CVR Energy, Inc. (NYSE: CVI, “CVR Energy” or the “Company”) today
announced a net loss attributable to CVR Energy stockholders of
$124 million, or $1.24 per diluted share, and an EBITDA loss of $35
million for the third quarter of 2024, compared to net income
attributable to CVR Energy stockholders of $353 million, or $3.51
per diluted share, and EBITDA of $530 million for the third quarter
of 2023. Excluding the adjustments shown in the corresponding
earnings release tables, adjusted loss per diluted share for the
third quarter of 2024 was 50 cents and adjusted EBITDA was $63
million, compared to adjusted earnings per diluted share of $1.89
and adjusted EBITDA of $313 million in the third quarter of 2023.
“CVR Energy’s 2024 third quarter earnings
results for its refining business were impacted by reduced refining
throughputs attributable to unplanned downtime at both facilities
partially caused by external power supply outages during the
quarter,” said Dave Lamp, CVR Energy’s Chief Executive Officer.
“The Board’s decision to suspend the quarterly dividend reflects
its concerns on just how long the current margin environment will
persist in light of the Company’s large, planned turnaround at its
Coffeyville refinery in the first quarter of 2025.
“CVR Partners achieved solid operating results
for the third quarter of 2024 driven by safe, reliable operations
and a combined ammonia production rate of 97 percent,” Lamp said.
“CVR Partners was pleased to declare a third quarter 2024 cash
distribution of $1.19 per common unit.”
Petroleum
The Petroleum Segment reported a third quarter
2024 net loss of $110 million and an EBITDA loss of $75 million,
compared to net income of $460 million and EBITDA of $484 million
for the third quarter of 2023. Adjusted EBITDA for the Petroleum
Segment was $24 million for the third quarter of 2024, compared to
$281 million for the third quarter of 2023.
Combined total throughput for the third quarter
of 2024 was approximately 189,000 barrels per day (bpd) compared to
approximately 212,000 bpd of combined total throughput for the
third quarter of 2023.
Refining margin for the third quarter of 2024
was $44 million, or $2.53 per total throughput barrel, compared to
$607 million, or $31.05 per total throughput barrel, during
the same period in 2023. Included in our third quarter 2024
refining margin were unfavorable mark-to-market impacts on our
outstanding RFS obligation of $59 million, unfavorable derivative
impacts of $9 million from open crack spread swap positions
and unfavorable inventory valuation impacts of $31 million.
Excluding these items, adjusted refining margin for the third
quarter of 2024 was $8.23 per barrel, compared to an adjusted
refining margin per barrel of $20.73 for the third quarter of 2023.
The decrease in adjusted refining margin per barrel was primarily
due to a decrease in the Group 3 2-1-1 crack spread.
Nitrogen Fertilizer
The Nitrogen Fertilizer Segment reported net
income of $4 million and EBITDA of $36 million on net
sales of $125 million for the third quarter of 2024, compared to
net income of $1 million and EBITDA of $32 million on net
sales of $131 million for the third quarter of 2023.
Production at CVR Partners, LP’s (“CVR
Partners”) fertilizer facilities decreased slightly compared to the
third quarter of 2023, producing a combined 212,000 tons of ammonia
during the third quarter of 2024, of which 61,000 net tons were
available for sale while the rest was upgraded to other fertilizer
products, including 321,000 tons of urea ammonia nitrate (“UAN”).
During the third quarter of 2023, the fertilizer facilities
produced a combined 217,000 tons of ammonia, of which 68,000 net
tons were available for sale while the remainder was upgraded to
other fertilizer products, including 358,000 tons of UAN.
For the third quarter 2024, average realized
gate prices for UAN showed an improvement compared to the prior
year, up 3 percent to $229 per ton, and ammonia was up 9 percent
over the prior year to $399 per ton. Average realized gate
prices for UAN and ammonia were $223 and $365 per ton,
respectively, for the third quarter of 2023.
Corporate and Other
The Company reported an income tax benefit of $6
million, or 4.6 percent of loss before income taxes, for the three
months ended September 30, 2024, compared to an income tax expense
of $84 million, or 19.3 percent of income before income taxes, for
the three months ended September 30, 2023. The decrease in income
tax expense was primarily due to a decrease in overall pretax
earnings while the change in the effective tax rate was primarily
due to changes in pretax earnings attributable to noncontrolling
interest and the impact of federal and state tax credits and
incentives in relation to overall pretax earnings.
The renewable diesel unit at the Wynnewood
refinery had total vegetable oil throughputs for the third quarter
of 2024 of approximately 19.6 million gallons, down from 23.8
million gallons in the third quarter of 2023. The decrease was
primarily due to running the unit at lower utilization rates in the
current period in an effort to optimize catalyst life.
Cash, Debt and Dividend
Consolidated cash and cash equivalents were $534
million at September 30, 2024, a decrease of $47 million from
December 31, 2023. Consolidated total debt and finance lease
obligations were $1.6 billion at September 30, 2024, including $548
million held by the Nitrogen Fertilizer Segment.
CVR Energy will not pay a cash dividend for the
third quarter of 2024.
Today, CVR Partners announced that the Board of
Directors of its general partner declared a third quarter 2024 cash
distribution of $1.19 per common unit, which will be paid on
November 18, 2024, to common unitholders of record as of
November 8, 2024.
Third Quarter
2024 Earnings Conference Call
CVR Energy previously announced that it will
host its third quarter 2024 Earnings Conference Call on Tuesday,
October 29, at 1 p.m. Eastern. The Earnings Conference Call
may also include discussion of Company developments,
forward-looking information and other material information about
business and financial matters.
The third quarter 2024 Earnings Conference Call
will be webcast live and can be accessed on the Investor Relations
section of CVR Energy’s website at www.CVREnergy.com. For investors
or analysts who want to participate during the call, the dial-in
number is (877) 407-8291. The webcast will be archived and
available for 14 days at
https://edge.media-server.com/mmc/p/fm39ca3r. A repeat of the call
also can be accessed for 14 days by dialing (877) 660-6853,
conference ID 13749245.
Forward-Looking StatementsThis
news release may contain forward-looking statements within the
meaning of Section 27A of the Securities Act of 1933, as amended,
and Section 21E of the Securities Exchange Act of 1934, as amended.
Statements concerning current estimates, expectations and
projections about future results, performance, prospects,
opportunities, plans, actions and events and other statements,
concerns, or matters that are not historical facts are
“forward-looking statements,” as that term is defined under the
federal securities laws. These forward-looking statements include,
but are not limited to, statements regarding future: continued safe
and reliable operations; drivers of our results; income, losses,
and earnings per diluted share; EBITDA and Adjusted EBITDA;
renewable identification numbers (“RINs”) expense; asset
utilization, capture, production volume, product yield and crude
oil gathering rates; cash flow generation; production; operating
income and net sales; throughput, including the impact of
turnarounds or fires thereon; refining margin, including
contributors thereto; margin environment; impact of costs to comply
with the RFS and revaluation of our RFS liability; outcome of
litigation and disputes, including impact on our financial position
and cash flows; crude oil and refined product pricing impacts on
inventory valuation; dividend yield; derivative gains and losses
and the drivers thereof; crack spreads, including the drivers
thereof; demand trends; RIN generation levels; ethanol and
biodiesel blending activities; inventory levels; benefits of our
corporate transformation to segregate our renewables business;
access to capital and new partnerships; RIN pricing, including its
impact on our results and our ability to offset the impact thereof;
disruptions to operations (planned and unplanned), including
impacts on results; carbon capture and decarbonization initiatives;
ammonia and UAN pricing; global fertilizer industry conditions;
grain prices; crop inventory levels; crop and planting levels;
demand for refined products; economic downturns and demand
destruction; production rates; production levels and utilization at
our nitrogen fertilizer facilities; nitrogen fertilizer sales
volumes, including factors driving same; ability to and levels to
which we upgrade ammonia to other fertilizer products, including
UAN; income tax expense, including the drivers thereof; changes to
pretax earnings and our effective tax rate; the availability of tax
credits and incentives; production rates and operations
capabilities of our renewable diesel unit, including the ability to
return to hydrocarbon service; renewable feedstock throughput;
purchases under share or unit repurchase programs (if any), or the
termination thereof; ability to access capital markets, secure
financing or sell assets; cash and cash equivalent levels; debt
levels; borrowings under our credit facilities (if any); dividends
and distributions, including the timing, payment and amount (if
any) thereof; any suspension of our dividend, including the
duration thereof; direct operating expenses, capital expenditures,
depreciation and amortization; efforts to reduce or defer expenses
and the amount and impact thereof; cash reserves; turnaround timing
and expense, including the impacts thereof on our liquidity;
impacts of any pandemic; labor supply shortages, difficulties,
disputes or strikes, including the impact thereof; the April 2024
fire at the Wynnewood Refinery including the impact and cost
thereof on and to our operations, financial position or otherwise;
and other matters. You can generally identify forward-looking
statements by our use of forward-looking terminology such as
“outlook,” “anticipate,” “believe,” “continue,” “could,”
“estimate,” “expect,” “explore,” “evaluate,” “intend,” “may,”
“might,” “plan,” “potential,” “predict,” “seek,” “should,” or
“will,” or the negative thereof or other variations thereon or
comparable terminology. These forward-looking statements are only
predictions and involve known and unknown risks and uncertainties,
many of which are beyond our control. Investors are cautioned that
various factors may affect these forward-looking statements,
including (among others) the health and economic effects of any
pandemic, demand for fossil fuels and price volatility of crude
oil, other feedstocks and refined products; the ability of Company
to pay cash dividends and of CVR Partners to make cash
distributions; potential operating hazards, including the impacts
of fires at our facilities; costs of compliance with existing or
new laws and regulations and potential liabilities arising
therefrom; impacts of the planting season on CVR Partners; our
controlling shareholder’s intention regarding ownership of our
common stock and potential strategic transactions involving us or
CVR Partners; general economic and business conditions; political
disturbances, geopolitical instability and tensions; impacts of
plant outages and weather conditions and events; and other risks.
For additional discussion of risk factors which may affect our
results, please see the risk factors and other disclosures included
in our most recent Annual Report on Form 10-K, any subsequently
filed Quarterly Reports on Form 10-Q and our other Securities and
Exchange Commission (“SEC”) filings. These and other risks may
cause our actual results, performance or achievements to differ
materially from any future results, performance or achievements
expressed or implied by these forward-looking statements. Given
these risks and uncertainties, you are cautioned not to place undue
reliance on such forward-looking statements. The forward-looking
statements included in this news release are made only as of the
date hereof. CVR Energy disclaims any intention or obligation to
update publicly or revise any forward-looking statements, whether
as a result of new information, future events or otherwise, except
to the extent required by law.
About CVR Energy, Inc.
Headquartered in Sugar Land, Texas, CVR Energy
is a diversified holding company primarily engaged in the
renewables, petroleum refining and marketing business as well as in
the nitrogen fertilizer manufacturing business through its interest
in CVR Partners. CVR Energy subsidiaries serve as the general
partner and own 37 percent of the common units of CVR Partners.
Investors and others should note that CVR Energy
may announce material information using SEC filings, press
releases, public conference calls, webcasts and the Investor
Relations page of its website. CVR Energy may use these channels to
distribute material information about the Company and to
communicate important information about the Company, corporate
initiatives and other matters. Information that CVR Energy posts on
its website could be deemed material; therefore, CVR Energy
encourages investors, the media, its customers, business partners
and others interested in the Company to review the information
posted on its website.
Contact Information:
Investor RelationsRichard Roberts(281)
207-3205InvestorRelations@CVREnergy.com
Media RelationsBrandee Stephens(281)
207-3516MediaRelations@CVREnergy.com
Non-GAAP Measures
Our management uses certain non-GAAP performance
measures, and reconciliations to those measures, to evaluate
current and past performance and prospects for the future to
supplement our financial information presented in accordance with
accounting principles generally accepted in the United States
(“GAAP”). These non-GAAP financial measures are important factors
in assessing our operating results and profitability and include
the performance and liquidity measures defined below.
As a result of continuing volatile market
conditions and the impacts certain non-cash items may have on the
evaluation of our operations and results, the Company began
disclosing the Adjusted Refining Margin non-GAAP measure, as
defined below, in the second quarter of 2024. We believe the
presentation of this non-GAAP measure is meaningful to compare our
operating results between periods and better aligns with our peer
companies. All prior periods presented have been conformed to the
definition below.
The following are non-GAAP measures we present
for the periods ended September 30, 2024 and 2023:
EBITDA - Consolidated net income (loss) before
(i) interest expense, net, (ii) income tax expense (benefit) and
(iii) depreciation and amortization expense.
Petroleum EBITDA and Nitrogen Fertilizer EBITDA
- Segment net income (loss) before segment (i) interest expense,
net, (ii) income tax expense (benefit), and (iii) depreciation and
amortization.
Refining Margin - The difference between our
Petroleum Segment net sales and cost of materials and other.
Adjusted Refining Margin - Refining Margin
adjusted for certain significant noncash items and items that
management believes are not attributable to or indicative of our
underlying operational results of the period or that may obscure
results and trends we deem useful.
Refining Margin and Adjusted Refining Margin,
per Throughput Barrel - Refining Margin and Adjusted Refining
Margin divided by the total throughput barrels during the period,
which is calculated as total throughput barrels per day times the
number of days in the period.
Direct Operating Expenses per Throughput Barrel
- Direct operating expenses for our Petroleum Segment divided by
total throughput barrels for the period, which is calculated as
total throughput barrels per day times the number of days in the
period.
Adjusted EBITDA, Petroleum Adjusted EBITDA and
Nitrogen Fertilizer Adjusted EBITDA - EBITDA, Petroleum EBITDA and
Nitrogen Fertilizer EBITDA adjusted for certain significant noncash
items and items that management believes are not attributable to or
indicative of our underlying operational results of the period or
that may obscure results and trends we deem useful.
Adjusted Earnings (Loss) per Share - Earnings
(loss) per share adjusted for certain significant non-cash items
and items that management believes are not attributable to or
indicative of our underlying operational results of the period or
that may obscure results and trends we deem useful.
Free Cash Flow - Net cash provided by (used in)
operating activities less capital expenditures and capitalized
turnaround expenditures.
We present these measures because we believe
they may help investors, analysts, lenders and ratings agencies
analyze our results of operations and liquidity in conjunction with
our U.S. GAAP results, including but not limited to our operating
performance as compared to other publicly traded companies in the
refining and fertilizer industries, without regard to historical
cost basis or financing methods and our ability to incur and
service debt and fund capital expenditures. Non-GAAP measures have
important limitations as analytical tools, because they exclude
some, but not all, items that affect net earnings and operating
income. These measures should not be considered substitutes for
their most directly comparable U.S. GAAP financial measures. See
“Non-GAAP Reconciliations” included herein for reconciliation of
these amounts. Due to rounding, numbers presented within this
section may not add or equal to numbers or totals presented
elsewhere within this document.
Factors Affecting Comparability of Our
Financial Results
Petroleum Segment
Our results of operations for the periods
presented may not be comparable with prior periods or to our
results of operations in the future due to capitalized expenditures
as part of planned turnarounds. Total capitalized expenditures were
$3 million and $2 million during the three months ended September
30, 2024 and 2023, respectively, and $45 million and $53 million
during the nine months ended September 30, 2024 and 2023,
respectively. The next planned turnaround is currently scheduled to
take place in the first quarter of 2025 at the Coffeyville
refinery.
|
CVR Energy, Inc. (all information in this release
is unaudited) |
| Consolidated Statement
of Operations Data |
|
|
|
| |
Three Months EndedSeptember
30, |
|
Nine Months EndedSeptember
30, |
|
(in millions, except per share data) |
|
2024 |
|
|
|
2023 |
|
|
|
2024 |
|
|
|
2023 |
|
| Net sales |
$ |
1,833 |
|
|
$ |
2,522 |
|
|
$ |
5,663 |
|
|
$ |
7,045 |
|
| Operating costs and
expenses: |
|
|
|
|
|
|
|
|
Cost of materials and other |
|
1,666 |
|
|
|
1,787 |
|
|
|
4,796 |
|
|
|
5,211 |
|
|
Direct operating expenses (exclusive of depreciation and
amortization) |
|
165 |
|
|
|
170 |
|
|
|
502 |
|
|
|
503 |
|
|
Depreciation and amortization |
|
73 |
|
|
|
80 |
|
|
|
218 |
|
|
|
217 |
|
|
Cost of sales |
|
1,904 |
|
|
|
2,037 |
|
|
|
5,516 |
|
|
|
5,931 |
|
| Selling, general and
administrative expenses (exclusive of depreciation and
amortization) |
|
40 |
|
|
|
38 |
|
|
|
103 |
|
|
|
109 |
|
| Depreciation and
amortization |
|
2 |
|
|
|
1 |
|
|
|
6 |
|
|
|
4 |
|
| Loss on asset disposal |
|
— |
|
|
|
1 |
|
|
|
1 |
|
|
|
1 |
|
|
Operating (loss) income |
|
(113 |
) |
|
|
445 |
|
|
|
37 |
|
|
|
1,000 |
|
| Other (expense) income: |
|
|
|
|
|
|
|
|
Interest expense, net |
|
(18 |
) |
|
|
(11 |
) |
|
|
(56 |
) |
|
|
(44 |
) |
|
Other income, net |
|
3 |
|
|
|
4 |
|
|
|
10 |
|
|
|
10 |
|
|
(Loss) income before income tax benefit |
|
(128 |
) |
|
|
438 |
|
|
|
(9 |
) |
|
|
966 |
|
| Income tax (benefit)
expense |
|
(6 |
) |
|
|
84 |
|
|
|
(14 |
) |
|
|
185 |
|
|
Net (loss) income |
|
(122 |
) |
|
|
354 |
|
|
|
5 |
|
|
|
781 |
|
| Less: Net income attributable
to noncontrolling interest |
|
2 |
|
|
|
1 |
|
|
|
27 |
|
|
|
103 |
|
|
Net (loss) income attributable to CVR Energy
stockholders |
$ |
(124 |
) |
|
$ |
353 |
|
|
$ |
(22 |
) |
|
$ |
678 |
|
| |
|
|
|
|
|
|
|
|
Basic and diluted (loss) earnings per share |
$ |
(1.24 |
) |
|
$ |
3.51 |
|
|
$ |
(0.22 |
) |
|
$ |
6.74 |
|
|
Dividends declared per share |
$ |
0.50 |
|
|
$ |
1.50 |
|
|
$ |
1.50 |
|
|
$ |
2.50 |
|
| |
|
|
|
|
|
|
|
| Adjusted (loss) earnings per
share |
$ |
(0.50 |
) |
|
$ |
1.89 |
|
|
$ |
(0.38 |
) |
|
$ |
4.98 |
|
| EBITDA* |
$ |
(35 |
) |
|
$ |
530 |
|
|
$ |
271 |
|
|
$ |
1,231 |
|
| Adjusted EBITDA * |
$ |
63 |
|
|
$ |
313 |
|
|
$ |
249 |
|
|
$ |
994 |
|
| |
|
|
|
|
|
|
|
| Weighted-average common shares
outstanding - basic and diluted |
|
100.5 |
|
|
|
100.5 |
|
|
|
100.5 |
|
|
|
100.5 |
|
_________________
* See “Non-GAAP Reconciliations” section below.
Selected Consolidated Balance Sheet Data
| (in millions) |
September 30, 2024 |
|
December 31, 2023 |
|
Cash and cash equivalents |
$ |
534 |
|
$ |
581 |
|
Working capital |
|
353 |
|
|
497 |
|
Total assets |
|
3,878 |
|
|
4,707 |
|
Total debt and finance lease obligations, including current
portion |
|
1,582 |
|
|
2,185 |
|
Total liabilities |
|
3,022 |
|
|
3,669 |
|
Total CVR stockholders’ equity |
|
675 |
|
|
847 |
Selected Consolidated Cash Flow Data
| |
Three Months EndedSeptember
30, |
|
Nine Months EndedSeptember
30, |
|
(in millions) |
|
2024 |
|
|
|
2023 |
|
|
|
2024 |
|
|
|
2023 |
|
| Net cash (used in) provided
by: |
|
|
|
|
|
|
|
|
Operating activities |
$ |
48 |
|
|
$ |
370 |
|
|
$ |
306 |
|
|
$ |
984 |
|
|
Investing activities |
|
(35 |
) |
|
|
(51 |
) |
|
|
(164 |
) |
|
|
(181 |
) |
|
Financing activities |
|
(65 |
) |
|
|
(181 |
) |
|
|
(794 |
) |
|
|
(424 |
) |
|
Net (decrease) increase in cash, cash equivalents, and
restricted cash |
$ |
(52 |
) |
|
$ |
138 |
|
|
$ |
(652 |
) |
|
$ |
379 |
|
| |
|
|
|
|
|
|
|
| Free cash flow* |
$ |
13 |
|
|
$ |
318 |
|
|
$ |
141 |
|
|
$ |
802 |
|
_________________
* See “Non-GAAP Reconciliations” section
below.
Selected Segment Data
| |
Three Months Ended September 30, |
| |
|
2024 |
|
|
|
2023 |
| (in millions) |
Petroleum |
|
Nitrogen Fertilizer |
|
Consolidated |
|
Petroleum |
|
Nitrogen Fertilizer |
|
Consolidated |
|
Net sales |
$ |
1,648 |
|
|
$ |
125 |
|
$ |
1,833 |
|
|
$ |
2,298 |
|
$ |
131 |
|
$ |
2,522 |
| Operating (loss) income |
|
(119 |
) |
|
|
11 |
|
|
(113 |
) |
|
|
431 |
|
|
8 |
|
|
445 |
| Net (loss) income |
|
(110 |
) |
|
|
4 |
|
|
(122 |
) |
|
|
460 |
|
|
1 |
|
|
354 |
| EBITDA* |
|
(75 |
) |
|
|
36 |
|
|
(35 |
) |
|
|
484 |
|
|
32 |
|
|
530 |
| |
|
|
|
|
|
|
|
|
|
|
|
| Capital expenditures(1) |
|
|
|
|
|
|
|
|
|
|
|
|
Maintenance capital expenditures |
$ |
22 |
|
|
$ |
7 |
|
$ |
31 |
|
|
$ |
20 |
|
$ |
8 |
|
$ |
30 |
|
Growth capital expenditures |
|
6 |
|
|
|
3 |
|
|
8 |
|
|
|
6 |
|
|
— |
|
|
21 |
|
Total capital expenditures |
$ |
28 |
|
|
$ |
10 |
|
$ |
39 |
|
|
$ |
26 |
|
$ |
8 |
|
$ |
51 |
| |
Nine Months Ended September 30, |
| |
|
2024 |
|
|
2023 |
| (in millions) |
Petroleum |
|
Nitrogen Fertilizer |
|
Consolidated |
|
Petroleum |
|
Nitrogen Fertilizer |
|
Consolidated |
|
Net sales |
$ |
5,165 |
|
$ |
386 |
|
$ |
5,663 |
|
$ |
6,290 |
|
$ |
540 |
|
$ |
7,045 |
| Operating income |
|
9 |
|
|
65 |
|
|
37 |
|
|
838 |
|
|
184 |
|
|
1,000 |
| Net income |
|
35 |
|
|
43 |
|
|
5 |
|
|
913 |
|
|
162 |
|
|
781 |
| EBITDA* |
|
152 |
|
|
129 |
|
|
271 |
|
|
989 |
|
|
243 |
|
|
1,231 |
| |
|
|
|
|
|
|
|
|
|
|
|
| Capital expenditures(1) |
|
|
|
|
|
|
|
|
|
|
|
|
Maintenance capital expenditures |
$ |
66 |
|
$ |
15 |
|
$ |
87 |
|
$ |
70 |
|
$ |
17 |
|
$ |
92 |
|
Growth capital expenditures |
|
31 |
|
|
4 |
|
|
43 |
|
|
9 |
|
|
1 |
|
|
56 |
|
Total capital expenditures |
$ |
97 |
|
$ |
19 |
|
$ |
130 |
|
$ |
79 |
|
$ |
18 |
|
$ |
148 |
_________________
* See “Non-GAAP Reconciliations” section
below.(1) Capital expenditures are shown exclusive
of capitalized turnaround expenditures.Selected Balance
Sheet Data
| |
September 30, 2024 |
|
December 31, 2023 |
| (in millions) |
Petroleum |
|
Nitrogen Fertilizer |
|
Consolidated |
|
Petroleum |
|
Nitrogen Fertilizer |
|
Consolidated |
|
Cash and cash equivalents |
$ |
275 |
|
$ |
111 |
|
$ |
534 |
|
$ |
375 |
|
$ |
45 |
|
$ |
581 |
| Total assets |
|
2,804 |
|
|
987 |
|
|
3,878 |
|
|
2,978 |
|
|
975 |
|
|
4,707 |
| Total debt and finance lease
obligations, including current portion(1) |
|
39 |
|
|
548 |
|
|
1,582 |
|
|
44 |
|
|
547 |
|
|
2,185 |
_________________
(1) Corporate total debt and
finance lease obligations, including current portion consisted of
$995 million and $1,594 million at September 30, 2024 and December
31, 2023, respectively.
Petroleum Segment
Key Operating Metrics per Total Throughput
Barrel
| |
Three Months EndedSeptember
30, |
|
Nine Months EndedSeptember
30, |
|
(in millions) |
|
2024 |
|
|
2023 |
|
|
2024 |
|
|
2023 |
| Refining margin * |
$ |
2.53 |
|
$ |
31.05 |
|
$ |
9.96 |
|
$ |
24.33 |
| Adjusted refining margin
* |
|
8.23 |
|
|
20.73 |
|
|
9.51 |
|
|
20.02 |
| Direct operating expenses
* |
|
5.72 |
|
|
5.39 |
|
|
6.14 |
|
|
5.58 |
_________________ * See “Non-GAAP Reconciliations” section
below.
Refining Throughput and Production Data by
Refinery
| Throughput
Data |
Three Months EndedSeptember
30, |
|
Nine Months EndedSeptember
30, |
|
(in bpd) |
2024 |
|
2023 |
|
2024 |
|
2023 |
| Coffeyville |
|
|
|
|
|
|
|
|
Gathered crude |
66,781 |
|
68,176 |
|
71,993 |
|
62,442 |
|
Other domestic |
35,111 |
|
49,303 |
|
36,549 |
|
47,491 |
|
Canadian |
6,243 |
|
2,731 |
|
8,423 |
|
2,307 |
|
Condensate |
— |
|
7,401 |
|
4,244 |
|
7,718 |
|
Other crude oil |
3,876 |
|
— |
|
1,484 |
|
— |
|
Other feedstocks and blendstocks |
11,691 |
|
12,260 |
|
11,678 |
|
12,538 |
| Wynnewood |
|
|
|
|
|
|
|
|
Gathered crude |
51,821 |
|
53,554 |
|
43,055 |
|
51,519 |
|
Other domestic |
1,504 |
|
543 |
|
1,309 |
|
1,822 |
|
Condensate |
9,663 |
|
15,780 |
|
8,634 |
|
14,567 |
|
Other feedstocks and blendstocks |
2,604 |
|
2,672 |
|
3,058 |
|
2,984 |
|
Total throughput |
189,294 |
|
212,420 |
|
190,427 |
|
203,388 |
| Production
Data |
Three Months EndedSeptember
30, |
|
Nine Months EndedSeptember
30, |
|
(in bpd) |
2024 |
|
|
2023 |
|
|
2024 |
|
|
2023 |
|
| Coffeyville |
|
|
|
|
|
|
|
|
Gasoline |
62,031 |
|
|
69,833 |
|
|
68,732 |
|
|
67,463 |
|
|
Distillate |
52,030 |
|
|
60,661 |
|
|
55,237 |
|
|
56,311 |
|
|
Other liquid products |
5,169 |
|
|
4,463 |
|
|
5,578 |
|
|
4,461 |
|
|
Solids |
4,734 |
|
|
4,416 |
|
|
4,901 |
|
|
3,896 |
|
| Wynnewood |
|
|
|
|
|
|
|
|
Gasoline |
34,539 |
|
|
36,997 |
|
|
30,746 |
|
|
37,656 |
|
|
Distillate |
23,902 |
|
|
25,615 |
|
|
19,722 |
|
|
24,825 |
|
|
Other liquid products |
5,874 |
|
|
9,038 |
|
|
4,600 |
|
|
7,355 |
|
|
Solids |
11 |
|
|
9 |
|
|
8 |
|
|
10 |
|
|
Total production |
188,290 |
|
|
211,032 |
|
|
189,524 |
|
|
201,977 |
|
| |
|
|
|
|
|
|
|
| Light product yield (as % of
crude throughput)(1) |
98.6 |
% |
|
97.8 |
% |
|
99.3 |
% |
|
99.1 |
% |
| Liquid volume yield (as % of
total throughput)(2) |
97.0 |
% |
|
97.3 |
% |
|
96.9 |
% |
|
97.4 |
% |
| Distillate yield (as % of
crude throughput)(3) |
43.4 |
% |
|
43.7 |
% |
|
42.7 |
% |
|
43.2 |
% |
_________________
(1) Total Gasoline and Distillate divided by total Gathered
crude, Other domestic, Canadian, and Condensate throughput
(collectively, “Total Crude Throughput”).(2) Total Gasoline,
Distillate, and Other liquid products divided by total
throughput.(3) Total Distillate divided by Total Crude
Throughput.
Key Market Indicators
| |
Three Months EndedSeptember
30, |
|
Nine Months EndedSeptember
30, |
|
|
|
2024 |
|
|
|
2023 |
|
|
|
2024 |
|
|
|
2023 |
|
| West Texas Intermediate (WTI)
NYMEX |
$ |
75.27 |
|
|
$ |
82.22 |
|
|
$ |
77.62 |
|
|
$ |
77.25 |
|
| Crude Oil Differentials to
WTI: |
|
|
|
|
|
|
|
|
Brent |
|
3.43 |
|
|
|
3.71 |
|
|
|
4.20 |
|
|
|
4.70 |
|
|
WCS (heavy sour) |
|
(13.84 |
) |
|
|
(15.91 |
) |
|
|
(14.43 |
) |
|
|
(16.33 |
) |
|
Condensate |
|
(0.32 |
) |
|
|
(0.22 |
) |
|
|
(0.60 |
) |
|
|
(0.18 |
) |
|
Midland Cushing |
|
0.78 |
|
|
|
1.53 |
|
|
|
1.14 |
|
|
|
1.32 |
|
| NYMEX Crack Spreads: |
|
|
|
|
|
|
|
|
Gasoline |
|
19.86 |
|
|
|
32.40 |
|
|
|
23.31 |
|
|
|
32.61 |
|
|
Heating Oil |
|
22.21 |
|
|
|
45.20 |
|
|
|
27.78 |
|
|
|
40.35 |
|
|
NYMEX 2-1-1 Crack Spread |
|
21.03 |
|
|
|
38.80 |
|
|
|
25.54 |
|
|
|
36.48 |
|
| PADD II Group 3 Product
Basis: |
|
|
|
|
|
|
|
|
Gasoline |
|
(1.77 |
) |
|
|
0.84 |
|
|
|
(7.43 |
) |
|
|
(2.39 |
) |
|
Ultra-Low Sulfur Diesel |
|
(1.51 |
) |
|
|
(0.25 |
) |
|
|
(5.15 |
) |
|
|
(0.38 |
) |
| PADD II Group 3 Product Crack
Spread: |
|
|
|
|
|
|
|
|
Gasoline |
|
18.09 |
|
|
|
33.24 |
|
|
|
15.88 |
|
|
|
30.22 |
|
|
Ultra-Low Sulfur Diesel |
|
20.70 |
|
|
|
44.96 |
|
|
|
22.62 |
|
|
|
39.97 |
|
| PADD II Group 3 2-1-1 |
|
19.40 |
|
|
|
39.10 |
|
|
|
19.25 |
|
|
|
35.10 |
|
Nitrogen Fertilizer Segment
Ammonia Utilization Rates
(1)
| |
Three Months EndedSeptember
30, |
|
Nine Months EndedSeptember
30, |
|
(percent of capacity utilization) |
2024 |
|
|
2023 |
|
|
2024 |
|
|
2023 |
|
| Consolidated |
97 |
% |
|
99 |
% |
|
96 |
% |
|
101 |
% |
_________________
(1) Reflects our ammonia utilization rates on a
consolidated basis. Utilization is an important measure used by
management to assess operational output at each of CVR Partners’
facilities. Utilization is calculated as actual tons produced
divided by capacity. We present our utilization for the three and
nine months ended September 30, 2024 and 2023 and take into account
the impact of our current turnaround cycles on any specific period.
Additionally, we present utilization solely on ammonia production
rather than each nitrogen product as it provides a comparative
baseline against industry peers and eliminates the disparity of
plant configurations for upgrade of ammonia into other nitrogen
products. With our efforts being primarily focused on ammonia
upgrade capabilities, this measure provides a meaningful view of
how well we operate.Sales and Production Data
| |
Three Months EndedSeptember
30, |
|
Nine Months EndedSeptember
30, |
|
|
|
2024 |
|
|
2023 |
|
|
2024 |
|
|
2023 |
| Consolidated sales volumes
(thousand tons): |
|
|
|
|
|
|
|
|
Ammonia |
|
62 |
|
|
62 |
|
|
175 |
|
|
183 |
|
UAN |
|
336 |
|
|
387 |
|
|
950 |
|
|
1,075 |
| |
|
|
|
|
|
|
|
| Consolidated product pricing
at gate (dollars per ton):(1) |
|
|
|
|
|
|
|
|
Ammonia |
$ |
399 |
|
$ |
365 |
|
$ |
481 |
|
$ |
633 |
|
UAN |
|
229 |
|
|
223 |
|
|
254 |
|
|
330 |
| |
|
|
|
|
|
|
|
| Consolidated production volume
(thousand tons): |
|
|
|
|
|
|
|
|
Ammonia(gross produced)(2) |
|
212 |
|
|
217 |
|
|
626 |
|
|
660 |
|
Ammonia(net available for sale)(2) |
|
61 |
|
|
68 |
|
|
191 |
|
|
200 |
|
UAN |
|
321 |
|
|
358 |
|
|
964 |
|
|
1,063 |
| |
|
|
|
|
|
|
|
| Feedstock: |
|
|
|
|
|
|
|
|
Petroleum coke used in production(thousands of tons) |
|
133 |
|
|
131 |
|
|
395 |
|
|
386 |
|
Petroleum coke used in production(dollars per ton) |
$ |
44.69 |
|
$ |
84.09 |
|
$ |
60.93 |
|
$ |
78.49 |
|
Natural gas used in production(thousands of MMBtus)(3) |
|
2,082 |
|
|
2,133 |
|
|
6,443 |
|
|
6,429 |
|
Natural gas used in production(dollars per MMBtu)(3) |
$ |
2.19 |
|
$ |
2.67 |
|
$ |
2.40 |
|
$ |
3.57 |
|
Natural gas in cost of materials and other(thousands of
MMBtus)(3) |
|
1,783 |
|
|
2,636 |
|
|
5,403 |
|
|
6,354 |
|
Natural gas in cost of materials and other(dollars per
MMBtu)(3) |
$ |
2.18 |
|
$ |
2.51 |
|
$ |
2.50 |
|
$ |
4.21 |
_________________
(1) Product pricing at gate represents sales
less freight revenue divided by product sales volume in tons and is
shown in order to provide a pricing measure that is comparable
across the fertilizer industry.(2) Gross tons produced for ammonia
represent total ammonia produced, including ammonia produced that
was upgraded into other fertilizer products. Net tons available for
sale represent ammonia available for sale that was not upgraded
into other fertilizer products.(3) The feedstock natural gas shown
above does not include natural gas used for fuel. The cost of fuel
natural gas is included in direct operating expense.
Key Market Indicators
| |
Three Months EndedSeptember
30, |
|
Nine Months EndedSeptember
30, |
|
|
|
2024 |
|
|
2023 |
|
|
2024 |
|
|
2023 |
| Ammonia — Southern
plains(dollars per ton) |
$ |
481 |
|
$ |
429 |
|
$ |
507 |
|
$ |
533 |
| Ammonia — Corn belt(dollars
per ton) |
|
529 |
|
|
501 |
|
|
550 |
|
|
621 |
| UAN — Corn belt(dollars per
ton) |
|
240 |
|
|
272 |
|
|
264 |
|
|
314 |
| |
|
|
|
|
|
|
|
| Natural gas NYMEX(dollars per
MMBtu) |
$ |
2.23 |
|
$ |
2.66 |
|
$ |
2.22 |
|
$ |
2.58 |
Q4 2024 Outlook
The table below summarizes our outlook for
certain operational statistics and financial information for the
fourth quarter of 2024. See “Forward-Looking Statements” above.
| |
Q4 2024 |
| |
Low |
|
High |
| Petroleum |
|
|
|
|
Total throughput(bpd) |
|
200,000 |
|
|
|
215,000 |
|
|
Direct operating expenses(in millions)(1) |
$ |
100 |
|
|
$ |
110 |
|
|
Turnaround(2) |
|
8 |
|
|
|
12 |
|
| |
|
|
|
| Renewables(3) |
|
|
|
|
Total throughput(in millions of gallons) |
|
17 |
|
|
|
22 |
|
|
Direct operating expenses(in millions)(1) |
$ |
9 |
|
|
$ |
11 |
|
| |
|
|
|
| Nitrogen Fertilizer |
|
|
|
|
Ammonia utilization rates |
|
|
|
|
Consolidated |
|
92 |
% |
|
|
97 |
% |
|
Coffeyville Fertilizer Facility |
|
90 |
% |
|
|
95 |
% |
|
East Dubuque Fertilizer Facility |
|
95 |
% |
|
|
100 |
% |
|
Direct operating expenses(in millions)(1) |
$ |
60 |
|
|
$ |
70 |
|
| |
|
|
|
| Capital Expenditures (in
millions)(2) |
|
|
|
|
Petroleum |
$ |
38 |
|
|
$ |
42 |
|
|
Renewables(3) |
|
1 |
|
|
|
2 |
|
|
Nitrogen Fertilizer |
|
19 |
|
|
|
23 |
|
|
Other |
|
1 |
|
|
|
3 |
|
|
Total capital expenditures |
$ |
59 |
|
|
$ |
70 |
|
_________________
(1) Direct operating expenses are shown
exclusive of depreciation and amortization, turnaround expenses,
and inventory valuation impacts.(2) Turnaround and capital
expenditures are disclosed on an accrual basis.(3) As of September
30, 2024, Renewables does not meet the definition of a reportable
segment as defined under Accounting Standards Codification 280.
Non-GAAP Reconciliations
Reconciliation of Net Income
to EBITDA and Adjusted EBITDA
| |
Three Months EndedSeptember
30, |
|
Nine Months EndedSeptember
30, |
|
(in millions) |
|
2024 |
|
|
|
2023 |
|
|
|
2024 |
|
|
|
2023 |
|
| Net (loss)
income |
$ |
(122 |
) |
|
$ |
354 |
|
|
$ |
5 |
|
|
$ |
781 |
|
|
Interest expense, net |
|
18 |
|
|
|
11 |
|
|
|
56 |
|
|
|
44 |
|
|
Income tax (benefit) expense |
|
(6 |
) |
|
|
84 |
|
|
|
(14 |
) |
|
|
185 |
|
|
Depreciation and amortization |
|
75 |
|
|
|
81 |
|
|
|
224 |
|
|
|
221 |
|
|
EBITDA |
|
(35 |
) |
|
|
530 |
|
|
|
271 |
|
|
|
1,231 |
|
| Adjustments: |
|
|
|
|
|
|
|
|
Revaluation of RFS liability, unfavorable (favorable) |
|
59 |
|
|
|
(174 |
) |
|
|
(32 |
) |
|
|
(228 |
) |
|
Unrealized loss on derivatives, net |
|
9 |
|
|
|
48 |
|
|
|
16 |
|
|
|
35 |
|
|
Inventory valuation impacts, unfavorable (favorable) |
|
30 |
|
|
|
(91 |
) |
|
|
(6 |
) |
|
|
(44 |
) |
|
Adjusted EBITDA |
$ |
63 |
|
|
$ |
313 |
|
|
$ |
249 |
|
|
$ |
994 |
|
Reconciliation of Basic and Diluted
(Loss) Earnings per Share to
Adjusted (Loss) Earnings per Share
| |
Three Months EndedSeptember
30, |
|
Nine Months EndedSeptember
30, |
|
|
|
2024 |
|
|
|
2023 |
|
|
|
2024 |
|
|
|
2023 |
|
| Basic and diluted
(loss) earnings per share |
$ |
(1.24 |
) |
|
$ |
3.51 |
|
|
$ |
(0.22 |
) |
|
$ |
6.74 |
|
| Adjustments:(1) |
|
|
|
|
|
|
|
|
Revaluation of RFS liability, unfavorable (favorable) |
|
0.44 |
|
|
|
(1.30 |
) |
|
|
(0.24 |
) |
|
|
(1.69 |
) |
|
Unrealized loss on derivatives, net |
|
0.07 |
|
|
|
0.36 |
|
|
|
0.12 |
|
|
|
0.26 |
|
|
Inventory valuation impacts, unfavorable (favorable) |
|
0.23 |
|
|
|
(0.68 |
) |
|
|
(0.04 |
) |
|
|
(0.33 |
) |
|
Adjusted (loss) earnings per share |
$ |
(0.50 |
) |
|
$ |
1.89 |
|
|
$ |
(0.38 |
) |
|
$ |
4.98 |
|
_________________
(1) Amounts are shown after-tax, using the Company’s marginal
tax rate, and are presented on a per share basis using the weighted
average shares outstanding for each period.
Reconciliation of Net Cash Provided By
Operating Activities to Free Cash
Flow
| |
Three Months EndedSeptember
30, |
|
Nine Months EndedSeptember
30, |
|
(in millions) |
|
2024 |
|
|
|
2023 |
|
|
|
2024 |
|
|
|
2023 |
|
| Net cash provided by
operating activities |
$ |
48 |
|
|
$ |
370 |
|
|
$ |
306 |
|
|
$ |
984 |
|
| Less: |
|
|
|
|
|
|
|
|
Capital expenditures |
|
(34 |
) |
|
|
(50 |
) |
|
|
(124 |
) |
|
|
(150 |
) |
|
Capitalized turnaround expenditures |
|
(2 |
) |
|
|
(3 |
) |
|
|
(46 |
) |
|
|
(53 |
) |
|
Return of equity method investment |
|
1 |
|
|
|
1 |
|
|
|
5 |
|
|
|
21 |
|
|
Free cash flow |
$ |
13 |
|
|
$ |
318 |
|
|
$ |
141 |
|
|
$ |
802 |
|
Reconciliation of Petroleum
Segment Net (Loss) Income to
EBITDA and Adjusted EBITDA
| |
Three Months EndedSeptember
30, |
|
Nine Months EndedSeptember
30, |
|
(in millions) |
|
2024 |
|
|
|
2023 |
|
|
|
2024 |
|
|
|
2023 |
|
| Petroleum net (loss)
income |
$ |
(110 |
) |
|
$ |
460 |
|
|
$ |
35 |
|
|
$ |
913 |
|
|
Interest income, net |
|
(5 |
) |
|
|
(26 |
) |
|
|
(16 |
) |
|
|
(65 |
) |
|
Depreciation and amortization |
|
40 |
|
|
|
50 |
|
|
|
133 |
|
|
|
141 |
|
|
Petroleum EBITDA |
|
(75 |
) |
|
|
484 |
|
|
|
152 |
|
|
|
989 |
|
| Adjustments: |
|
|
|
|
|
|
|
|
Revaluation of RFS liability, unfavorable (favorable) |
|
59 |
|
|
|
(174 |
) |
|
|
(32 |
) |
|
|
(228 |
) |
|
Unrealized loss on derivatives, net |
|
9 |
|
|
|
53 |
|
|
|
16 |
|
|
|
37 |
|
|
Inventory valuation impacts, unfavorable (favorable)(1) |
|
31 |
|
|
|
(82 |
) |
|
|
(8 |
) |
|
|
(48 |
) |
|
Petroleum Adjusted EBITDA |
$ |
24 |
|
|
$ |
281 |
|
|
$ |
128 |
|
|
$ |
750 |
|
Reconciliation of Petroleum
Segment Gross (Loss) Profit to
Refining Margin and Adjusted Refining Margin
| |
Three Months EndedSeptember
30, |
|
Nine Months EndedSeptember
30, |
|
(in millions) |
|
2024 |
|
|
|
2023 |
|
|
|
2024 |
|
|
|
2023 |
|
| Net
sales |
$ |
1,648 |
|
|
$ |
2,298 |
|
|
$ |
5,165 |
|
|
$ |
6,290 |
|
| Less: |
|
|
|
|
|
|
|
|
Cost of materials and other |
|
(1,604 |
) |
|
|
(1,691 |
) |
|
|
(4,645 |
) |
|
|
(4,939 |
) |
|
Direct operating expenses (exclusive of depreciation and
amortization) |
|
(100 |
) |
|
|
(105 |
) |
|
|
(320 |
) |
|
|
(310 |
) |
|
Depreciation and amortization |
|
(40 |
) |
|
|
(50 |
) |
|
|
(133 |
) |
|
|
(141 |
) |
|
Gross (loss) profit |
|
(96 |
) |
|
|
452 |
|
|
|
67 |
|
|
|
900 |
|
| Add: |
|
|
|
|
|
|
|
|
Direct operating expenses (exclusive of depreciation and
amortization) |
|
100 |
|
|
|
105 |
|
|
|
320 |
|
|
|
310 |
|
|
Depreciation and amortization |
|
40 |
|
|
|
50 |
|
|
|
133 |
|
|
|
141 |
|
|
Refining margin |
|
44 |
|
|
|
607 |
|
|
|
520 |
|
|
|
1,351 |
|
| Adjustments: |
|
|
|
|
|
|
|
|
Revaluation of RFS liability, unfavorable (favorable) |
|
59 |
|
|
|
(174 |
) |
|
|
(32 |
) |
|
|
(228 |
) |
|
Unrealized loss on derivatives, net |
|
9 |
|
|
|
53 |
|
|
|
16 |
|
|
|
37 |
|
|
Inventory valuation impacts, unfavorable (favorable)(1) |
|
31 |
|
|
|
(82 |
) |
|
|
(8 |
) |
|
|
(48 |
) |
|
Adjusted refining margin |
$ |
143 |
|
|
$ |
404 |
|
|
$ |
496 |
|
|
$ |
1,112 |
|
_________________
(1) The Petroleum Segment’s basis for
determining inventory value under GAAP is First-In, First-Out
(“FIFO”). Changes in crude oil prices can cause fluctuations in the
inventory valuation of crude oil, work in process and finished
goods, thereby resulting in a favorable inventory valuation impact
when crude oil prices increase and an unfavorable inventory
valuation impact when crude oil prices decrease. The inventory
valuation impact is calculated based upon inventory values at the
beginning of the accounting period and at the end of the accounting
period. In order to derive the inventory valuation impact per total
throughput barrel, we utilize the total dollar figures for the
inventory valuation impact and divide by the number of total
throughput barrels for the period.
Reconciliation of
Petroleum Segment Total Throughput Barrels
and Metrics per Total Throughput Barrel
| |
Three Months EndedSeptember
30, |
|
Nine Months EndedSeptember
30, |
|
|
|
2024 |
|
|
2023 |
|
|
2024 |
|
|
2023 |
| Total throughput barrels per
day |
|
189,294 |
|
|
212,420 |
|
|
190,427 |
|
|
203,388 |
| Days in the period |
|
92 |
|
|
92 |
|
|
274 |
|
|
273 |
|
Total throughput barrels |
|
17,415,033 |
|
|
19,542,631 |
|
|
52,176,994 |
|
|
55,524,925 |
| |
|
|
|
|
|
|
|
| (in millions, except per total
throughput barrel) |
|
|
|
|
|
|
|
| Refining margin |
$ |
44 |
|
$ |
607 |
|
$ |
520 |
|
$ |
1,351 |
| Refining margin per total
throughput barrel |
$ |
2.53 |
|
$ |
31.05 |
|
$ |
9.96 |
|
$ |
24.33 |
| |
|
|
|
|
|
|
|
| Adjusted refining margin |
$ |
143 |
|
$ |
404 |
|
$ |
496 |
|
$ |
1,112 |
| Adjusted refining margin per
total throughput barrel |
$ |
8.23 |
|
$ |
20.73 |
|
$ |
9.51 |
|
$ |
20.02 |
| |
|
|
|
|
|
|
|
| Direct operating expenses
(exclusive of depreciation and amortization) |
$ |
100 |
|
$ |
105 |
|
$ |
320 |
|
$ |
310 |
| Direct operating expenses per
total throughput barrel |
$ |
5.72 |
|
$ |
5.39 |
|
$ |
6.14 |
|
$ |
5.58 |
Reconciliation of Nitrogen Fertilizer
Segment Net Income to EBITDA and
Adjusted EBITDA
| |
Three Months EndedSeptember
30, |
|
Nine Months EndedSeptember
30, |
|
(in millions) |
|
2024 |
|
|
2023 |
|
|
2024 |
|
|
2023 |
| Nitrogen Fertilizer
net income |
$ |
4 |
|
$ |
1 |
|
$ |
43 |
|
$ |
162 |
|
Interest expense, net |
|
7 |
|
|
8 |
|
|
22 |
|
|
22 |
|
Depreciation and amortization |
|
25 |
|
|
23 |
|
|
64 |
|
|
59 |
|
Nitrogen Fertilizer EBITDA and Adjusted
EBITDA |
$ |
36 |
|
$ |
32 |
|
$ |
129 |
|
$ |
243 |
CVR Energy (NYSE:CVI)
過去 株価チャート
から 11 2024 まで 12 2024
CVR Energy (NYSE:CVI)
過去 株価チャート
から 12 2023 まで 12 2024
