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UNITED
STATES
SECURITIES
AND EXCHANGE COMMISSION
Washington,
D.C. 20549
FORM
8-K
CURRENT
REPORT
Pursuant
to Section 13 or 15(d)
of
the Securities Exchange Act of 1934
Date
of report (Date of earliest event reported): November 5, 2024
GULFPORT ENERGY CORPORATION
(Exact
Name of Registrant as Specified in Charter)
| Delaware |
|
001-19514 |
|
86-3684669 |
(State
or other jurisdiction
of incorporation) |
|
(Commission
File Number) |
|
(I.R.S.
Employer
Identification Number) |
713 Market Drive
Oklahoma City, Oklahoma |
|
73114 |
(Address
of principal
executive offices) |
|
(Zip
code) |
(405)
252-4600
(Registrant’s
telephone number, including area code)
(Former
name or former address, if changed since last report)
Check
the appropriate box below if the Form 8-K is intended to simultaneously satisfy the filing obligation of the Registrant under any of
the following provisions:
| ☐ |
Written
communications pursuant to Rule 425 under the Securities Act |
| ☐ |
Soliciting
material pursuant to Rule 14a-12 under the Exchange Act |
| ☐ |
Pre-commencement
communications pursuant to Rule 14d-2(b) under the Exchange Act |
| ☐ |
Pre-commencement
communications pursuant to Rule 13e-4(c) under the Exchange Act |
Securities
registered pursuant to Section 12(b) of the Act:
| Title
of each class |
|
Name
of each exchange on which registered |
|
Trading
Symbol |
| Common stock, par value $0.0001 per share |
|
The New York Stock Exchange |
|
GPOR |
Indicate
by check mark whether the registrant is an emerging growth company as defined in Rule 405 of the Securities Act of 1933 (§230.405
of this chapter) or Rule 12b-2 of the Securities Exchange Act of 1934 (§240.12b-2 of this chapter).
Emerging
growth company ☐
If
an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying
with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐
Item
2.02. Results of Operations and Financial Condition.
On
November 5, 2024, Gulfport Energy Corporation (“Gulfport”) issued a press release reporting its financial and operating results
for the three months ended September 30, 2024, and provided an update on its 2024 development plan and financial guidance. A copy of
the press release and supplemental financial information are attached as Exhibit 99.1 and Exhibit 99.2, respectively, to this Current
Report on Form 8-K.
Item
7.01. Regulation FD Disclosure.
Also
on November 5, 2024, Gulfport posted an updated investor presentation on its website. The presentation may be found on Gulfport’s
website at http://www.gulfportenergy.com by selecting “Investors,” “Company Information” and then “Presentations.”
The
information in the press release and updated investor presentation is being furnished, not filed, pursuant to Item 2.02 and Item 7.01.
Accordingly, the information in the press release and updated investor presentation will not be incorporated by reference into any registration
statement filed by Gulfport under the Securities Act of 1933, as amended, unless specifically identified therein as being incorporated
therein by reference.
Item
9.01. Financial Statements and Exhibits
(d)
Exhibits
SIGNATURE
Pursuant
to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by
the undersigned thereunto duly authorized.
| |
GULFPORT ENERGY CORPORATION |
| |
|
| Date: November 5, 2024 |
By: |
/s/
Michael Hodges |
| |
|
Michael Hodges |
| |
|
Chief Financial Officer |
2
Exhibit 99.1
Gulfport
Energy Reports Third Quarter 2024 Financial and Operating Results and Expands Common Stock Repurchase Authorization by 54% to $1.0 Billion
OKLAHOMA
CITY (November 5, 2024) Gulfport Energy Corporation (NYSE: GPOR) (“Gulfport” or the “Company”) today
reported financial and operating results for the three months ended September 30, 2024 and provided an update on its 2024 development
plan and financial guidance.
Third
Quarter 2024 and Recent Highlights
| ● | Delivered
total net production of 1.06 Bcfe per day comprised of approximately 91% natural gas, 6%
natural gas liquids and 3% oil and condensate |
| ● | Produced
total net oil production of 4.6 MBbl per day, an increase of 68% over second quarter 2024 |
| ● | Incurred
capital expenditures of $82.5 million, below analyst consensus expectations |
| ● | Reported
$14.0 million of net loss, $61.8 million of adjusted net income(1) and $178.1
million of adjusted EBITDA(1), above analyst consensus expectations |
| ● | Generated
$189.7 million of net cash provided by operating activities and $72.6 million of adjusted
free cash flow(1), above analyst consensus expectations |
| ● | Completed
opportunistic discretionary acreage acquisitions totaling $19.8 million |
| ● | Repurchased
approximately 341 thousand shares for approximately $49.9 million during the third quarter
of 2024 |
| ● | Repurchased
approximately 5.2 million shares for approximately $518.7 million(2) since the
inception of the repurchase program |
| ● | Expanded
common stock repurchase authorization by 54% percent to $1.0 billion |
| ● | Extended
the weighted average maturity of the Company’s long-term senior notes by 3.2 years
and lowered the Company’s weighted average interest rate on its long-term senior notes
by approximately 1.2% |
| ● | Completed
fall borrowing base redetermination of revolving credit facility, which resulted in (1) increase
in elected commitments to $1.0 billion, (2) borrowing base reaffirmed at $1.1 billion and
(3) extension of the maturity to September 2028 |
| ● | Issued
Annual Corporate Sustainability Report and remain committed to delivering cleaner, lower-carbon
energy in a safe, environmentally responsible manner |
Updated
Full Year 2024 Outlook
| ● | Reducing
guidance for drilling and completion capital expenditures to $325 million – $335 million,
a decrease of 4% based upon the midpoint of the Company’s previously issued guidance
range |
| ● | Planning
to allocate approximately $45 million to targeted discretionary acreage acquisitions, of
which $38.8 million was deployed by the end of the third quarter of 2024 |
| ● | Reiterating
plans to allocate substantially all 2024 adjusted free cash flow(1) towards common
share repurchases after discretionary acreage acquisitions |
John
Reinhart, President and CEO, commented, “Gulfport’s third quarter results continued to benefit from the operating momentum
that we have built throughout this year and as we announced in August, the Company expects to realize over $25 million in capital savings
on our drilling and completion activities during 2024. Based on the current commodity price environment, we have elected to allocate
the majority of these savings to incremental shareholder returns through our recently expanded common share repurchase program. As a
result, we are lowering our full year 2024 capital guidance.”
Reinhart
continued, “We continued to add to our attractive acreage portfolio and, through September 30, we invested $38.8 million in discretionary
acreage acquisition opportunities during 2024, extending our high-quality, liquids-rich inventory by approximately one year. In addition,
production and cash flows for the third quarter benefited from the turn-in-line of our four-well Utica condensate pad in Harrison County,
Ohio, increasing our average daily oil production by 68% quarter-over-quarter. The wells have exhibited attractive production rates in
combination with minimal pressure drawdown during the initial 90-day period. Increased production rates are now being tested to determine
the optimal production profile aimed at maximizing long-term well performance. The Company also completed drilling on four additional
Utica condensate wells during the third quarter and look forward to further development of our Marcellus acreage in early 2025, highlighting
the liquids optionality and flexibility of our asset base as well as the continuous optimization of our development program targeting
improved returns.”
“As
we close out 2024 and expect an improving 2025 natural gas macro environment, we forecast accelerating adjusted free cash flow generation
for our business, highlighting our disciplined approach to capital allocation and our focus on enhancing margins and optimizing efficiencies.
Based entirely on the capital efficiency gains achieved over the past two years, we expect 2025 total base capital requirements to be
in line with our updated 2024 capital guidance provided today. This capital program will continue to focus on liquids-rich development,
improving margins and supporting our robust expected adjusted free cash flow generation. We will continue to focus on increasing shareholder
value and believe our stock remains undervalued. As a result, we are pleased to announce a significant increase in our common stock repurchase
authorization by 54% to $1.0 billion, which highlights our commitment to the return of capital to our shareholders. We plan to remain
consistent in our free cash flow allocation framework and will continue to return substantially all of our adjusted free cash flow, excluding
discretionary acreage acquisitions, through common stock repurchases. We believe the consistency of our committed approach to share repurchases
over the past few years has delivered tremendous value to our shareholders and changes to our capital allocation framework, or other
potential strategic considerations, would need to be accretive to our fundamental value and compare favorably to repurchasing our undervalued
stock,” Reinhart concluded.
A
company presentation to accompany the Gulfport earnings conference call can be accessed by clicking here.
| 1. | A
non-GAAP financial measure. Reconciliations of these non-GAAP measures and other disclosures
are provided with the supplemental financial tables available on our website at www.gulfportenergy.com. |
| 2. | As
of October 28, 2024. |
Operational
Update
The
table below summarizes Gulfport's operated drilling and completion activity for the third quarter of 2024:
| | |
Quarter Ended September 30, 2024 | |
| | |
Gross | | |
Net | | |
Lateral Length | |
| Spud | |
| | |
| | |
| |
| Utica | |
| 3 | | |
| 3.0 | | |
| 18,800 | |
| SCOOP | |
| — | | |
| — | | |
| — | |
| | |
| | | |
| | | |
| | |
| Drilled | |
| | | |
| | | |
| | |
| Utica | |
| 5 | | |
| 5.0 | | |
| 13,100 | |
| SCOOP | |
| — | | |
| — | | |
| — | |
| | |
| | | |
| | | |
| | |
| Completed | |
| | | |
| | | |
| | |
| Utica | |
| 3 | | |
| 3.0 | | |
| 14,300 | |
| SCOOP | |
| 3 | | |
| 2.4 | | |
| 12,400 | |
| | |
| | | |
| | | |
| | |
| Turned-to-Sales | |
| | | |
| | | |
| | |
| Utica | |
| 7 | | |
| 6.6 | | |
| 16,000 | |
| SCOOP | |
| 3 | | |
| 2.4 | | |
| 12,400 | |
Gulfport’s
net daily production for the third quarter of 2024 averaged 1,057.2 MMcfe per day, primarily consisting of 861.6 MMcfe per day in the
Utica/Marcellus and 195.6 MMcfe per day in the SCOOP. For the third quarter of 2024, Gulfport’s net daily production mix was comprised
of approximately 91% natural gas, 6% natural gas liquids ("NGL") and 3% oil and condensate.
| | |
Three Months
Ended
September 30,
2024 | | |
Three Months
Ended
September 30,
2023 | |
| Production | |
| | |
| |
| Natural gas (Mcf/day) | |
| 966,522 | | |
| 971,352 | |
| Oil and condensate (Bbl/day) | |
| 4,618 | | |
| 3,195 | |
| NGL (Bbl/day) | |
| 10,489 | | |
| 11,061 | |
| Total (Mcfe/day) | |
| 1,057,164 | | |
| 1,056,887 | |
| Average Prices | |
| | | |
| | |
| Natural Gas: | |
| | | |
| | |
| Average price without the impact of derivatives ($/Mcf) | |
$ | 1.80 | | |
$ | 1.99 | |
| Impact from settled derivatives ($/Mcf) | |
$ | 0.95 | | |
$ | 0.54 | |
| Average price, including settled derivatives ($/Mcf) | |
$ | 2.75 | | |
$ | 2.53 | |
| Oil and condensate: | |
| | | |
| | |
| Average price without the impact of derivatives ($/Bbl) | |
$ | 69.35 | | |
$ | 77.90 | |
| Impact from settled derivatives ($/Bbl) | |
$ | 0.22 | | |
$ | (7.25 | ) |
| Average price, including settled derivatives ($/Bbl) | |
$ | 69.57 | | |
$ | 70.65 | |
| NGL: | |
| | | |
| | |
| Average price without the impact of derivatives ($/Bbl) | |
$ | 27.58 | | |
$ | 26.49 | |
| Impact from settled derivatives ($/Bbl) | |
$ | (0.16 | ) | |
$ | 2.62 | |
| Average price, including settled derivatives ($/Bbl) | |
$ | 27.42 | | |
$ | 29.11 | |
| Total: | |
| | | |
| | |
| Average price without the impact of derivatives ($/Mcfe) | |
$ | 2.22 | | |
$ | 2.34 | |
| Impact from settled derivatives ($/Mcfe) | |
$ | 0.87 | | |
$ | 0.50 | |
| Average price, including settled derivatives ($/Mcfe) | |
$ | 3.09 | | |
$ | 2.84 | |
| Selected operating metrics | |
| | | |
| | |
| Lease operating expenses ($/Mcfe) | |
$ | 0.19 | | |
$ | 0.16 | |
| Taxes other than income ($/Mcfe) | |
$ | 0.07 | | |
$ | 0.07 | |
| Transportation, gathering, processing and compression expense ($/Mcfe) | |
$ | 0.92 | | |
$ | 0.89 | |
| Recurring cash general and administrative expenses ($/Mcfe) (non-GAAP) | |
$ | 0.13 | | |
$ | 0.12 | |
| Interest expenses ($/Mcfe) | |
$ | 0.16 | | |
$ | 0.15 | |
Capital
Investment
Capital
investment was $82.5 million (on an incurred basis) for the third quarter of 2024, of which $64.9 million related to drilling and
completion (“D&C”) activity and $17.6 million related to maintenance leasehold and land investment. In addition, Gulfport
invested approximately $19.8 million in discretionary acreage acquisitions.
For
the nine-month period ended September 30, 2024, capital investment was $329.0 million (on an incurred basis), of which $277.4
million related to D&C activity and $51.6 million to maintenance leasehold and land investment. In addition, Gulfport invested approximately
$38.8 million in discretionary acreage acquisitions.
Expanded
Common Stock Repurchase Program
Gulfport's
board of directors recently expanded the Company's previously announced common stock repurchase program and Gulfport is now authorized
to repurchase up to $1.0 billion of its outstanding shares of common stock through December 31, 2025.
Gulfport
repurchased approximately 341 thousand shares of common stock at a weighted-average price of $146.17 during the third quarter of 2024,
totaling approximately $49.9 million. As of October 28, 2024, the Company had repurchased approximately 5.2 million shares of common
stock at a weighted-average share price of $100.17 since the program initiated in March 2022, totaling approximately $518.7 million in
aggregate. The Company currently has approximately $481.3 million of remaining capacity under the expanded share repurchase program.
Financial
Position and Liquidity
As
of September 30, 2024, Gulfport had approximately $3.2 million of cash and cash equivalents, $30.0 million of borrowings under
its revolving credit facility, $63.8 million of letters of credit outstanding, $25.7 million of outstanding 2026 senior notes
and $650.0 million of outstanding 2029 senior notes.
Gulfport’s
liquidity at September 30, 2024, totaled approximately $909.4 million, comprised of the $3.2 million of cash and cash equivalents
and approximately $906.2 million of available borrowing capacity under its credit facility.
Derivatives
Gulfport
enters into commodity derivative contracts on a portion of its expected future production volumes to mitigate the Company's exposure
to commodity price fluctuations. For details, please refer to the "Derivatives" section provided with the supplemental financial
tables available on our website at ir.gulfportenergy.com.
Third
Quarter 2024 Conference Call
Gulfport
will host a teleconference and webcast to discuss its third quarter of 2024 results beginning at 9:00 a.m. ET (8:00 a.m. CT) on Wednesday,
November 6, 2024.
The
conference call can be heard live through a link on the Gulfport website, www.gulfportenergy.com. In addition, you may participate in
the conference call by dialing 866-373-3408 domestically or 412-902-1039 internationally. A replay of the conference call will be available
on the Gulfport website and a telephone audio replay will be available from November 6, 2024 to November 20, 2024, by calling
877-660-6853 domestically or 201-612-7415 internationally and then entering the replay passcode 13749355.
Financial
Statements and Guidance Documents
Third
quarter of 2024 earnings results and supplemental information regarding quarterly data such as production volumes, pricing, financial
statements and non-GAAP reconciliations are available on our website at ir.gulfportenergy.com.
Non-GAAP
Disclosures
This
news release includes non-GAAP financial measures. Such non-GAAP measures should be not considered as an alternative to GAAP measures.
Reconciliations of these non-GAAP measures and other disclosures are provided with the supplemental financial tables available on our
website at ir.gulfportenergy.com.
About
Gulfport
Gulfport
is an independent natural gas-weighted exploration and production company focused on the exploration, acquisition and production of natural
gas, crude oil and NGL in the United States with primary focus in the Appalachia and Anadarko basins. Our principal properties are located
in eastern Ohio targeting the Utica and Marcellus formations and in central Oklahoma targeting the SCOOP Woodford and SCOOP Springer
formations.
Forward
Looking Statements
This
press release includes “forward-looking statements” for purposes of the safe harbor provisions of the Private Securities
Litigation Reform Act of 1995, Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act
of 1934. Forward-looking statements are statements other than statements of historical fact. They include statements regarding Gulfport’s
current expectations, management's outlook guidance or forecasts of future events, projected cash flow and liquidity, inflation, share
repurchases and other return of capital plans, its ability to enhance cash flow and financial flexibility, future production and commodity
mix, plans and objectives for future operations, the ability of our employees, portfolio strength and operational leadership to create
long-term value and the assumptions on which such statements are based. Gulfport believes the expectations and forecasts reflected in
the forward-looking statements are reasonable, Gulfport can give no assurance they will prove to have been correct. They can be affected
by inaccurate or changed assumptions or by known or unknown risks and uncertainties. Important risks, assumptions and other important
factors that could cause future results to differ materially from those expressed in the forward-looking statements are described under
"Risk Factors" in Item 1A of Gulfport’s annual report on Form 10-K for the year ended December 31, 2023 and any
updates to those factors set forth in Gulfport's subsequent quarterly reports on Form 10-Q or current reports on Form 8-K (available
at https://www.gulfportenergy.com/investors/sec-filings). Gulfport undertakes no obligation to release publicly any revisions to any
forward-looking statements, to report events or to report the occurrence of unanticipated events.
Investors
should note that Gulfport announces financial information in SEC filings, press releases and public conference calls. Gulfport
may use the Investors section of its website (www.gulfportenergy.com) to communicate with investors. It is possible that the financial
and other information posted there could be deemed to be material information. The information on Gulfport’s website is not
part of this filing.
Investor
Contact:
Jessica
Antle – Vice President, Investor Relations
jantle@gulfportenergy.com
405-252-4550
6
Exhibit 99.2
Three months and nine months ended September 30,
2024
Supplemental Information of Gulfport Energy
| Table of Contents: |
|
Page: |
| Production Volumes by Asset Area |
|
2 |
| Production and Pricing |
|
4 |
| Consolidated Statements of Income |
|
6 |
| Consolidated Balance Sheets |
|
8 |
| Consolidated Statement of Cash Flows |
|
10 |
| Updated 2024E Guidance |
|
12 |
| Derivatives |
|
13 |
| Non-GAAP Reconciliations |
|
14 |
| Definitions |
|
15 |
| Adjusted Net Income |
|
16 |
| Adjusted EBITDA |
|
18 |
| Adjusted Free Cash Flow |
|
20 |
| Recurring General and Administrative Expenses |
|
22 |
Production Volumes by Asset Area: Three months ended September 30,
2024
Production Volumes
| | |
Three Months Ended
September 30, 2024 | | |
Three Months Ended
September 30, 2023 | |
| Natural gas (Mcf/day) | |
| | |
| |
| Utica & Marcellus | |
| 822,015 | | |
| 795,191 | |
| SCOOP | |
| 144,507 | | |
| 176,161 | |
| Total | |
| 966,522 | | |
| 971,352 | |
| Oil and condensate (Bbl/day) | |
| | | |
| | |
| Utica & Marcellus | |
| 3,105 | | |
| 528 | |
| SCOOP | |
| 1,513 | | |
| 2,667 | |
| Total | |
| 4,618 | | |
| 3,195 | |
| NGL (Bbl/day) | |
| | | |
| | |
| Utica & Marcellus | |
| 3,491 | | |
| 2,271 | |
| SCOOP | |
| 6,998 | | |
| 8,790 | |
| Total | |
| 10,489 | | |
| 11,061 | |
| Combined (Mcfe/day) | |
| | | |
| | |
| Utica & Marcellus | |
| 861,592 | | |
| 811,985 | |
| SCOOP | |
| 195,572 | | |
| 244,902 | |
| Total | |
| 1,057,164 | | |
| 1,056,887 | |
| Totals may not sum or recalculate due to rounding. | |
| | | |
| | |
Production Volumes by Asset Area: Nine months ended September 30,
2024
Production Volumes
| | |
Nine Months Ended
September 30, 2024 | | |
Nine Months Ended
September 30, 2023 | |
| Natural gas (Mcf/day) | |
| | |
| |
| Utica & Marcellus | |
| 816,788 | | |
| 755,372 | |
| SCOOP | |
| 154,054 | | |
| 198,616 | |
| Total | |
| 970,842 | | |
| 953,989 | |
| Oil and condensate (Bbl/day) | |
| | | |
| | |
| Utica & Marcellus | |
| 1,815 | | |
| 558 | |
| SCOOP | |
| 1,754 | | |
| 3,256 | |
| Total | |
| 3,569 | | |
| 3,813 | |
| NGL (Bbl/day) | |
| | | |
| | |
| Utica & Marcellus | |
| 2,610 | | |
| 2,466 | |
| SCOOP | |
| 7,629 | | |
| 9,921 | |
| Total | |
| 10,239 | | |
| 12,387 | |
| Combined (Mcfe/day) | |
| | | |
| | |
| Utica & Marcellus | |
| 843,339 | | |
| 773,512 | |
| SCOOP | |
| 210,348 | | |
| 277,676 | |
| Total | |
| 1,053,687 | | |
| 1,051,188 | |
| Totals may not sum or recalculate due to rounding. | |
| | | |
| | |
Production and Pricing: Three months ended September 30, 2024
The following table summarizes production and related pricing for
the three months ended September 30, 2024, as compared to such data for the three months ended September 30, 2023. Some totals
below may not sum or recalculate due to rounding.
| | |
Three Months Ended
September 30, 2024 | | |
Three Months Ended
September 30, 2023 | |
| Natural gas sales | |
| | |
| |
| Natural gas production volumes (MMcf) | |
| 88,920 | | |
| 89,364 | |
| Natural gas production volumes (MMcf) per day | |
| 967 | | |
| 971 | |
| Total sales | |
$ | 159,862 | | |
$ | 177,401 | |
| Average price without the impact of derivatives ($/Mcf) | |
$ | 1.80 | | |
$ | 1.99 | |
| Impact from settled derivatives ($/Mcf) | |
$ | 0.95 | | |
$ | 0.54 | |
| Average price, including settled derivatives ($/Mcf) | |
$ | 2.75 | | |
$ | 2.53 | |
| | |
| | | |
| | |
| Oil and condensate sales | |
| | | |
| | |
| Oil and condensate production volumes (MBbl) | |
| 425 | | |
| 294 | |
| Oil and condensate production volumes (MBbl) per day | |
| 5 | | |
| 3 | |
| Total sales | |
$ | 29,467 | | |
$ | 22,896 | |
| Average price without the impact of derivatives ($/Bbl) | |
$ | 69.35 | | |
$ | 77.90 | |
| Impact from settled derivatives ($/Bbl) | |
$ | 0.22 | | |
$ | (7.25 | ) |
| Average price, including settled derivatives ($/Bbl) | |
$ | 69.57 | | |
$ | 70.65 | |
| | |
| | | |
| | |
| NGL sales | |
| | | |
| | |
| NGL production volumes (MBbl) | |
| 965 | | |
| 1,018 | |
| NGL production volumes (MBbl) per day | |
| 10 | | |
| 11 | |
| Total sales | |
$ | 26,617 | | |
$ | 26,953 | |
| Average price without the impact of derivatives ($/Bbl) | |
$ | 27.58 | | |
$ | 26.49 | |
| Impact from settled derivatives ($/Bbl) | |
$ | (0.16 | ) | |
$ | 2.62 | |
| Average price, including settled derivatives ($/Bbl) | |
$ | 27.42 | | |
$ | 29.11 | |
| | |
| | | |
| | |
| Natural gas, oil and condensate and NGL sales | |
| | | |
| | |
| Natural gas equivalents (MMcfe) | |
| 97,259 | | |
| 97,234 | |
| Natural gas equivalents (MMcfe) per day | |
| 1,057 | | |
| 1,057 | |
| Total sales | |
$ | 215,946 | | |
$ | 227,250 | |
| Average price without the impact of derivatives ($/Mcfe) | |
$ | 2.22 | | |
$ | 2.34 | |
| Impact from settled derivatives ($/Mcfe) | |
$ | 0.87 | | |
$ | 0.50 | |
| Average price, including settled derivatives ($/Mcfe) | |
$ | 3.09 | | |
$ | 2.84 | |
| | |
| | | |
| | |
| Production Costs: | |
| | | |
| | |
| Average lease operating expenses ($/Mcfe) | |
$ | 0.19 | | |
$ | 0.16 | |
| Average taxes other than income ($/Mcfe) | |
$ | 0.07 | | |
$ | 0.07 | |
| Average transportation, gathering, processing and compression ($/Mcfe) | |
$ | 0.92 | | |
$ | 0.89 | |
| Total lease operating expenses, midstream costs and production taxes ($/Mcfe) | |
$ | 1.18 | | |
$ | 1.12 | |
Production and Pricing: Nine months ended September 30, 2024
The following table summarizes production and related pricing for
the nine months ended September 30, 2024, as compared to such data for the nine months ended September 30, 2023. Some totals
below may not sum or recalculate due to rounding.
| | |
Nine Months Ended
September 30, 2024 | | |
Nine Months Ended
September 30, 2023 | |
| Natural gas sales | |
| | |
| |
| Natural gas production volumes (MMcf) | |
| 266,011 | | |
| 260,439 | |
| Natural gas production volumes (MMcf) per day | |
| 971 | | |
| 954 | |
| Total sales | |
$ | 492,606 | | |
$ | 619,181 | |
| Average price without the impact of derivatives ($/Mcf) | |
$ | 1.85 | | |
$ | 2.38 | |
| Impact from settled derivatives ($/Mcf) | |
$ | 0.91 | | |
$ | 0.37 | |
| Average price, including settled derivatives ($/Mcf) | |
$ | 2.76 | | |
$ | 2.75 | |
| | |
| | | |
| | |
| Oil and condensate sales | |
| | | |
| | |
| Oil and condensate production volumes (MBbl) | |
| 978 | | |
| 1,041 | |
| Oil and condensate production volumes (MBbl) per day | |
| 4 | | |
| 4 | |
| Total sales | |
$ | 70,295 | | |
$ | 76,212 | |
| Average price without the impact of derivatives ($/Bbl) | |
$ | 71.89 | | |
$ | 73.21 | |
| Impact from settled derivatives ($/Bbl) | |
$ | (0.17 | ) | |
$ | (2.29 | ) |
| Average price, including settled derivatives ($/Bbl) | |
$ | 71.72 | | |
$ | 70.92 | |
| | |
| | | |
| | |
| NGL sales | |
| | | |
| | |
| NGL production volumes (MBbl) | |
| 2,805 | | |
| 3,382 | |
| NGL production volumes (MBbl) per day | |
| 10 | | |
| 12 | |
| Total sales | |
$ | 80,870 | | |
$ | 92,935 | |
| Average price without the impact of derivatives ($/Bbl) | |
$ | 28.83 | | |
$ | 27.48 | |
| Impact from settled derivatives ($/Bbl) | |
$ | (0.55 | ) | |
$ | 1.88 | |
| Average price, including settled derivatives ($/Bbl) | |
$ | 28.28 | | |
$ | 29.36 | |
| | |
| | | |
| | |
| Natural gas, oil and condensate and NGL sales | |
| | | |
| | |
| Natural gas equivalents (MMcfe) | |
| 288,710 | | |
| 286,974 | |
| Natural gas equivalents (MMcfe) per day | |
| 1,054 | | |
| 1,051 | |
| Total sales | |
$ | 643,771 | | |
$ | 788,328 | |
| Average price without the impact of derivatives ($/Mcfe) | |
$ | 2.23 | | |
$ | 2.75 | |
| Impact from settled derivatives ($/Mcfe) | |
$ | 0.83 | | |
$ | 0.35 | |
| Average price, including settled derivatives ($/Mcfe) | |
$ | 3.06 | | |
$ | 3.10 | |
| | |
| | | |
| | |
| Production Costs: | |
| | | |
| | |
| Average lease operating expenses ($/Mcfe) | |
$ | 0.18 | | |
$ | 0.18 | |
| Average taxes other than income ($/Mcfe) | |
$ | 0.08 | | |
$ | 0.09 | |
| Average transportation, gathering, processing and compression ($/Mcfe) | |
$ | 0.91 | | |
$ | 0.91 | |
| Total lease operating expenses, midstream costs and production taxes ($/Mcfe) | |
$ | 1.16 | | |
$ | 1.18 | |
Consolidated Statements of Income: Three months ended September 30,
2024
(In thousands, except per share data)
(Unaudited)
| | |
Three Months Ended
September 30, 2024 | | |
Three Months Ended
September 30, 2023 | |
| REVENUES: | |
| | |
| |
| Natural gas sales | |
$ | 159,862 | | |
$ | 177,401 | |
| Oil and condensate sales | |
| 29,467 | | |
| 22,896 | |
| Natural gas liquid sales | |
| 26,617 | | |
| 26,953 | |
| Net gain on natural gas, oil and NGL derivatives | |
| 37,966 | | |
| 39,417 | |
| Total revenues | |
| 253,912 | | |
| 266,667 | |
| OPERATING EXPENSES: | |
| | | |
| | |
| Lease operating expenses | |
| 18,218 | | |
| 15,627 | |
| Taxes other than income | |
| 6,833 | | |
| 7,216 | |
| Transportation, gathering, processing and compression | |
| 89,900 | | |
| 86,602 | |
| Depreciation, depletion and amortization | |
| 82,825 | | |
| 79,505 | |
| Impairment of oil and natural gas properties | |
| 30,487 | | |
| — | |
| General and administrative expenses | |
| 10,479 | | |
| 9,894 | |
| Accretion expense | |
| 583 | | |
| 639 | |
| Total operating expenses | |
| 239,325 | | |
| 199,483 | |
| INCOME FROM OPERATIONS | |
| 14,587 | | |
| 67,184 | |
| OTHER EXPENSE (INCOME): | |
| | | |
| | |
| Interest expense | |
| 15,866 | | |
| 14,919 | |
| Loss on debt extinguishment | |
| 13,388 | | |
| — | |
| Other, net | |
| 3,133 | | |
| (1,438 | ) |
| Total other expense | |
| 32,387 | | |
| 13,481 | |
| (LOSS) INCOME BEFORE INCOME TAXES | |
| (17,800 | ) | |
| 53,703 | |
| INCOME TAX BENEFIT: | |
| | | |
| | |
| Current | |
| — | | |
| — | |
| Deferred | |
| (3,833 | ) | |
| (554,741 | ) |
| Total income tax benefit | |
| (3,833 | ) | |
| (554,741 | ) |
| NET (LOSS) INCOME | |
$ | (13,967 | ) | |
$ | 608,444 | |
| Dividends on preferred stock | |
| (1,093 | ) | |
| (1,133 | ) |
| Participating securities - preferred stock | |
| — | | |
| (89,756 | ) |
| NET (LOSS) INCOME ATTRIBUTABLE TO COMMON STOCKHOLDERS | |
$ | (15,060 | ) | |
$ | 517,555 | |
| NET (LOSS) INCOME PER COMMON SHARE: | |
| | | |
| | |
| Basic | |
$ | (0.83 | ) | |
$ | 27.72 | |
| Diluted | |
$ | (0.83 | ) | |
$ | 27.37 | |
| Weighted average common shares outstanding—Basic | |
| 18,062 | | |
| 18,670 | |
| Weighted average common shares outstanding—Diluted | |
| 18,062 | | |
| 18,954 | |
Consolidated Statements of Income: Nine months ended September 30,
2024
(In thousands, except per share data)
(Unaudited)
| | |
Nine Months Ended
September 30, 2024 | | |
Nine Months Ended
September 30, 2023 | |
| REVENUES: | |
| | |
| |
| Natural gas sales | |
$ | 492,606 | | |
$ | 619,181 | |
| Oil and condensate sales | |
| 70,295 | | |
| 76,212 | |
| Natural gas liquid sales | |
| 80,870 | | |
| 92,935 | |
| Net gain on natural gas, oil and NGL derivatives | |
| 74,487 | | |
| 514,266 | |
| Total revenues | |
| 718,258 | | |
| 1,302,594 | |
| OPERATING EXPENSES: | |
| | | |
| | |
| Lease operating expenses | |
| 50,843 | | |
| 51,644 | |
| Taxes other than income | |
| 22,111 | | |
| 25,849 | |
| Transportation, gathering, processing and compression | |
| 263,048 | | |
| 259,883 | |
| Depreciation, depletion and amortization | |
| 241,401 | | |
| 238,747 | |
| Impairment of oil and natural gas properties | |
| 30,487 | | |
| — | |
| General and administrative expenses | |
| 30,429 | | |
| 27,238 | |
| Restructuring costs | |
| — | | |
| 4,762 | |
| Accretion expense | |
| 1,705 | | |
| 2,117 | |
| Total operating expenses | |
| 640,024 | | |
| 610,240 | |
| INCOME FROM OPERATIONS | |
| 78,234 | | |
| 692,354 | |
| OTHER EXPENSE (INCOME): | |
| | | |
| | |
| Interest expense | |
| 46,027 | | |
| 42,402 | |
| Loss on debt extinguishment | |
| 13,388 | | |
| — | |
| Other, net | |
| 3,530 | | |
| (20,492 | ) |
| Total other expense | |
| 62,945 | | |
| 21,910 | |
| INCOME BEFORE INCOME TAXES | |
| 15,289 | | |
| 670,444 | |
| INCOME TAX EXPENSE (BENEFIT): | |
| | | |
| | |
| Current | |
| — | | |
| — | |
| Deferred | |
| 3,433 | | |
| (554,741 | ) |
| Total income tax expense (benefit) | |
| 3,433 | | |
| (554,741 | ) |
| NET INCOME | |
$ | 11,856 | | |
$ | 1,225,185 | |
| Dividends on preferred stock | |
| (3,293 | ) | |
| (3,718 | ) |
| Participating securities - preferred stock | |
| (1,259 | ) | |
| (180,394 | ) |
| NET INCOME ATTRIBUTABLE TO COMMON STOCKHOLDERS | |
$ | 7,304 | | |
$ | 1,041,073 | |
| NET INCOME PER COMMON SHARE: | |
| | | |
| | |
| Basic | |
$ | 0.40 | | |
$ | 55.72 | |
| Diluted | |
$ | 0.40 | | |
$ | 55.08 | |
| Weighted average common shares outstanding—Basic | |
| 18,133 | | |
| 18,686 | |
| Weighted average common shares outstanding—Diluted | |
| 18,463 | | |
| 18,937 | |
Consolidated Balance Sheets
(In thousands)
| | |
September 30, 2024 | | |
December 31, 2023 | |
| |
(Unaudited) | | |
| |
| Assets | |
| | |
| |
| Current assets: | |
| | |
| |
| Cash and cash equivalents | |
$ | 3,220 | | |
$ | 1,929 | |
| Accounts receivable—oil, natural gas, and natural gas liquids sales | |
| 88,931 | | |
| 122,479 | |
| Accounts receivable—joint interest and other | |
| 14,274 | | |
| 22,221 | |
| Prepaid expenses and other current assets | |
| 5,944 | | |
| 16,951 | |
| Short-term derivative instruments | |
| 111,076 | | |
| 233,226 | |
| Total current assets | |
| 223,445 | | |
| 396,806 | |
| Property and equipment: | |
| | | |
| | |
| Oil and natural gas properties, full-cost method | |
| | | |
| | |
| Proved oil and natural gas properties | |
| 3,276,165 | | |
| 2,904,519 | |
| Unproved properties | |
| 224,370 | | |
| 204,233 | |
| Other property and equipment | |
| 11,314 | | |
| 9,165 | |
| Total property and equipment | |
| 3,511,849 | | |
| 3,117,917 | |
| Less: accumulated depletion, depreciation, amortization and impairment | |
| (1,137,464 | ) | |
| (865,618 | ) |
| Total property and equipment, net | |
| 2,374,385 | | |
| 2,252,299 | |
| Other assets: | |
| | | |
| | |
| Long-term derivative instruments | |
| 23,073 | | |
| 47,566 | |
| Deferred tax asset | |
| 521,723 | | |
| 525,156 | |
| Operating lease assets | |
| 8,666 | | |
| 14,299 | |
| Other assets | |
| 26,864 | | |
| 31,487 | |
| Total other assets | |
| 580,326 | | |
| 618,508 | |
| Total assets | |
$ | 3,178,156 | | |
$ | 3,267,613 | |
Consolidated Balance Sheets
(In thousands, except share data)
| | |
September 30, 2024 | | |
December 31, 2023 | |
| |
(Unaudited) | | |
| |
| Liabilities, Mezzanine Equity and Stockholders’ Equity | |
| | |
| |
| Current liabilities: | |
| | |
| |
| Accounts payable and accrued liabilities | |
$ | 282,413 | | |
$ | 309,532 | |
| Short-term derivative instruments | |
| 36,758 | | |
| 21,963 | |
| Current portion of operating lease liabilities | |
| 7,906 | | |
| 12,959 | |
| Total current liabilities | |
| 327,077 | | |
| 344,454 | |
| Non-current liabilities: | |
| | | |
| | |
| Long-term derivative instruments | |
| 23,618 | | |
| 18,602 | |
| Asset retirement obligation | |
| 32,327 | | |
| 29,941 | |
| Non-current operating lease liabilities | |
| 760 | | |
| 1,340 | |
| Long-term debt | |
| 694,389 | | |
| 667,382 | |
| Total non-current liabilities | |
| 751,094 | | |
| 717,265 | |
| Total liabilities | |
$ | 1,078,171 | | |
$ | 1,061,719 | |
| Commitments and contingencies (Note 9) | |
| | | |
| | |
| Mezzanine equity: | |
| | | |
| | |
| Preferred stock - $0.0001 par value, 110.0 thousand shares authorized, 43.7 thousand issued and outstanding at September 30, 2024, and 44.2 thousand issued and outstanding at December 31, 2023 | |
| 43,745 | | |
| 44,214 | |
| Stockholders’ equity: | |
| | | |
| | |
| Common stock - $0.0001 par value, 42.0 million shares authorized, 17.8 million issued and outstanding at September 30, 2024, and 18.3 million issued and outstanding at December 31, 2023 | |
| 2 | | |
| 2 | |
| Additional paid-in capital | |
| 200,196 | | |
| 315,726 | |
| Common stock held in reserve, 0 shares at September 30, 2024 and 62.0 thousand shares at December 31, 2023 | |
| — | | |
| (1,996 | ) |
| Retained earnings | |
| 1,856,511 | | |
| 1,847,948 | |
| Treasury stock, at cost - 3.1 thousand shares at September 30, 2024 and 0 shares at December 31, 2023 | |
| (469 | ) | |
| — | |
| Total stockholders’ equity | |
$ | 2,056,240 | | |
$ | 2,161,680 | |
| Total liabilities, mezzanine equity and stockholders’ equity | |
$ | 3,178,156 | | |
$ | 3,267,613 | |
Consolidated Statement of Cash Flows: Three months ended September 30,
2024
(In thousands)
(Unaudited)
| | |
Three Months Ended
September 30, 2024 | | |
Three Months Ended
September 30, 2023 | |
| Cash flows from operating activities: | |
| | |
| |
| Net (loss) income | |
$ | (13,967 | ) | |
$ | 608,444 | |
| Adjustments to reconcile net (loss) income to net cash provided by operating activities: | |
| | | |
| | |
| Depletion, depreciation and amortization | |
| 82,825 | | |
| 79,505 | |
| Impairment of oil and natural gas properties | |
| 30,487 | | |
| — | |
| Loss on debt extinguishment | |
| 13,388 | | |
| — | |
| Net gain on derivative instruments | |
| (37,965 | ) | |
| (39,417 | ) |
| Net cash receipts on settled derivative instruments | |
| 84,876 | | |
| 49,061 | |
| Deferred income tax benefit | |
| (3,833 | ) | |
| (554,741 | ) |
| Stock-based compensation expense | |
| 2,664 | | |
| 2,360 | |
| Other, net | |
| 1,485 | | |
| 1,683 | |
| Changes in operating assets and liabilities, net | |
| 29,738 | | |
| 9,379 | |
| Net cash provided by operating activities | |
| 189,698 | | |
| 156,274 | |
| Cash flows from investing activities: | |
| | | |
| | |
| Additions to oil and natural gas properties | |
| (132,059 | ) | |
| (137,726 | ) |
| Proceeds from sale of oil and natural gas properties | |
| — | | |
| (1 | ) |
| Other, net | |
| (494 | ) | |
| (661 | ) |
| Net cash used in investing activities | |
| (132,553 | ) | |
| (138,388 | ) |
| Cash flows from financing activities: | |
| | | |
| | |
| Principal payments on Credit Facility | |
| (314,000 | ) | |
| (230,000 | ) |
| Borrowings on Credit Facility | |
| 214,000 | | |
| 226,000 | |
| Issuance of 2029 Senior Notes | |
| 650,000 | | |
| — | |
| Early retirement of 2026 Senior Notes | |
| (524,298 | ) | |
| — | |
| Premium paid on 2026 Senior Notes | |
| (12,941 | ) | |
| — | |
| Debt issuance costs and loan commitment fees | |
| (14,714 | ) | |
| (45 | ) |
| Dividends on preferred stock | |
| (1,093 | ) | |
| (1,131 | ) |
| Repurchase of common stock under Repurchase Program | |
| (25,228 | ) | |
| (8,241 | ) |
| Repurchase of common stock under Repurchase Program - related party | |
| (24,862 | ) | |
| — | |
| Shares exchanged for tax withholdings | |
| (2,022 | ) | |
| (1,411 | ) |
| Other | |
| — | | |
| (2 | ) |
| Net cash used in financing activities | |
| (55,158 | ) | |
| (14,830 | ) |
| Net change in cash and cash equivalents | |
| 1,987 | | |
| 3,056 | |
| Cash and cash equivalents at beginning of period | |
| 1,233 | | |
| 5,269 | |
| Cash and cash equivalents at end of period | |
$ | 3,220 | | |
$ | 8,325 | |
Consolidated Statement of Cash Flows: Nine months ended September 30,
2024
(In thousands)
(Unaudited)
| | |
Nine Months Ended September 30, 2024 | | |
Nine Months Ended September 30, 2023 | |
| Cash flows from operating activities: | |
| | |
| |
| Net income | |
$ | 11,856 | | |
$ | 1,225,185 | |
| Adjustments to reconcile net income to net cash provided by operating activities: | |
| | | |
| | |
| Depletion, depreciation and amortization | |
| 241,401 | | |
| 238,747 | |
| Impairment of oil and natural gas properties | |
| 30,487 | | |
| — | |
| Loss on debt extinguishment | |
| 13,388 | | |
| — | |
| Net gain on derivative instruments | |
| (74,487 | ) | |
| (514,266 | ) |
| Net cash receipts on settled derivative instruments | |
| 240,941 | | |
| 101,947 | |
| Deferred income tax expense (benefit) | |
| 3,433 | | |
| (554,741 | ) |
| Stock-based compensation expense | |
| 8,410 | | |
| 7,403 | |
| Other, net | |
| 4,509 | | |
| 5,867 | |
| Changes in operating assets and liabilities, net | |
| 21,247 | | |
| 57,538 | |
| Net cash provided by operating activities | |
| 501,185 | | |
| 567,680 | |
| Cash flows from investing activities: | |
| | | |
| | |
| Additions to oil and natural gas properties | |
| (376,910 | ) | |
| (421,132 | ) |
| Proceeds from sale of oil and natural gas properties | |
| — | | |
| 2,647 | |
| Other, net | |
| (2,141 | ) | |
| (1,496 | ) |
| Net cash used in investing activities | |
| (379,051 | ) | |
| (419,981 | ) |
| Cash flows from financing activities: | |
| | | |
| | |
| Principal payments on Credit Facility | |
| (825,000 | ) | |
| (748,000 | ) |
| Borrowings on Credit Facility | |
| 737,000 | | |
| 698,000 | |
| Issuance of 2029 Senior Notes | |
| 650,000 | | |
| — | |
| Early retirement of 2026 Senior Notes | |
| (524,298 | ) | |
| — | |
| Premium paid on 2026 Senior Notes | |
| (12,941 | ) | |
| — | |
| Debt issuance costs and loan commitment fees | |
| (14,820 | ) | |
| (6,965 | ) |
| Dividends on preferred stock | |
| (3,293 | ) | |
| (3,718 | ) |
| Repurchase of common stock under Repurchase Program | |
| (64,021 | ) | |
| (62,326 | ) |
| Repurchase of common stock under Repurchase Program - related party | |
| (39,864 | ) | |
| (20,431 | ) |
| Shares exchanged for tax withholdings | |
| (23,606 | ) | |
| (3,191 | ) |
| Other | |
| — | | |
| (2 | ) |
| Net cash used in financing activities | |
| (120,843 | ) | |
| (146,633 | ) |
| Net change in cash and cash equivalents | |
| 1,291 | | |
| 1,066 | |
| Cash and cash equivalents at beginning of period | |
| 1,929 | | |
| 7,259 | |
| Cash and cash equivalents at end of period | |
$ | 3,220 | | |
$ | 8,325 | |
Updated 2024E Guidance
Gulfport's 2024 guidance assumes commodity strip
prices as of October 18, 2024, adjusted for applicable commodity and location differentials, and no property acquisitions or divestitures.
| | |
Year Ending | |
| | |
December 31, 2024 | |
| | |
Low | | |
High | |
| Production | |
| | |
| |
| Average daily gas equivalent (MMcfe/day) | |
| 1,055 | | |
| 1,070 | |
| % Gas | |
| ~92% | |
| | |
| | | |
| | |
| Realizations (before hedges) | |
| | | |
| | |
| Natural gas (differential to NYMEX settled price) ($/Mcf) | |
$ | (0.20 | ) | |
$ | (0.35 | ) |
| NGL (% of WTI) | |
| 35 | % | |
| 40 | % |
| Oil (differential to NYMEX WTI) ($/Bbl) | |
$ | (5.50 | ) | |
$ | (6.50 | ) |
| | |
| | | |
| | |
| Expenses | |
| | | |
| | |
| Lease operating expense ($/Mcfe) | |
$ | 0.17 | | |
$ | 0.19 | |
| Taxes other than income ($/Mcfe) | |
$ | 0.08 | | |
$ | 0.10 | |
| Transportation, gathering, processing and compression ($/Mcfe) | |
$ | 0.90 | | |
$ | 0.94 | |
| Recurring cash general and administrative(1,2) ($/Mcfe) | |
$ | 0.11 | | |
$ | 0.13 | |
| | |
Total | |
| |
(in millions) | |
| Capital expenditures (incurred) | |
| |
| D&C | |
$ | 325 | | |
$ | 335 | |
| Maintenance leasehold and land | |
$ | 50 | | |
$ | 60 | |
| Total base capital expenditures | |
$ | 375 | | |
$ | 395 | |
| | |
| | | |
| | |
| Discretionary acreage acquisitions | |
| ~$45 | |
| (1) | Recurring cash G&A includes capitalization. It excludes
non-cash stock compensation and expenses related to the continued administration of our prior Chapter 11 filing. |
| (2) | This is a non-GAAP measure. Reconciliations of these non-GAAP
measures and other disclosures are provided with the supplemental financial tables available on our website at www.gulfportenergy.com. |
Derivatives
The below details Gulfport's hedging positions
as of October 28, 2024:
| | |
4Q2024 | | |
Full Year 2025 | | |
Full Year 2026 | |
| Natural Gas Contract Summary (NYMEX): | |
| | |
| | |
| |
| Fixed Price Swaps | |
| | |
| | |
| |
| Volume (BBtupd) | |
| 400 | | |
| 250 | | |
| 160 | |
| Weighted Average Price ($/MMBtu) | |
$ | 3.77 | | |
$ | 3.82 | | |
$ | 3.59 | |
| | |
| | | |
| | | |
| | |
| Fixed Price Collars | |
| | | |
| | | |
| | |
| Volume (BBtupd) | |
| 225 | | |
| 220 | | |
| 70 | |
| Weighted Average Floor Price ($/MMBtu) | |
$ | 3.36 | | |
$ | 3.37 | | |
$ | 3.31 | |
| Weighted Average Ceiling Price ($/MMBtu) | |
$ | 5.14 | | |
$ | 4.23 | | |
$ | 4.06 | |
| | |
| | | |
| | | |
| | |
| Fixed Price Calls Sold | |
| | | |
| | | |
| | |
| Volume (BBtupd) | |
| 202 | | |
| 193 | | |
| — | |
| Weighted Average Price ($/MMBtu) | |
$ | 3.33 | | |
$ | 5.80 | | |
$ | — | |
| | |
| | | |
| | | |
| | |
| Rex Zone 3 Basis | |
| | | |
| | | |
| | |
| Volume (BBtupd) | |
| 150 | | |
| 110 | | |
| 40 | |
| Differential ($/MMBtu) | |
$ | (0.15 | ) | |
$ | (0.20 | ) | |
$ | (0.19 | ) |
| | |
| | | |
| | | |
| | |
| Tetco M2 Basis | |
| | | |
| | | |
| | |
| Volume (BBtupd) | |
| 230 | | |
| 230 | | |
| 130 | |
| Differential ($/MMBtu) | |
$ | (0.94 | ) | |
$ | (0.96 | ) | |
$ | (0.98 | ) |
| | |
| | | |
| | | |
| | |
| NGPL TX OK Basis | |
| | | |
| | | |
| | |
| Volume (BBtupd) | |
| 70 | | |
| 40 | | |
| — | |
| Differential ($/MMBtu) | |
$ | (0.31 | ) | |
$ | (0.29 | ) | |
$ | — | |
| | |
| | | |
| | | |
| | |
| TGP 500 Basis | |
| | | |
| | | |
| | |
| Volume (BBtupd) | |
| — | | |
| 10 | | |
| 10 | |
| Differential ($/MMBtu) | |
$ | — | | |
$ | 0.31 | | |
$ | 0.54 | |
| | |
| | | |
| | | |
| | |
| Transco Station 85 Basis | |
| | | |
| | | |
| | |
| Volume (BBtupd) | |
| — | | |
| 5 | | |
| 5 | |
| Differential ($/MMBtu) | |
$ | — | | |
$ | 0.38 | | |
$ | 0.52 | |
| | |
| | | |
| | | |
| | |
| Oil Contract Summary (WTI): | |
| | | |
| | | |
| | |
| Fixed Price Swaps | |
| | | |
| | | |
| | |
| Volume (Bblpd) | |
| 500 | | |
| 2,000 | | |
| — | |
| Weighted Average Price ($/Bbl) | |
$ | 77.50 | | |
$ | 74.50 | | |
$ | — | |
| | |
| | | |
| | | |
| | |
| Fixed Price Collars | |
| | | |
| | | |
| | |
| Volume (Bblpd) | |
| 1,000 | | |
| — | | |
| — | |
| Weighted Average Floor Price ($/Bbl) | |
$ | 62.00 | | |
$ | — | | |
$ | — | |
| Weighted Average Ceiling Price ($/Bbl) | |
$ | 80.00 | | |
$ | — | | |
$ | — | |
| | |
| | | |
| | | |
| | |
| NGL Contract Summary: | |
| | | |
| | | |
| | |
| C3 Propane Fixed Price Swaps | |
| | | |
| | | |
| | |
| Volume (Bblpd) | |
| 2,500 | | |
| 2,000 | | |
| — | |
| Weighted Average Price ($/Bbl) | |
$ | 30.25 | | |
$ | 30.09 | | |
$ | — | |
Non-GAAP Reconciliations
Gulfport’s management uses certain
non-GAAP financial measures for planning, forecasting and evaluating business and financial performance, and believes that they are
useful tools to assess Gulfport’s operating results. Although these are not measures of performance calculated in accordance
with generally accepted accounting principles (GAAP), management believes that these financial measures are useful to an investor in
evaluating Gulfport because (i) analysts utilize these metrics when evaluating company performance and have requested this
information as of a recent practicable date, (ii) these metrics are widely used to evaluate a company’s operating performance,
and (iii) we want to provide updated information to investors. Investors should not view these metrics as a substitute for measures
of performance that are calculated in accordance with GAAP. In addition, because all companies do not calculate these measures
identically, these measures may not be comparable to similarly titled measures of other companies.
These non-GAAP financial measures include adjusted
net income, adjusted EBITDA, adjusted free cash flow, and recurring general and administrative expense. A reconciliation of each financial
measure to its most directly comparable GAAP financial measure is included in the tables below. These non-GAAP measure should be considered
in addition to, but not instead of, the financial statements prepared in accordance with GAAP.
Definitions
Adjusted net income is a non-GAAP financial measure
equal to net income (loss) less non-cash derivative loss (gain), impairment of oil and natural gas properties, non-recurring general and
administrative expenses comprised of expenses related to the continued administration of our prior Chapter 11 filing, stock-based compensation
expenses, restructuring costs, loss on debt extinguishment, other items which include items related to our Chapter 11 filing and other
non-material expenses and the tax effect of the adjustments to net income.
Adjusted EBITDA is a non-GAAP financial measure
equal to net income (loss), the most directly comparable GAAP financial measure, plus interest expense, deferred income tax expense (benefit),
depreciation, depletion, amortization, impairment and accretion, non-cash derivative loss (gain), non-recurring general and administrative
expenses comprised of expenses related to the continued administration of our prior Chapter 11 filing, stock-based compensation, restructuring
costs, loss on debt extinguishment and other items which include items related to our Chapter 11 filing and other non-material expenses.
Adjusted free cash flow is a non-GAAP measure
defined as adjusted EBITDA plus certain non-cash items that are included in net cash provided by operating activities but excluded from
adjusted EBITDA less interest expense, capitalized expenses incurred and capital expenditures incurred excluding discretionary acreage
acquisitions. Gulfport includes an adjusted free cash flow estimate for 2024. We are unable, however, to provide a quantitative reconciliation
of the forward-looking non-GAAP measure to its most directly comparable forward-looking GAAP measure because management cannot reliably
quantify certain of the necessary components of such forward-looking GAAP measure. Accordingly, Gulfport is relying on the exception provided
by Item 10(e)(1)(i)(B) of Regulation S-K to exclude such reconciliation. Items excluded in net cash provided by (used in) operating activities
to arrive at adjusted free cash flow include interest expense, income taxes, capitalized expenses as well as one-time items or items whose
timing or amount cannot be reasonably estimated.
Recurring general and administrative expense is
a non-GAAP financial measure equal to general and administrative expense (GAAP) plus capitalized general and administrative expense, less
non-recurring general and administrative expenses comprised of expenses related to the continued administration of our prior Chapter 11
filing. Gulfport includes a recurring general and administrative expense estimate for 2024. We are unable, however, to provide a quantitative
reconciliation of the forward-looking non-GAAP measure to its most directly comparable forward-looking GAAP measure because management
cannot reliably quantify certain of the necessary components of such forward-looking GAAP measure. Accordingly, Gulfport is relying on
the exception provided by Item 10(e)(1)(i)(B) of Regulation S-K to exclude such reconciliation. Items excluded in general and administrative
expense to arrive at recurring general and administrative expense include capitalized expenses as well as one-time items or items whose
timing or amount cannot be reasonably estimated. The non-GAAP measure recurring general and administrative expenses allows investors to
compare Gulfport’s total general and administrative expenses, including capitalization, to peer companies that account for their
oil and gas operations using the successful efforts method.
Adjusted Net Income: Three months ended September 30, 2024
(In thousands)
(Unaudited)
| | |
Three Months Ended September 30, 2024 | | |
Three Months Ended September 30, 2023 | |
| | |
| | |
| |
| Net (Loss) Income (GAAP) | |
$ | (13,967 | ) | |
$ | 608,444 | |
| | |
| | | |
| | |
| Adjustments: | |
| | | |
| | |
| Non-cash derivative loss | |
| 46,911 | | |
| 9,644 | |
| Impairment of oil and natural gas properties | |
| 30,487 | | |
| — | |
| Non-recurring general and administrative expense | |
| 33 | | |
| 700 | |
| Stock-based compensation expense | |
| 2,664 | | |
| 2,360 | |
| Loss on debt extinguishment | |
| 13,388 | | |
| — | |
| Other, net(1) | |
| 3,133 | | |
| (1,438 | ) |
| Tax effect of adjustments(2) | |
| (20,801 | ) | |
| (554,741 | ) |
| Adjusted Net Income (Non-GAAP) | |
$ | 61,848 | | |
$ | 64,969 | |
| (1) | For the three months ended
September 30, 2024, “Other, net” included approximately $3.0 million related to changes in the Company’s legal reserves
for certain litigation and regulatory proceedings. |
| (2) | Deferred income taxes were
approximately 22% for the three months ended September 30, 2024. For the three months ended September 30, 2023, the Company released
a significant portion of its valuation allowance during the period. As a result, the Company adjusted the total impact of the deferred
income tax benefit from its adjusted net income during the period. |
Adjusted Net Income: Nine months ended September 30, 2024
(In thousands)
(Unaudited)
| | |
Nine Months Ended September 30, 2024 | | |
Nine Months Ended September 30, 2023 | |
| | |
| | |
| |
| Net Income (GAAP) | |
$ | 11,856 | | |
$ | 1,225,185 | |
| | |
| | | |
| | |
| Adjustments: | |
| | | |
| | |
| Non-cash derivative loss (gain) | |
| 166,454 | | |
| (412,319 | ) |
| Impairment of oil and natural gas properties | |
| 30,487 | | |
| — | |
| Non-recurring general and administrative expense | |
| 1,561 | | |
| 2,435 | |
| Stock-based compensation expense | |
| 8,410 | | |
| 6,138 | |
| Restructuring costs | |
| — | | |
| 4,762 | |
| Loss on debt extinguishment | |
| 13,388 | | |
| — | |
| Other, net(1,2) | |
| 3,530 | | |
| (20,492 | ) |
| Tax effect of adjustments(3) | |
| (50,272 | ) | |
| (554,741 | ) |
| Adjusted Net Income (Non-GAAP) | |
$ | 185,414 | | |
$ | 250,968 | |
| (1) | For the nine months ended September
30, 2024, “Other, net” included approximately $3.0 million related to changes in the Company’s legal reserves for certain
litigation and regulatory proceedings. |
| (2) | For the nine months ended September
30, 2023, “Other, net” included a $17.8 million receipt of funds related to our interim claim distribution from our Chapter
11 Plan of Reorganization and a $1 million administrative payment to Rover as part of the executed settlement. For more discussion, refer
to Note 1 of our consolidated financial statements included in our Quarterly Report on Form 10-Q for the nine months ended September
30, 2024. Additionally, “Other, net” included a $5.0 million recoupment of previously placed collateral for certain firm
transportation commitments during our Chapter 11 filing. |
| (3) | Deferred income taxes were
approximately 22% for the nine months ended September 30, 2024. For the nine months ended September 30, 2023, the Company’s effective
tax rate was significantly impacted by the partial release of its valuation allowance during the third quarter of 2023. As a result,
the Company adjusted the total impact of the deferred income tax benefit from its adjusted net income during the period. |
Adjusted EBITDA: Three months ended September 30, 2024
(In thousands)
(Unaudited)
| | |
Three Months Ended September 30, 2024 | | |
Three Months Ended September 30, 2023 | |
| | |
| | |
| |
| Net (Loss) Income (GAAP) | |
$ | (13,967 | ) | |
$ | 608,444 | |
| | |
| | | |
| | |
| Adjustments: | |
| | | |
| | |
| Interest expense | |
| 15,866 | | |
| 14,919 | |
| Deferred income tax benefit | |
| (3,833 | ) | |
| (554,741 | ) |
| DD&A, impairment and accretion | |
| 113,895 | | |
| 80,144 | |
| Non-cash derivative loss | |
| 46,911 | | |
| 9,644 | |
| Non-recurring general and administrative expenses | |
| 33 | | |
| 700 | |
| Stock-based compensation expense | |
| 2,664 | | |
| 2,360 | |
| Loss on debt extinguishment | |
| 13,388 | | |
| — | |
| Other, net(1) | |
| 3,133 | | |
| (1,438 | ) |
| Adjusted EBITDA (Non-GAAP) | |
$ | 178,090 | | |
$ | 160,032 | |
| (1) | For the three months ended
September 30, 2024, “Other, net” included approximately $3.0 million related to changes in the Company’s legal reserves
for certain litigation and regulatory proceedings. |
Adjusted EBITDA: Nine months ended September 30, 2024
(In thousands)
(Unaudited)
| | |
Nine Months Ended September 30, 2024 | | |
Nine Months Ended September 30, 2023 | |
| | |
| | |
| |
| Net Income (GAAP) | |
$ | 11,856 | | |
$ | 1,225,185 | |
| | |
| | | |
| | |
| Adjustments: | |
| | | |
| | |
| Interest expense | |
| 46,027 | | |
| 42,402 | |
| Deferred income tax expense (benefit) | |
| 3,433 | | |
| (554,741 | ) |
| DD&A, impairment and accretion | |
| 273,593 | | |
| 240,864 | |
| Non-cash derivative loss (gain) | |
| 166,454 | | |
| (412,319 | ) |
| Non-recurring general and administrative expenses | |
| 1,561 | | |
| 2,435 | |
| Stock-based compensation expense | |
| 8,410 | | |
| 6,138 | |
| Restructuring costs | |
| — | | |
| 4,762 | |
| Loss on debt extinguishment | |
| 13,388 | | |
| — | |
| Other, net(1,2) | |
| 3,530 | | |
| (20,492 | ) |
| Adjusted EBITDA (Non-GAAP) | |
$ | 528,252 | | |
$ | 534,234 | |
| (1) | For the nine months ended September
30, 2024, “Other, net” included approximately $3.0 million related to changes in the Company’s legal reserves for certain
litigation and regulatory proceedings. |
| (2) | For the nine months ended September
30, 2023, “Other, net” included a $17.8 million receipt of funds related to our interim claim distribution from our Chapter
11 Plan of Reorganization and a $1 million administrative payment to Rover as part of the executed settlement. For more discussion, refer
to Note 1 of our consolidated financial statements included in our Quarterly Report on Form 10-Q for the nine months ended September
30, 2024. Additionally, “Other, net” included a $5.0 million recoupment of previously placed collateral for certain firm
transportation commitments during our Chapter 11 filing. |
Adjusted Free Cash Flow: Three months ended September 30, 2024
(In thousands)
(Unaudited)
| | |
Three Months Ended September 30, 2024 | | |
Three Months Ended September 30, 2023 | |
| | |
| | |
| |
| Net cash provided by operating activity (GAAP) | |
$ | 189,698 | | |
$ | 156,274 | |
| Adjustments: | |
| | | |
| | |
| Interest expense | |
| 15,866 | | |
| 14,919 | |
| Non-recurring general and administrative expenses | |
| 33 | | |
| 700 | |
| Other, net(1) | |
| 2,231 | | |
| (2,482 | ) |
| Changes in operating assets and liabilities, net: | |
| | | |
| | |
| Accounts receivable - oil, natural gas, and natural gas liquids sales | |
| (5,415 | ) | |
| 14,627 | |
| Accounts receivable - joint interest and other | |
| (6,936 | ) | |
| (5,519 | ) |
| Accounts payable and accrued liabilities | |
| (15,900 | ) | |
| (17,175 | ) |
| Prepaid expenses | |
| (1,499 | ) | |
| (1,329 | ) |
| Other assets | |
| 12 | | |
| 17 | |
| Total changes in operating assets and liabilities, net | |
$ | (29,738 | ) | |
$ | (9,379 | ) |
| Adjusted EBITDA (Non-GAAP) | |
$ | 178,090 | | |
$ | 160,032 | |
| Interest expense | |
| (15,866 | ) | |
| (14,919 | ) |
| Capitalized expenses incurred(2) | |
| (6,413 | ) | |
| (5,611 | ) |
| Capital expenditures incurred(3,4,5) | |
| (83,254 | ) | |
| (90,584 | ) |
| Adjusted free cash flow (Non-GAAP) | |
$ | 72,557 | | |
$ | 48,918 | |
| (1) | For the three months ended
September 30, 2024, “Other, net” included approximately $3.0 million related to changes in the Company’s legal reserves
for certain litigation and regulatory proceedings. |
| (2) | Includes cash capitalized general
and administrative expense and incurred capitalized interest expenses. |
| (3) | Incurred capital expenditures
and cash capital expenditures may vary from period to period due to the cash payment cycle. |
| (4) | For the three months ended
September 30, 2024, includes $0.8 million of non-D&C capital and excludes targeted discretionary acreage acquisitions of $19.8 million
that the Company has guided to an anticipated total of approximately $45 million of discretionary acreage acquisitions in 2024. |
| (5) | For the three months ended
September 30, 2023, includes $0.7 million of non-D&C capital and excludes targeted discretionary acreage acquisitions of $19.4 million. |
Adjusted Free Cash Flow: Nine months ended September 30, 2024
(In thousands)
(Unaudited)
| | |
Nine Months Ended September 30, 2024 | | |
Nine Months Ended September 30, 2023 | |
| | |
| | |
| |
| Net cash provided by operating activity (GAAP) | |
$ | 501,185 | | |
$ | 567,680 | |
| Adjustments: | |
| | | |
| | |
| Interest expense | |
| 46,027 | | |
| 42,402 | |
| Non-recurring general and administrative expenses | |
| 1,561 | | |
| 2,435 | |
| Restructuring costs | |
| — | | |
| 4,762 | |
| Other, net(1,2) | |
| 726 | | |
| (25,507 | ) |
| Changes in operating assets and liabilities, net: | |
| | | |
| | |
| Accounts receivable - oil, natural gas, and natural gas liquids sales | |
| (33,548 | ) | |
| (171,673 | ) |
| Accounts receivable - joint interest and other | |
| (7,947 | ) | |
| (9,114 | ) |
| Accounts payable and accrued liabilities | |
| 21,117 | | |
| 123,657 | |
| Prepaid expenses | |
| (850 | ) | |
| (356 | ) |
| Other assets | |
| (19 | ) | |
| (52 | ) |
| Total changes in operating assets and liabilities, net | |
$ | (21,247 | ) | |
$ | (57,538 | ) |
| Adjusted EBITDA (Non-GAAP) | |
$ | 528,252 | | |
$ | 534,234 | |
| Interest expense | |
| (46,027 | ) | |
| (42,402 | ) |
| Capitalized expenses incurred(3) | |
| (17,991 | ) | |
| (16,117 | ) |
| Capital expenditures incurred(4,5,6) | |
| (332,633 | ) | |
| (362,298 | ) |
| Adjusted free cash flow (Non-GAAP) | |
$ | 131,601 | | |
$ | 113,417 | |
| (1) | For the nine months ended September
30, 2024, “Other, net” included approximately $3.0 million related to changes in the Company’s legal reserves for certain
litigation and regulatory proceedings. |
| (2) | For the nine months ended September
30, 2023, “Other, net” included a $17.8 million receipt of funds related to our interim claim distribution from our Chapter
11 Plan of Reorganization and a $1 million administrative payment to Rover as part of the executed settlement. For more discussion, refer
to Note 1 of our consolidated financial statements included in our Quarterly Report on Form 10-Q for the nine months ended September
30, 2024. Additionally, “Other, net” included a $5.0 million recoupment of previously placed collateral for certain firm
transportation commitments during our Chapter 11 filing. |
| (3) | Includes cash capitalized general
and administrative expense and incurred capitalized interest expenses. |
| (4) | Incurred capital expenditures
and cash capital expenditures may vary from period to period due to the cash payment cycle. |
| (5) | For the nine months ended September
30, 2024, includes $3.7 million of non-D&C capital and excludes targeted discretionary acreage acquisitions of $38.8 million that
the Company has guided to an anticipated total of approximately $45 million of discretionary acreage acquisitions in 2024. |
| (6) | For the nine months ended September
30, 2023, includes $1.7 million of non-D&C capital and excludes targeted discretionary acreage acquisitions of $24.9 million. |
Recurring General and Administrative Expenses:
Three months ended September 30, 2024
(In thousands)
(Unaudited)
| | |
Three Months Ended
September 30, 2024 | | |
Three Months Ended
September 30, 2023 | |
| | |
Cash | | |
Non-Cash | | |
Total | | |
Cash | | |
Non-Cash | | |
Total | |
| | |
| | |
| | |
| | |
| | |
| | |
| |
| General and administrative expense (GAAP) | |
$ | 7,815 | | |
$ | 2,664 | | |
$ | 10,479 | | |
$ | 7,534 | | |
$ | 2,360 | | |
$ | 9,894 | |
| Capitalized general and administrative expense | |
| 5,183 | | |
| 1,312 | | |
| 6,495 | | |
| 4,496 | | |
| 1,162 | | |
| 5,658 | |
| Non-recurring general and administrative expense | |
| (33 | ) | |
| — | | |
| (33 | ) | |
| (700 | ) | |
| — | | |
| (700 | ) |
| Recurring general and administrative before capitalization (Non-GAAP) | |
$ | 12,965 | | |
$ | 3,976 | | |
$ | 16,941 | | |
$ | 11,330 | | |
$ | 3,522 | | |
$ | 14,852 | |
Recurring General and Administrative Expenses:
Nine months ended September 30, 2024
(In thousands)
(Unaudited)
| | |
Nine Months Ended
September 30, 2024 | | |
Nine Months Ended
September 30, 2023 | |
| | |
Cash | | |
Non-Cash | | |
Total | | |
Cash | | |
Non-Cash | | |
Total | |
| | |
| | |
| | |
| | |
| | |
| | |
| |
| General and administrative expense (GAAP) | |
$ | 22,019 | | |
$ | 8,410 | | |
$ | 30,429 | | |
$ | 21,100 | | |
$ | 6,138 | | |
$ | 27,238 | |
| Capitalized general and administrative expense | |
| 14,388 | | |
| 4,142 | | |
| 18,530 | | |
| 13,163 | | |
| 3,023 | | |
| 16,186 | |
| Non-recurring general and administrative expense | |
| (1,561 | ) | |
| — | | |
| (1,561 | ) | |
| (2,435 | ) | |
| — | | |
| (2,435 | ) |
| Recurring general and administrative before capitalization (Non-GAAP) | |
$ | 34,846 | | |
$ | 12,552 | | |
$ | 47,398 | | |
$ | 31,828 | | |
$ | 9,161 | | |
$ | 40,989 | |
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| Name: |
dei_EntityEmergingGrowthCompany |
| Namespace Prefix: |
dei_ |
| Data Type: |
xbrli:booleanItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionCommission file number. The field allows up to 17 characters. The prefix may contain 1-3 digits, the sequence number may contain 1-8 digits, the optional suffix may contain 1-4 characters, and the fields are separated with a hyphen.
| Name: |
dei_EntityFileNumber |
| Namespace Prefix: |
dei_ |
| Data Type: |
dei:fileNumberItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionTwo-character EDGAR code representing the state or country of incorporation.
| Name: |
dei_EntityIncorporationStateCountryCode |
| Namespace Prefix: |
dei_ |
| Data Type: |
dei:edgarStateCountryItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionThe exact name of the entity filing the report as specified in its charter, which is required by forms filed with the SEC. Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Exchange Act
-Number 240
-Section 12
-Subsection b-2
| Name: |
dei_EntityRegistrantName |
| Namespace Prefix: |
dei_ |
| Data Type: |
xbrli:normalizedStringItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionThe Tax Identification Number (TIN), also known as an Employer Identification Number (EIN), is a unique 9-digit value assigned by the IRS. Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Exchange Act
-Number 240
-Section 12
-Subsection b-2
| Name: |
dei_EntityTaxIdentificationNumber |
| Namespace Prefix: |
dei_ |
| Data Type: |
dei:employerIdItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionLocal phone number for entity.
| Name: |
dei_LocalPhoneNumber |
| Namespace Prefix: |
dei_ |
| Data Type: |
xbrli:normalizedStringItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionBoolean flag that is true when the Form 8-K filing is intended to satisfy the filing obligation of the registrant as pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act. Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Exchange Act
-Number 240
-Section 13e
-Subsection 4c
| Name: |
dei_PreCommencementIssuerTenderOffer |
| Namespace Prefix: |
dei_ |
| Data Type: |
xbrli:booleanItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionBoolean flag that is true when the Form 8-K filing is intended to satisfy the filing obligation of the registrant as pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act. Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Exchange Act
-Number 240
-Section 14d
-Subsection 2b
| Name: |
dei_PreCommencementTenderOffer |
| Namespace Prefix: |
dei_ |
| Data Type: |
xbrli:booleanItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionTitle of a 12(b) registered security. Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Exchange Act
-Number 240
-Section 12
-Subsection b
| Name: |
dei_Security12bTitle |
| Namespace Prefix: |
dei_ |
| Data Type: |
dei:securityTitleItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionName of the Exchange on which a security is registered. Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Exchange Act
-Number 240
-Section 12
-Subsection d1-1
| Name: |
dei_SecurityExchangeName |
| Namespace Prefix: |
dei_ |
| Data Type: |
dei:edgarExchangeCodeItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionBoolean flag that is true when the Form 8-K filing is intended to satisfy the filing obligation of the registrant as soliciting material pursuant to Rule 14a-12 under the Exchange Act. Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Exchange Act
-Number 240
-Section 14a
-Subsection 12
| Name: |
dei_SolicitingMaterial |
| Namespace Prefix: |
dei_ |
| Data Type: |
xbrli:booleanItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionTrading symbol of an instrument as listed on an exchange.
| Name: |
dei_TradingSymbol |
| Namespace Prefix: |
dei_ |
| Data Type: |
dei:tradingSymbolItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionBoolean flag that is true when the Form 8-K filing is intended to satisfy the filing obligation of the registrant as written communications pursuant to Rule 425 under the Securities Act. Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Securities Act
-Number 230
-Section 425
| Name: |
dei_WrittenCommunications |
| Namespace Prefix: |
dei_ |
| Data Type: |
xbrli:booleanItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
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