call may be accessed at 888-203-1112, pass code 3421896.
LINKS TO EARNINGS TABLES AND PRESENTATION:
Presentation:
http://ir.oneok.com/~/media/Files/O/OneOK-IR/financial-reports/2019/q2-2019-earnings-results-presentation.pdf
NON-GAAP (GENERALLY ACCEPTED ACCOUNTING PRINCIPLES) FINANCIAL MEASURES:
ONEOK has disclosed in this news release adjusted earnings before interest, taxes, depreciation and amortization (adjusted EBITDA), distributable cash flow and dividend coverage ratio, which are non-GAAP financial metrics, used to measure the company's financial performance and are defined as follows:
-- Adjusted EBITDA is defined as net income adjusted for interest expense,
depreciation and amortization, noncash impairment charges, income taxes,
noncash compensation expense, allowance for equity funds used during
construction (equity AFUDC), and other noncash items.
-- Distributable cash flow is defined as adjusted EBITDA, computed as
described above, less interest expense, maintenance capital expenditures
and equity earnings from investments, excluding noncash impairment
charges, adjusted for cash distributions received from unconsolidated
affiliates and certain other items.
-- Dividend coverage ratio is defined as ONEOK's distributable cash flow to
ONEOK shareholders divided by the dividends paid for the period.
These non-GAAP financial measures described above are useful to investors because they, and similar measures, are used by many companies in the industry as a measure of financial performance and are commonly employed by financial analysts and others to evaluate ONEOK's financial performance and to compare ONEOK's financial performance with the performance of other companies within ONEOK's industry. Adjusted EBITDA, distributable cash flow and dividend coverage ratio should not be considered in isolation or as a substitute for net income or any other measure of financial performance presented in accordance with GAAP.
These non-GAAP financial measures exclude some, but not all, items that affect net income. Additionally, these calculations may not be comparable with similarly titled measures of other companies. Reconciliations of net income to adjusted EBITDA, distributable cash flow and dividend coverage ratio are included in the tables.
ONEOK, Inc. (pronounced ONE-OAK) (NYSE: OKE) is a leading midstream service provider and owner of one of the nation's premier natural gas liquids (NGL) systems, connecting NGL supply in the Mid-Continent, Permian and Rocky Mountain regions with key market centers and an extensive network of natural gas gathering, processing, storage and transportation assets.
ONEOK is a FORTUNE 500 company and is included in the S&P 500.
For the latest news about ONEOK, find us at www.oneok.com or on LinkedIn, Facebook, Twitter and Instagram.
Some of the statements contained and incorporated in this news release are forward-looking statements as defined under federal securities laws. The forward-looking statements relate to our anticipated financial performance (including projected levels of quarterly and annual dividends), liquidity, management's plans and objectives for our future capital-growth projects and other future operations (including plans to construct additional natural gas and natural gas liquids pipelines and processing facilities), our business prospects, the outcome of regulatory and legal proceedings, market conditions and other matters. We make these forward-looking statements in reliance on the safe harbor protections provided under federal securities laws and other applicable laws.
Forward-looking statements include the items identified in the preceding paragraph, the information concerning possible or assumed future results of our operations and other statements contained or incorporated in this news release identified by words such as "anticipate," "believe," "continue," "could," "estimate," "expect," "forecast," "goal," "guidance," "intend," "may," "might," "plan," "potential," "project," "scheduled," "should," "will," "would" and other words and terms of similar meaning.
One should not place undue reliance on forward-looking statements. Known and unknown risks, uncertainties and other factors may cause our actual results, performance or achievements to be materially different from any future results, performance or achievements expressed or implied by forward-looking statements. Those factors may affect our operations, markets, products, services and prices. These and other risks are described in greater detail in Item 1A, Risk Factors, in our most recent Annual Report on Form 10-K and in the other filings that we make with the Securities and Exchange Commission (SEC), which are available on the SEC's website at www.sec.gov. All forward-looking statements attributable to us or persons acting on our behalf are expressly qualified in their entirety by these factors. Any such forward-looking statement speaks only as of the date on which such statement is made, and, other than as required under securities laws, we undertake no obligation to update publicly any forward-looking statement whether as a result of new information, subsequent events or change in circumstances, expectations or otherwise.
Forward-looking statements are based on current expectations, estimates and assumptions that involve a number of risks and uncertainties, many of which are beyond our control, and are not guarantees of future results. Accordingly, there are or will be important factors that could cause actual results to differ materially from those indicated in such statements and, therefore, you should not place undue reliance on any such statements and caution must be exercised in relying on forward-looking statements. These risks and uncertainties include, without limitation, the following:
-- competition from other United States and foreign energy suppliers and
transporters, as well as alternative forms of energy, including, but not
limited to, solar power, wind power, geothermal energy and biofuels such
as ethanol and biodiesel;
-- the capital intensive nature of our businesses;
-- the profitability of assets or businesses acquired or constructed by us;
-- risks of marketing, trading and hedging activities, including the risks
of changes in energy prices or the financial condition of our
counterparties;
-- the uncertainty of estimates, including accruals and costs of
environmental remediation;
-- the effects of changes in governmental policies and regulatory actions,
including changes with respect to income and other taxes, pipeline
safety, environmental compliance, climate change initiatives and
authorized rates of recovery of natural gas and natural gas
transportation costs;
-- the impact on drilling and production by factors beyond our control,
including the demand for natural gas and crude oil; producers' desire
and ability to drill and obtain necessary permits; reserve performance;
and capacity constraints on the pipelines that transport crude oil,
natural gas and NGLs from producing areas and our facilities;
-- difficulties or delays experienced by trucks, railroads or pipelines in
delivering products to or from our terminals or pipelines;
-- the effects of weather and other natural phenomena, including climate
change, on our operations, demand for our services and energy prices;
-- changes in demand for the use of natural gas, NGLs and crude oil because
of market conditions caused by concerns about climate change;
-- the impact of unforeseen changes in interest rates, debt and equity
markets, inflation rates, economic recession and other external factors
over which we have no control, including the effect on pension and
postretirement expense and funding resulting from changes in equity and
bond market returns;
-- our indebtedness and guarantee obligations could make us vulnerable to
general adverse economic and industry conditions, limit our ability to
borrow additional funds and/or place us at competitive disadvantages
compared with our competitors that have less debt, or have other adverse
consequences;
-- actions by rating agencies concerning our credit;
-- the results of administrative proceedings and litigation, regulatory
actions, rule changes and receipt of expected clearances involving any
local, state or federal regulatory body, including the Federal Energy
Regulatory Commission (FERC), the National Transportation Safety Board,
the Pipeline and Hazardous Materials Safety Administration (PHMSA), the
U.S. Environmental Protection Agency (EPA) and the U.S. Commodity
Futures Trading Commission (CFTC);
-- our ability to access capital at competitive rates or on terms
acceptable to us;
-- risks associated with adequate supply to our gathering, processing,
fractionation and pipeline facilities, including production declines
that outpace new drilling or extended periods of ethane rejection;
-- the risk that material weaknesses or significant deficiencies in our
internal controls over financial reporting could emerge or that minor
problems could become significant;
-- the impact and outcome of pending and future litigation;
-- the timing and extent of changes in energy commodity prices;
-- the ability to market pipeline capacity on favorable terms, including
the effects of:
-- future demand for and prices of natural gas, NGLs and crude oil;
-- competitive conditions in the overall energy market;
-- availability of supplies of United States natural gas and crude oil;
and
-- availability of additional storage capacity;
-- performance of contractual obligations by our customers, service
providers, contractors and shippers;
-- the timely receipt of approval by applicable governmental entities for
construction and operation of our pipeline and other projects and
required regulatory clearances;
-- our ability to acquire all necessary permits, consents or other
approvals in a timely manner, to promptly obtain all necessary materials
and supplies required for construction, and to construct gathering,
processing, storage, fractionation and transportation facilities without
labor or contractor problems;
-- the mechanical integrity of facilities operated;
-- demand for our services in the proximity of our facilities;
-- our ability to control operating costs and make cost-saving changes;
-- acts of nature, sabotage, terrorism or other similar acts that cause
damage to our facilities or our suppliers', customers' or shippers'
facilities;
-- economic climate and growth in the geographic areas in which we do
business;
-- the risk of a prolonged slowdown in growth or decline in the United
States or international economies, including liquidity risks in United
States or foreign credit markets;
-- the impact of recently issued and future accounting updates and other
changes in accounting policies;
-- the possibility of future terrorist attacks or the possibility or
occurrence of an outbreak of, or changes in, hostilities or changes in
the political conditions throughout the world;
-- the risk of increased costs for insurance premiums, security or other
items as a consequence of terrorist attacks;
-- risks associated with pending or possible acquisitions and dispositions,
including our ability to finance or integrate any such acquisitions and
any regulatory delay or conditions imposed by regulatory bodies in
connection with any such acquisitions and dispositions;
-- the impact of uncontracted capacity in our assets being greater or less
than expected;
-- the ability to recover operating costs and amounts equivalent to income
taxes, costs of property, plant and equipment and regulatory assets in
our state and FERC-regulated rates;
-- the composition and quality of the natural gas and NGLs we gather and
process in our plants and transport on our pipelines;
-- the efficiency of our plants in processing natural gas and extracting
and fractionating NGLs;
-- the impact of potential impairment charges;
-- the risk inherent in the use of information systems in our respective
businesses, implementation of new software and hardware, and the impact
on the timeliness of information for financial reporting;
-- our ability to control construction costs and completion schedules of
our pipelines and other projects; and
-- the risk factors listed in the reports ONEOK has filed and may file with
the Securities and Exchange Commission (the "SEC"), which are
incorporated by reference.
These reports are also available from the sources described below. Forward-looking statements are based on the estimates and opinions of management at the time the statements are made. ONEOK undertakes no obligation to publicly update any forward-looking statement, whether as a result of new information, future events or changes in circumstances, expectations or otherwise.
The foregoing review of important factors should not be construed as exhaustive and should be read in conjunction with the other cautionary statements that are included herein and elsewhere, including the Risk Factors included in the most recent reports on Form 10-K and Form 10-Q and other documents of ONEOK on file with the SEC. ONEOK's SEC filings are available publicly on the SEC's website at www.sec.gov.
Analyst Contact: Megan Patterson
918-561-5325
Media Contact: Brad Borror
918-588-7582
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SOURCE ONEOK, Inc.
