PHX Minerals Reports Record Royalty Volumes for the Quarter Ended June 30, 2024; Increases Fixed Quarterly Dividend Payment 33%
FORT WORTH, Texas, Aug. 7, 2024 – PHX MINERALS INC., “PHX” or the “Company” (NYSE: PHX), today reported financial and operating results for the quarter ended June 30, 2024.
Summary of Results for the Quarter Ended June 30, 2024
- Net income was $1.3 million, or $0.04 per diluted share, compared to net loss of ($0.2) million, or ($0.01) per diluted share, for the quarter ended March 31, 2024.
- Adjusted EBITDA(1) was $6.4 million, compared to $4.6 million for the quarter ended March 31, 2024.
- Royalty production volumes increased 46%, to a quarterly record 2,709 Mmcfe, compared to the quarter ended March 31, 2024, as a result of high interest high impact wells coming online in the Haynesville.
- Total production volumes increased 40% compared to the quarter ended March 31, 2024 to 2,968 Mmcfe, the highest quarterly production for PHX since the quarter ended June 30, 2018.
- Converted 55 gross (0.40 net) wells to producing status, compared to a conversion of 85 gross (0.32 net) wells to producing status during the quarter ended March 31, 2024.
- Inventory of 241 gross (0.927 net) wells in progress and permits as of June 30, 2024, compared to 230 gross (1.099 net) wells in progress and permits as of March 31, 2024.
- Total debt was $28.8 million, down $4.0 million since December 31, 2023, and the debt-to-adjusted EBITDA (TTM) (1) ratio was 1.32x at June 30, 2024.
Subsequent Events
- PHX announced a 33% increase in its fixed quarterly dividend to $0.04 per share, payable on Sep. 6, 2024, to stockholders of record on Aug. 23, 2024.
- This is a non-GAAP measure. Refer to the Non-GAAP Reconciliation section.
Chad L. Stephens, President and CEO, commented, “The operational and financial results for the second quarter again provide compelling evidence about the quality of our asset base. Royalty production reached record levels during the quarter, and we had a strong conversion of high interest high impact wells driving robust quarter-over-quarter production growth. As we have explained in prior quarters, our royalty volumes can be lumpy depending on the timing of these high interest high impact wells. Our wells in progress metric remains strong, including several other high interest high impact wells. This demonstrates the continued operator activity on our minerals, despite the dramatic year over year decrease in the rig count impacted by the current commodity price environment. We do not control pace of development or well completion timing, thus, we expect continued quarterly lumpiness in our volumes.”
“Our strong cash generation enabled us to reduce our debt by another $2 million, lowering our debt-to-adjusted EBITDA ratio from 1.58x to 1.32x further strengthening our balance sheet,” continued Mr. Stephens. “Our financial performance enabled us to again increase our quarterly cash dividend, which has now risen 400% since early 2020. Our financial strength also provides the necessary liquidity to further explore the acquisition of premium mineral assets.”
Financial Highlights
|
|
|
Three Months Ended |
|
|
Three Months Ended |
|
|
Six Months Ended |
|
|
Six Months Ended |
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||||
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|
|
June 30, 2024 |
|
|
June 30, 2023 |
|
|
June 30, 2024 |
|
|
June 30, 2023 |
|
||||
|
Royalty Interest Sales |
|
$ |
8,818,964 |
|
|
$ |
6,217,663 |
|
|
$ |
14,995,239 |
|
|
$ |
16,341,404 |
|
|
Working Interest Sales |
|
$ |
1,007,042 |
|
|
$ |
1,013,501 |
|
|
$ |
1,920,975 |
|
|
$ |
2,747,007 |
|
|
Natural Gas, Oil and NGL Sales |
|
$ |
9,826,006 |
|
|
$ |
7,231,164 |
|
|
$ |
16,916,214 |
|
|
$ |
19,088,411 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||
|
Gains (Losses) on Derivative Contracts |
|
$ |
(418,997 |
) |
|
$ |
183,006 |
|
|
$ |
208,495 |
|
|
$ |
3,985,826 |
|
|
Lease Bonuses and Rental Income |
|
$ |
134,226 |
|
|
$ |
111,991 |
|
|
$ |
285,944 |
|
|
$ |
425,141 |
|
|
Total Revenue |
|
$ |
9,541,235 |
|
|
$ |
7,526,161 |
|
|
$ |
17,410,653 |
|
|
$ |
23,499,378 |
|
|
|
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Lease Operating Expense |
|
|
|
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|
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|
|
|
|
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|
||||
|
per Working Interest Mcfe |
|
$ |
1.14 |
|
|
$ |
1.16 |
|
|
$ |
1.21 |
|
|
$ |
1.34 |
|
|
Transportation, Gathering and |
|
|
|
|
|
|
|
|
|
|
|
|
||||
|
Marketing per Mcfe |
|
$ |
0.52 |
|
|
$ |
0.39 |
|
|
$ |
0.47 |
|
|
$ |
0.43 |
|
|
Production and Ad Valorem Tax |
|
|
|
|
|
|
|
|
|
|
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|
||||
|
per Mcfe |
|
$ |
0.20 |
|
|
$ |
0.19 |
|
|
$ |
0.19 |
|
|
$ |
0.21 |
|
|
G&A Expense per Mcfe |
|
$ |
0.92 |
|
|
$ |
1.38 |
|
|
$ |
1.20 |
|
|
$ |
1.29 |
|
|
Cash G&A Expense per Mcfe (1) |
|
$ |
0.69 |
|
|
$ |
1.07 |
|
|
$ |
0.92 |
|
|
$ |
1.01 |
|
|
Interest Expense per Mcfe |
|
$ |
0.22 |
|
|
$ |
0.23 |
|
|
$ |
0.27 |
|
|
$ |
0.23 |
|
|
DD&A per Mcfe |
|
$ |
0.76 |
|
|
$ |
0.96 |
|
|
$ |
0.91 |
|
|
$ |
0.86 |
|
|
Total Expense per Mcfe |
|
$ |
2.72 |
|
|
$ |
3.30 |
|
|
$ |
3.16 |
|
|
$ |
3.21 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||
|
Net Income (Loss) |
|
$ |
1,295,771 |
|
|
$ |
(41,291 |
) |
|
$ |
1,112,156 |
|
|
$ |
9,511,953 |
|
|
Adjusted EBITDA (2) |
|
$ |
6,426,167 |
|
|
$ |
4,086,707 |
|
|
$ |
11,033,201 |
|
|
$ |
11,826,947 |
|
|
|
|
|
|
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|
|
|
|
|
|
|
|
||||
|
Cash Flow from Operations (3) |
|
$ |
4,176,704 |
|
|
$ |
4,915,788 |
|
|
$ |
9,423,355 |
|
|
$ |
13,849,265 |
|
|
CapEx (4) |
|
$ |
28,286 |
|
|
$ |
84,593 |
|
|
$ |
35,726 |
|
|
$ |
275,419 |
|
|
CapEx - Mineral Acquisitions |
|
$ |
871,930 |
|
|
$ |
1,677,388 |
|
|
$ |
2,278,178 |
|
|
$ |
11,914,003 |
|
|
|
|
|
|
|
|
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|
|
|
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|
||||
|
Borrowing Base |
|
|
|
|
|
|
|
$ |
50,000,000 |
|
|
$ |
45,000,000 |
|
||
|
Debt |
|
|
|
|
|
|
|
$ |
28,750,000 |
|
|
$ |
23,750,000 |
|
||
|
Debt-to-Adjusted EBITDA (TTM) (2) |
|
|
|
|
|
|
|
|
1.32 |
|
|
|
0.93 |
|
||
- Cash G&A expense is G&A excluding restricted stock and deferred director’s expense from the adjusted EBITDA table in the non-GAAP Reconciliation section.
- This is a non-GAAP measure. Refer to the Non-GAAP Reconciliation section.
- GAAP cash flow from operations.
- Includes legacy working interest expenditures and fixtures and equipment.
Operating Highlights
|
|
Three Months Ended |
|
|
Three Months Ended |
|
|
Six Months Ended |
|
|
Six Months Ended |
|
||||
|
|
June 30, 2024 |
|
|
June 30, 2023 |
|
|
June 30, 2024 |
|
|
June 30, 2023 |
|
||||
|
Gas Mcf Sold |
|
2,464,846 |
|
|
|
1,854,485 |
|
|
|
4,164,955 |
|
|
|
3,813,496 |
|
|
Average Sales Price per Mcf before the |
|
|
|
|
|
|
|
|
|
|
|
||||
|
effects of settled derivative contracts |
$ |
2.05 |
|
|
$ |
1.92 |
|
|
$ |
2.07 |
|
|
$ |
2.75 |
|
|
Average Sales Price per Mcf after the |
|
|
|
|
|
|
|
|
|
|
|
||||
|
effects of settled derivative contracts |
$ |
2.57 |
|
|
$ |
2.49 |
|
|
$ |
2.78 |
|
|
$ |
3.18 |
|
|
% of sales subject to hedges |
|
38 |
% |
|
|
45 |
% |
|
|
48 |
% |
|
|
47 |
% |
|
Oil Barrels Sold |
|
51,828 |
|
|
|
41,009 |
|
|
|
89,088 |
|
|
|
95,116 |
|
|
Average Sales Price per Bbl before the |
|
|
|
|
|
|
|
|
|
|
|
||||
|
effects of settled derivative contracts |
$ |
77.38 |
|
|
$ |
73.87 |
|
|
$ |
76.81 |
|
|
$ |
75.09 |
|
|
Average Sales Price per Bbl after the |
|
|
|
|
|
|
|
|
|
|
|
||||
|
effects of settled derivative contracts |
$ |
75.38 |
|
|
$ |
73.80 |
|
|
$ |
75.72 |
|
|
$ |
71.58 |
|
|
% of sales subject to hedges |
|
25 |
% |
|
|
53 |
% |
|
|
30 |
% |
|
|
49 |
% |
|
NGL Barrels Sold |
|
31,994 |
|
|
|
33,929 |
|
|
|
64,179 |
|
|
|
67,033 |
|
|
Average Sales Price per Bbl(1) |
$ |
23.75 |
|
|
$ |
18.93 |
|
|
$ |
22.63 |
|
|
$ |
22.02 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||
|
Mcfe Sold |
|
2,967,779 |
|
|
|
2,304,113 |
|
|
|
5,084,557 |
|
|
|
4,786,390 |
|
|
Natural gas, oil and NGL sales before the |
|
|
|
|
|
|
|
|
|
|
|
||||
|
effects of settled derivative contracts |
$ |
9,826,006 |
|
|
$ |
7,231,164 |
|
|
$ |
16,916,214 |
|
|
$ |
19,088,411 |
|
|
Natural gas, oil and NGL sales after the |
|
|
|
|
|
|
|
|
|
|
|
||||
|
effects of settled derivative contracts |
$ |
11,010,613 |
|
|
$ |
8,280,104 |
|
|
$ |
19,770,130 |
|
|
$ |
20,394,028 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||
|
(1) There were no NGL settled derivative contracts during the 2024 and 2023 periods. |
|
||||||||||||||
Total Production for the last four quarters was as follows:
|
Quarter ended |
|
Mcf Sold |
|
|
Oil Bbls Sold |
|
|
NGL Bbls Sold |
|
|
Mcfe Sold |
|
||||
|
6/30/2024 |
|
|
2,464,846 |
|
|
|
51,828 |
|
|
|
31,994 |
|
|
|
2,967,779 |
|
|
3/31/2024 |
|
|
1,700,108 |
|
|
|
37,260 |
|
|
|
32,184 |
|
|
|
2,116,776 |
|
|
12/31/2023 |
|
|
1,775,577 |
|
|
|
39,768 |
|
|
|
38,422 |
|
|
|
2,244,717 |
|
|
9/30/2023 |
|
|
1,868,012 |
|
|
|
48,032 |
|
|
|
32,029 |
|
|
|
2,348,378 |
|
The percentage of total production volumes attributable to natural gas was 83% for the quarter ended June 30, 2024.
Royalty Interest Production for the last four quarters was as follows:
|
Quarter ended |
|
Mcf Sold |
|
|
Oil Bbls Sold |
|
|
NGL Bbls Sold |
|
|
Mcfe Sold |
|
||||
|
6/30/2024 |
|
|
2,304,176 |
|
|
|
47,024 |
|
|
|
20,461 |
|
|
|
2,709,090 |
|
|
3/31/2024 |
|
|
1,533,580 |
|
|
|
33,083 |
|
|
|
20,844 |
|
|
|
1,857,147 |
|
|
12/31/2023 |
|
|
1,590,301 |
|
|
|
35,547 |
|
|
|
23,769 |
|
|
|
1,946,196 |
|
|
9/30/2023 |
|
|
1,689,396 |
|
|
|
43,575 |
|
|
|
20,416 |
|
|
|
2,073,342 |
|
The percentage of royalty production volumes attributable to natural gas was 85% for the quarter ended June 30, 2024.
Working Interest Production for the last four quarters was as follows:
|
Quarter ended |
|
Mcf Sold |
|
|
Oil Bbls Sold |
|
|
NGL Bbls Sold |
|
|
Mcfe Sold |
|
||||
|
6/30/2024 |
|
|
160,670 |
|
|
|
4,804 |
|
|
|
11,533 |
|
|
|
258,689 |
|
|
3/31/2024 |
|
|
166,528 |
|
|
|
4,177 |
|
|
|
11,340 |
|
|
|
259,629 |
|
|
12/31/2023 |
|
|
185,276 |
|
|
|
4,221 |
|
|
|
14,653 |
|
|
|
298,521 |
|
|
9/30/2023 |
|
|
178,616 |
|
|
|
4,457 |
|
|
|
11,613 |
|
|
|
275,036 |
|
Outlook
PHX is providing an updated operational outlook for 2024 as follows:
|
|
|
2023 Actual |
|
YTD 2024 Actual |
2024 Outlook |
|
Mineral & Royalty Production (Mmcfe) |
|
8,123 |
|
4,566 |
8,700 - 9,100 |
|
Working Interest Production (Mmcfe) |
|
1,256 |
|
518 |
1,000 - 1,200 |
|
Total Production (Mmcfe) |
|
9,379 |
|
5,084 |
9,700 - 10,300 |
|
Percentage Natural Gas |
|
80% |
|
82% |
79% - 82% |
|
|
|
|
|
|
|
|
Transportation, Gathering & |
|
|
|
|
|
|
Marketing (per Mcfe) |
|
$0.39 |
|
$0.47 |
$0.40 - $0.50 |
|
Production Tax (as % of pre-hedge |
|
|
|
|
|
|
sales volumes) |
|
5.20% |
|
5.90% |
5.25% - 6.25% |
|
LOE Expenses (on an absolute basis in 000’s) |
|
$1,599 |
|
$627 |
$1,100 - $1,300 |
|
Cash G&A (on an absolute basis in 000’s) |
|
$9,500 |
|
$4,683 |
$9,500 - $9,900 |
Quarter Ended June 30, 2024 Results
The Company recorded net income of $1.3 million, or $0.04 per diluted share, for the quarter ended June 30, 2024, as compared to net loss of ($0.04) million, or $0.00 per diluted share, for the quarter ended June 30, 2023. The change in net income was principally the result of increased natural gas, oil and NGL sales, decreased general and administrative expenses, and increased gains on asset sales, partially offset by increased losses associated with our derivative contracts and increased income tax provision.
Natural gas, oil and NGL revenue increased $2.6 million, or 36%, for the quarter ended June 30, 2024, compared to the quarter ended June 30, 2023, due to increases in natural gas and oil volumes of 33% and 26%, respectively, and increases in natural gas, oil, and NGL prices of 7%, 5%, and 25%, respectively, partially offset by a decrease in NGL volumes of 6%.
The increase in royalty production volumes during the quarter ended June 30, 2024, as compared to the quarter ended June 30, 2023, resulted primarily from new wells being brought online in the Haynesville Shale. The production decrease in working interest volumes during the quarter ended June 30, 2024, as compared to the quarter ended June 30, 2023, resulted from natural production decline.
The Company had a net loss on derivative contracts of ($0.4) million for the quarter ended June 30, 2024, comprised of a $1.2 million gain on settled derivatives and a ($1.6) million non-cash loss on derivatives, as compared to a net gain of $0.2 million for the quarter ended June 30, 2023. The change in net gain on derivative contracts was due to the Company’s settlements of natural gas and oil collars and fixed price swaps and the change in valuation caused by the difference in June 30, 2024 pricing relative to the strike price on open derivative contracts.
Six Months Ended June 30, 2024 Results
The Company recorded net income of $1.1 million, or $0.03 per share, for the six months ended June 30, 2024, as compared to a net income of $9.5 million, or $0.26 per share, for the six months ended June 30, 2023. The change in net income was principally the result of a decrease in natural gas, oil and NGL sales, a decrease in gains associated with our hedge contracts, and a decrease in gains on asset sales, partially offset by a decrease in income tax provision.
Natural gas, oil and NGL revenue decreased $2.2 million, or 11%, for the six months ended June 30, 2024, compared to the six months ended June 30, 2023, due to decreases in oil and NGL volumes of 6% and 4%, respectively, and a decrease in gas prices of 25%, partially offset by an increase in gas volumes of 9% and increases in oil and NGL prices of 2% and 3%, respectively.
The production increase in royalty volumes during the six months ended June 30, 2024, as compared to the six months ended June 30, 2023, resulted primarily from new wells in the Haynesville Shale coming online. The production decrease in working interest volumes during the six months ended June 30, 2024, as compared to the six months ended June 30, 2023, resulted from natural production decline and divestitures of working interest properties.
The Company had a net gain on derivative contracts of $0.2 million for the six months ended June 30, 2024, compromised of a $2.9 million gain on settled derivatives and a $2.6 million non-cash loss on derivatives, as compared to a net gain of $4.0 million for the six months ended June 30, 2023. The change in net gain on derivative contracts was due to the Company’s settlements of natural gas and oil collars and fixed price swaps and the change in valuation caused by the difference in June 30, 2024 pricing relative to the strike price on open derivative contracts.
Operations Update
During the quarter ended June 30, 2024, the Company converted 55 gross (0.40 net) wells to producing status, including 28 gross (0.30 net) wells in the Haynesville and 14 gross (0.07 net) wells in the SCOOP, compared to 81 gross (0.30 net) wells converted in the quarter ended June 30, 2023.
At June 30, 2024, the Company had a total of 241 gross (0.927 net) wells in progress and permits across its mineral positions, compared to 230 gross (1.099 net) wells in progress and permits at March 31, 2024. As of July 8, 2024, 15 rigs were operating on the Company’s acreage and 60 rigs were operating within 2.5 miles of its acreage.
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Bakken/ |
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Three |
|
|
Arkoma |
|
|
|
|
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|||||||
|
|
SCOOP |
|
|
STACK |
|
|
Forks |
|
|
Stack |
|
|
Haynesville |
|
|
Other |
|
|
Total |
|
|||||||
|
As of June 30, 2024: |
|
|
|
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|
|
|
|
|
|
|
|
|
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|
|||||||
|
Gross Wells in Progress on PHX Acreage (1) |
|
74 |
|
|
|
7 |
|
|
|
2 |
|
|
|
3 |
|
|
|
58 |
|
|
|
3 |
|
|
|
147 |
|
|
Net Wells in Progress on PHX Acreage (1) |
|
0.252 |
|
|
|
0.009 |
|
|
|
0.001 |
|
|
|
0.015 |
|
|
|
0.296 |
|
|
|
0.016 |
|
|
|
0.589 |
|
|
Gross Active Permits on PHX Acreage |
|
35 |
|
|
|
6 |
|
|
|
3 |
|
|
|
7 |
|
|
|
35 |
|
|
|
8 |
|
|
|
94 |
|
|
Net Active Permits on PHX Acreage |
|
0.151 |
|
|
|
0.007 |
|
|
|
0.003 |
|
|
|
0.030 |
|
|
|
0.112 |
|
|
|
0.035 |
|
|
|
0.338 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||
|
As of July 8, 2024: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||
|
Rigs Present on PHX Acreage |
|
7 |
|
|
|
3 |
|
|
|
- |
|
|
|
1 |
|
|
|
4 |
|
|
|
- |
|
|
|
15 |
|
|
Rigs Within 2.5 Miles of PHX Acreage |
|
10 |
|
|
|
11 |
|
|
|
6 |
|
|
|
1 |
|
|
|
23 |
|
|
|
9 |
|
|
|
60 |
|
(1) Wells in progress includes drilling wells and drilled but uncompleted wells, or DUCs.
Leasing Activity
During the quarter ended June 30, 2024, the Company leased 313 net mineral acres to third-party exploration and production companies for an average bonus payment of $550 per net mineral acre and an average royalty of 24%.
Acquisition and Divestiture Update
During the quarter ended June 30, 2024, the Company purchased 96 net royalty acres for approximately $0.9 million and sold 1,005 acres, which were outside the Company's core focus areas and predominately undeveloped and unleased, for approximately $0.5 million.
|
|
|
Acquisitions |
|
|||||||||||||
|
|
|
SCOOP |
|
|
Haynesville |
|
|
Other |
|
|
Total |
|
||||
|
During Three Months Ended June 30, 2024: |
|
|
|
|
|
|
|
|
|
|
|
|
||||
|
Net Mineral Acres Purchased |
|
|
35 |
|
|
|
21 |
|
|
|
- |
|
|
|
56 |
|
|
Net Royalty Acres Purchased |
|
|
58 |
|
|
|
38 |
|
|
|
- |
|
|
|
96 |
|
Quarterly Conference Call
PHX will host a conference call to discuss the Company’s results for the quarter ended June 30, 2024, at 11 a.m. EDT on Aug. 8, 2024. Management’s discussion will be followed by a question-and-answer session with investors.
To participate on the conference call, please dial 877-407-3088 (toll-free domestic) or 201-389-0927. A replay of the call will be available for 14 days after the call. The number to access the replay of the conference call is 877-660-6853 and the PIN for the replay is 13748051.
A live audio webcast of the conference call will be accessible from the “Investors” section of PHX’s website at https://phxmin.com/events. The webcast will be archived for at least 90 days.
FINANCIAL RESULTS
Statements of Income
|
|
Three Months Ended June 30, |
|
|
Six Months Ended June 30, |
|
|
||||||||||
|
|
2024 |
|
|
2023 |
|
|
2024 |
|
|
2023 |
|
|
||||
|
Revenues: |
|
|
|
|
|
|
|
|||||||||
|
Natural gas, oil and NGL sales |
$ |
9,826,006 |
|
|
$ |
7,231,164 |
|
|
$ |
16,916,214 |
|
|
$ |
19,088,411 |
|
|
|
Lease bonuses and rental income |
|
134,226 |
|
|
|
111,991 |
|
|
|
285,944 |
|
|
|
425,141 |
|
|
|
Gains (losses) on derivative contracts |
|
(418,997 |
) |
|
|
183,006 |
|
|
|
208,495 |
|
|
|
3,985,826 |
|
|
|
|
|
9,541,235 |
|
|
|
7,526,161 |
|
|
|
17,410,653 |
|
|
|
23,499,378 |
|
|
|
Costs and expenses: |
|
|
|
|
|
|
|
|
|
|
|
|
||||
|
Lease operating expenses |
|
294,354 |
|
|
|
341,463 |
|
|
|
626,763 |
|
|
|
916,405 |
|
|
|
Transportation, gathering and marketing |
|
1,540,396 |
|
|
|
906,373 |
|
|
|
2,383,900 |
|
|
|
2,035,129 |
|
|
|
Production and ad valorem taxes |
|
597,995 |
|
|
|
434,580 |
|
|
|
990,322 |
|
|
|
986,838 |
|
|
|
Depreciation, depletion and amortization |
|
2,268,284 |
|
|
|
2,210,332 |
|
|
|
4,624,610 |
|
|
|
4,100,322 |
|
|
|
Provision for impairment |
|
- |
|
|
|
- |
|
|
|
- |
|
|
|
2,073 |
|
|
|
Interest expense |
|
651,982 |
|
|
|
524,294 |
|
|
|
1,366,868 |
|
|
|
1,081,767 |
|
|
|
General and administrative |
|
2,734,628 |
|
|
|
3,177,103 |
|
|
|
6,081,665 |
|
|
|
6,159,012 |
|
|
|
Losses (gains) on asset sales and other |
|
(197,326 |
) |
|
|
139,307 |
|
|
|
(173,114 |
) |
|
|
(4,195,121 |
) |
|
|
Total costs and expenses |
|
7,890,313 |
|
|
|
7,733,452 |
|
|
|
15,901,014 |
|
|
|
11,086,425 |
|
|
|
Income (loss) before provision for income taxes |
|
1,650,922 |
|
|
|
(207,291 |
) |
|
|
1,509,639 |
|
|
|
12,412,953 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||
|
Provision for income taxes |
|
355,151 |
|
|
|
(166,000 |
) |
|
|
397,483 |
|
|
|
2,901,000 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||
|
Net income (loss) |
$ |
1,295,771 |
|
|
$ |
(41,291 |
) |
|
$ |
1,112,156 |
|
|
$ |
9,511,953 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||
|
Basic and diluted earnings per common share |
$ |
0.04 |
|
|
$ |
(0.00 |
) |
|
$ |
0.03 |
|
|
$ |
0.26 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||
|
Weighted average shares outstanding: |
|
|
|
|
|
|
|
|
|
|
|
|
||||
|
Basic |
|
36,308,224 |
|
|
|
35,965,281 |
|
|
|
36,301,540 |
|
|
|
35,950,615 |
|
|
|
Diluted |
|
36,379,653 |
|
|
|
35,965,281 |
|
|
|
36,301,540 |
|
|
|
36,034,438 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||
|
Dividends per share of |
|
|
|
|
|
|
|
|
|
|
|
|
||||
|
common stock paid in period |
$ |
0.0300 |
|
|
$ |
0.0225 |
|
|
$ |
0.0600 |
|
|
$ |
0.0450 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||
Balance Sheets
|
|
June 30, 2024 |
|
|
Dec. 31, 2023 |
|
||
|
Assets |
|
|
|
|
|
||
|
Current assets: |
|
|
|
|
|
||
|
Cash and cash equivalents |
$ |
2,271,544 |
|
|
$ |
806,254 |
|
|
Natural gas, oil, and NGL sales receivables (net of $0 |
|
5,071,590 |
|
|
|
4,900,126 |
|
|
allowance for uncollectable accounts) |
|
|
|
|
|
||
|
Refundable income taxes |
|
372,963 |
|
|
|
455,931 |
|
|
Derivative contracts, net |
|
877,538 |
|
|
|
3,120,607 |
|
|
Other |
|
703,210 |
|
|
|
878,659 |
|
|
Total current assets |
|
9,296,845 |
|
|
|
10,161,577 |
|
|
|
|
|
|
|
|
||
|
Properties and equipment at cost, based on |
|
|
|
|
|
||
|
successful efforts accounting: |
|
|
|
|
|
||
|
Producing natural gas and oil properties |
|
216,696,381 |
|
|
|
209,082,847 |
|
|
Non-producing natural gas and oil properties |
|
52,997,639 |
|
|
|
58,820,445 |
|
|
Other |
|
1,361,064 |
|
|
|
1,360,614 |
|
|
|
|
271,055,084 |
|
|
|
269,263,906 |
|
|
Less accumulated depreciation, depletion and amortization |
|
(118,186,569 |
) |
|
|
(114,139,423 |
) |
|
Net properties and equipment |
|
152,868,515 |
|
|
|
155,124,483 |
|
|
|
|
|
|
|
|
||
|
Derivative contracts, net |
|
- |
|
|
|
162,980 |
|
|
Operating lease right-of-use assets |
|
502,194 |
|
|
|
572,610 |
|
|
Other, net |
|
640,573 |
|
|
|
486,630 |
|
|
Total assets |
$ |
163,308,127 |
|
|
$ |
166,508,280 |
|
|
|
|
|
|
|
|
||
|
Liabilities and Stockholders' Equity |
|
|
|
|
|
||
|
Current liabilities: |
|
|
|
|
|
||
|
Accounts payable |
$ |
636,327 |
|
|
$ |
562,607 |
|
|
Current portion of operating lease liability |
|
239,571 |
|
|
|
233,390 |
|
|
Accrued liabilities and other |
|
1,457,285 |
|
|
|
1,215,275 |
|
|
Total current liabilities |
|
2,333,183 |
|
|
|
2,011,272 |
|
|
|
|
|
|
|
|
||
|
Long-term debt |
|
28,750,000 |
|
|
|
32,750,000 |
|
|
Deferred income taxes, net |
|
6,829,023 |
|
|
|
6,757,637 |
|
|
Asset retirement obligations |
|
1,083,947 |
|
|
|
1,062,139 |
|
|
Derivative contracts, net |
|
239,372 |
|
|
|
- |
|
|
Operating lease liability, net of current portion |
|
574,598 |
|
|
|
695,818 |
|
|
Total liabilities |
|
39,810,123 |
|
|
|
43,276,866 |
|
|
|
|
|
|
|
|
||
|
Stockholders' equity: |
|
|
|
|
|
||
|
Common Stock, $0.01666 par value; 75,000,000 shares authorized and |
|
|
|
|
|
||
|
36,121,723 issued at June 30, 2024; 54,000,500 shares authorized |
|
|
|
|
|
||
|
and 36,121,723 issued at Dec. 31, 2023 |
|
601,788 |
|
|
|
601,788 |
|
|
Capital in excess of par value |
|
43,054,447 |
|
|
|
41,676,417 |
|
|
Deferred directors' compensation |
|
1,471,052 |
|
|
|
1,487,590 |
|
|
Retained earnings |
|
78,891,082 |
|
|
|
80,022,839 |
|
|
|
|
124,018,369 |
|
|
|
123,788,634 |
|
|
Less treasury stock, at cost; 122,785 shares at June 30, |
|
|
|
|
|
||
|
2024, and 131,477 shares at Dec. 31, 2023 |
|
(520,365 |
) |
|
|
(557,220 |
) |
|
Total stockholders' equity |
|
123,498,004 |
|
|
|
123,231,414 |
|
|
Total liabilities and stockholders' equity |
$ |
163,308,127 |
|
|
$ |
166,508,280 |
|
Condensed Statements of Cash Flows
|
|
Six Months Ended |
|
|
Six Months Ended |
|
||
|
|
June 30, 2024 |
|
|
June 30, 2023 |
|
||
|
Operating Activities |
|
|
|
|
|
||
|
Net income (loss) |
$ |
1,112,156 |
|
|
$ |
9,511,953 |
|
|
Adjustments to reconcile net income (loss) to net cash provided |
|
|
|
|
|
||
|
by operating activities: |
|
|
|
|
|
||
|
Depreciation, depletion and amortization |
|
4,624,610 |
|
|
|
4,100,322 |
|
|
Impairment of producing properties |
|
- |
|
|
|
2,073 |
|
|
Provision for deferred income taxes |
|
71,386 |
|
|
|
2,679,000 |
|
|
Gain from leasing fee mineral acreage |
|
(285,944 |
) |
|
|
(425,141 |
) |
|
Proceeds from leasing fee mineral acreage |
|
292,350 |
|
|
|
488,173 |
|
|
Net (gain) loss on sales of assets |
|
(511,684 |
) |
|
|
(4,428,212 |
) |
|
Directors' deferred compensation expense |
|
90,661 |
|
|
|
109,383 |
|
|
Total (gain) loss on derivative contracts |
|
(208,495 |
) |
|
|
(3,985,826 |
) |
|
Cash receipts (payments) on settled derivative contracts |
|
2,853,916 |
|
|
|
1,865,779 |
|
|
Restricted stock award expense |
|
1,307,686 |
|
|
|
1,228,871 |
|
|
Other |
|
55,059 |
|
|
|
70,526 |
|
|
Cash provided (used) by changes in assets and liabilities: |
|
|
|
|
|
||
|
Natural gas, oil and NGL sales receivables |
|
(171,464 |
) |
|
|
3,944,092 |
|
|
Income taxes receivable |
|
82,968 |
|
|
|
(675,268 |
) |
|
Other current assets |
|
131,854 |
|
|
|
405,055 |
|
|
Accounts payable |
|
73,810 |
|
|
|
(228,305 |
) |
|
Other non-current assets |
|
(138,508 |
) |
|
|
95,283 |
|
|
Income taxes payable |
|
- |
|
|
|
(576,427 |
) |
|
Accrued liabilities |
|
42,994 |
|
|
|
(332,066 |
) |
|
Total adjustments |
|
8,311,199 |
|
|
|
4,337,312 |
|
|
Net cash provided by operating activities |
|
9,423,355 |
|
|
|
13,849,265 |
|
|
|
|
|
|
|
|
||
|
Investing Activities |
|
|
|
|
|
||
|
Capital expenditures |
|
(35,726 |
) |
|
|
(275,419 |
) |
|
Acquisition of minerals and overriding royalty interests |
|
(2,278,178 |
) |
|
|
(11,914,003 |
) |
|
Net proceeds from sales of assets |
|
515,775 |
|
|
|
9,223,405 |
|
|
Net cash provided by (used in) investing activities |
|
(1,798,129 |
) |
|
|
(2,966,017 |
) |
|
|
|
|
|
|
|
||
|
Financing Activities |
|
|
|
|
|
||
|
Borrowings under credit facility |
|
1,000,000 |
|
|
|
6,000,000 |
|
|
Payments of loan principal |
|
(5,000,000 |
) |
|
|
(15,550,000 |
) |
|
Payments on off-market derivative contracts |
|
- |
|
|
|
(560,162 |
) |
|
Purchases of treasury stock |
|
- |
|
|
|
(669 |
) |
|
Payments of dividends |
|
(2,159,936 |
) |
|
|
(1,620,442 |
) |
|
Net cash provided by (used in) financing activities |
|
(6,159,936 |
) |
|
|
(11,731,273 |
) |
|
|
|
|
|
|
|
||
|
Increase (decrease) in cash and cash equivalents |
|
1,465,290 |
|
|
|
(848,025 |
) |
|
Cash and cash equivalents at beginning of period |
|
806,254 |
|
|
|
2,115,652 |
|
|
Cash and cash equivalents at end of period |
$ |
2,271,544 |
|
|
$ |
1,267,627 |
|
|
|
|
|
|
|
|
||
|
Supplemental Disclosures of Cash Flow Information: |
|
|
|
|
|
||
|
|
|
|
|
|
|
||
|
Interest paid (net of capitalized interest) |
$ |
1,409,711 |
|
|
$ |
1,155,637 |
|
|
Income taxes paid (net of refunds received) |
$ |
243,130 |
|
|
$ |
1,473,696 |
|
|
|
|
|
|
|
|
||
|
Supplemental Schedule of Noncash Investing and Financing Activities: |
|
|
|
|
|
||
|
|
|
|
|
|
|
||
|
Dividends declared and unpaid |
$ |
83,977 |
|
|
$ |
72,460 |
|
|
|
|
|
|
|
|
||
|
Gross additions to properties and equipment |
$ |
2,357,409 |
|
|
$ |
12,952,046 |
|
|
Net increase (decrease) in accounts receivable for properties |
|
|
|
|
|
||
|
and equipment additions |
|
(43,505 |
) |
|
|
(762,624 |
) |
|
Capital expenditures and acquisitions |
$ |
2,313,904 |
|
|
$ |
12,189,422 |
|
Derivative Contracts as of June 30, 2024
|
|
|
Production volume |
|
|
|
|
|
Contract period |
|
covered per month |
|
Index |
|
Contract price |
|
Natural gas costless collars |
|
|
|
|
|
|
|
July - September 2024 |
|
30,000 Mmbtu |
|
NYMEX Henry Hub |
|
$3.00 floor / $3.60 ceiling |
|
October 2024 - June 2025 |
|
30,000 Mmbtu |
|
NYMEX Henry Hub |
|
$3.00 floor / $5.00 ceiling |
|
November 2024 - March 2025 |
|
90,000 Mmbtu |
|
NYMEX Henry Hub |
|
$3.25 floor / $5.25 ceiling |
|
November - December 2024 |
|
35,000 Mmbtu |
|
NYMEX Henry Hub |
|
$3.50 floor / $5.15 ceiling |
|
January - March 2025 |
|
30,000 Mmbtu |
|
NYMEX Henry Hub |
|
$3.50 floor / $5.15 ceiling |
|
January 2025 |
|
55,000 Mmbtu |
|
NYMEX Henry Hub |
|
$3.50 floor / $4.40 ceiling |
|
February 2025 |
|
25,000 Mmbtu |
|
NYMEX Henry Hub |
|
$3.50 floor / $4.40 ceiling |
|
March 2025 |
|
35,000 Mmbtu |
|
NYMEX Henry Hub |
|
$3.50 floor / $4.40 ceiling |
|
April 2025 - September 2025 |
|
55,000 Mmbtu |
|
NYMEX Henry Hub |
|
$3.00 floor / $3.75 ceiling |
|
November 2025 - March 2026 |
|
100,000 Mmbtu |
|
NYMEX Henry Hub |
|
$3.50 floor / $4.85 ceiling |
|
November 2025 - March 2026 |
|
75,000 Mmbtu |
|
NYMEX Henry Hub |
|
$3.50 floor / $4.72 ceiling |
|
November 2025 - March 2026 |
|
15,000 Mmbtu |
|
NYMEX Henry Hub |
|
$3.50 floor / $5.15 ceiling |
|
Natural gas fixed price swaps |
|
|
|
|
|
|
|
July - October 2024 |
|
50,000 Mmbtu |
|
NYMEX Henry Hub |
|
$3.17 |
|
July 2024 |
|
127,500 Mmbtu |
|
NYMEX Henry Hub |
|
$3.24 |
|
July - October 2024 |
|
75,000 Mmbtu |
|
NYMEX Henry Hub |
|
$3.47 |
|
July - October 2024 |
|
25,000 Mmbtu |
|
NYMEX Henry Hub |
|
$3.47 |
|
August - September 2024 |
|
120,000 Mmbtu |
|
NYMEX Henry Hub |
|
$3.24 |
|
October 2024 |
|
105,000 Mmbtu |
|
NYMEX Henry Hub |
|
$3.24 |
|
November - December 2024 |
|
70,000 Mmbtu |
|
NYMEX Henry Hub |
|
$4.16 |
|
December 2024 |
|
50,000 Mmbtu |
|
NYMEX Henry Hub |
|
$3.39 |
|
January - March 2025 |
|
60,000 Mmbtu |
|
NYMEX Henry Hub |
|
$4.16 |
|
January - March 2025 |
|
50,000 Mmbtu |
|
NYMEX Henry Hub |
|
$3.51 |
|
April - October 2025 |
|
100,000 Mmbtu |
|
NYMEX Henry Hub |
|
$3.28 |
|
Oil costless collars |
|
|
|
|
|
|
|
June 2024 |
|
1,650 Bbls |
|
NYMEX WTI |
|
$63.00 floor / $76.00 ceiling |
|
June 2024 |
|
500 Bbls |
|
NYMEX WTI |
|
$65.00 floor / $76.50 ceiling |
|
June - September 2024 |
|
500 Bbls |
|
NYMEX WTI |
|
$70.00 floor / $78.10 ceiling |
|
July - October 2024 |
|
1,650 Bbls |
|
NYMEX WTI |
|
$65.00 floor / $76.50 ceiling |
|
October - December 2024 |
|
500 Bbls |
|
NYMEX WTI |
|
$67.00 floor / $77.00 ceiling |
|
Oil fixed price swaps |
|
|
|
|
|
|
|
June - October 2024 |
|
1,000 Bbls |
|
NYMEX WTI |
|
$66.10 |
|
June 2024 |
|
1,300 Bbls |
|
NYMEX WTI |
|
$70.59 |
|
July - October 2024 |
|
1,500 Bbls |
|
NYMEX WTI |
|
$69.50 |
|
September 2024 |
|
500 Bbls |
|
NYMEX WTI |
|
$76.46 |
|
October 2024 |
|
500 Bbls |
|
NYMEX WTI |
|
$76.12 |
|
November 2024 |
|
500 Bbls |
|
NYMEX WTI |
|
$75.49 |
|
November - December 2024 |
|
2,000 Bbls |
|
NYMEX WTI |
|
$69.50 |
|
November 2024 - March 2025 |
|
1,600 Bbls |
|
NYMEX WTI |
|
$64.80 |
|
December 2024 |
|
500 Bbls |
|
NYMEX WTI |
|
$74.94 |
|
January 2025 |
|
500 Bbls |
|
NYMEX WTI |
|
$74.48 |
|
January - March 2025 |
|
500 Bbls |
|
NYMEX WTI |
|
$69.50 |
|
January - June 2025 |
|
2,000 Bbls |
|
NYMEX WTI |
|
$70.90 |
|
February 2025 |
|
500 Bbls |
|
NYMEX WTI |
|
$74.10 |
|
March 2025 |
|
500 Bbls |
|
NYMEX WTI |
|
$73.71 |
|
April 2025 |
|
500 Bbls |
|
NYMEX WTI |
|
$73.30 |
|
April - June 2025 |
|
750 Bbls |
|
NYMEX WTI |
|
$69.50 |
|
April - June 2025 |
|
1,000 Bbls |
|
NYMEX WTI |
|
$68.00 |
|
May 2025 |
|
500 Bbls |
|
NYMEX WTI |
|
$72.92 |
|
June 2025 |
|
500 Bbls |
|
NYMEX WTI |
|
$72.58 |
|
July 2025 |
|
500 Bbls |
|
NYMEX WTI |
|
$72.24 |
|
July - September 2025 |
|
500 Bbls |
|
NYMEX WTI |
|
$69.50 |
|
July - December 2025 |
|
1,500 Bbls |
|
NYMEX WTI |
|
$68.90 |
|
August 2025 |
|
500 Bbls |
|
NYMEX WTI |
|
$71.88 |
|
September 2025 |
|
500 Bbls |
|
NYMEX WTI |
|
$71.60 |
|
October 2025 |
|
750 Bbls |
|
NYMEX WTI |
|
$71.12 |
|
November 2025 |
|
750 Bbls |
|
NYMEX WTI |
|
$70.99 |
|
December 2025 |
|
750 Bbls |
|
NYMEX WTI |
|
$70.66 |
|
January 2026 |
|
1,500 Bbls |
|
NYMEX WTI |
|
$70.53 |
|
February 2026 |
|
1,500 Bbls |
|
NYMEX WTI |
|
$71.28 |
|
March 2026 |
|
1,500 Bbls |
|
NYMEX WTI |
|
$70.42 |
Non-GAAP Reconciliation
This press release includes certain “non-GAAP financial measures” as defined under the rules and regulations of the U.S. Securities and Exchange Commission, or the SEC, including Regulation G. These non-GAAP financial measures are calculated using GAAP amounts in the Company’s financial statements. These measures, detailed below, are provided in addition to, not as an alternative for, and should be read in conjunction with, the information contained in the Company’s financial statements prepared in accordance with GAAP (including the notes thereto), included in the Company’s SEC filings and posted on its website.
Adjusted EBITDA Reconciliation
The Company defines “adjusted EBITDA” as earnings before interest, taxes, depreciation and amortization, or EBITDA, excluding non-cash gains (losses) on derivatives and gains (losses) on asset sales and including cash receipts from (payments on) off-market derivatives and restricted stock and deferred directors’ expense. The Company has included a presentation of adjusted EBITDA because it recognizes that certain investors consider this amount to be a useful means of measuring the Company’s ability to meet its debt service obligations and evaluating its financial performance. Adjusted EBITDA has limitations and should not be considered in isolation or as a substitute for net income, operating income, cash flow from operations or other consolidated income or cash flow data prepared in accordance with GAAP. Because not all companies use identical calculations, this presentation of adjusted EBITDA may not be comparable to a similarly titled measure of other companies. The following table provides a reconciliation of net income (loss) to adjusted EBITDA for the quarters indicated:
|
|
Three Months Ended |
|
|
Three Months Ended |
|
|
Six Months Ended |
|
|
Six Months Ended |
|
|
Three Months Ended |
|
|||||
|
|
June 30, 2024 |
|
|
June 30, 2023 |
|
|
June 30, 2024 |
|
|
June 30, 2023 |
|
|
Mar. 31, 2024 |
|
|||||
|
Net Income |
$ |
1,295,771 |
|
|
$ |
(41,291 |
) |
|
$ |
1,112,156 |
|
|
$ |
9,511,953 |
|
|
$ |
(183,615 |
) |
|
Plus: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||
|
Income tax expense |
|
355,151 |
|
|
|
(166,000 |
) |
|
|
397,483 |
|
|
|
2,901,000 |
|
|
|
42,332 |
|
|
Interest expense |
|
651,982 |
|
|
|
524,294 |
|
|
|
1,366,868 |
|
|
|
1,081,767 |
|
|
|
714,886 |
|
|
DD&A |
|
2,268,284 |
|
|
|
2,210,332 |
|
|
|
4,624,610 |
|
|
|
4,100,322 |
|
|
|
2,356,326 |
|
|
Impairment expense |
|
- |
|
|
|
- |
|
|
|
- |
|
|
|
2,073 |
|
|
|
- |
|
|
Less: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||
|
Non-cash gains (losses) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||
|
on derivatives |
|
(1,603,604 |
) |
|
|
(865,935 |
) |
|
|
(2,645,421 |
) |
|
|
2,306,464 |
|
|
|
(1,041,817 |
) |
|
Gains (losses) on asset sales |
|
445,184 |
|
|
|
10,230 |
|
|
|
511,684 |
|
|
|
4,428,213 |
|
|
|
66,500 |
|
|
Plus: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||
|
Cash payments on off-market derivative |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||
|
contracts |
|
- |
|
|
|
- |
|
|
|
- |
|
|
|
(373,745 |
) |
|
|
- |
|
|
Restricted stock and deferred |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||
|
director's expense |
|
696,559 |
|
|
|
703,667 |
|
|
|
1,398,347 |
|
|
|
1,338,254 |
|
|
|
701,788 |
|
|
Adjusted EBITDA |
$ |
6,426,167 |
|
|
$ |
4,086,707 |
|
|
$ |
11,033,201 |
|
|
$ |
11,826,947 |
|
|
$ |
4,607,034 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||
Debt-to-Adjusted EBITDA (TTM) Reconciliation
“Debt-to-adjusted EBITDA (TTM)” is defined as the ratio of long-term debt to adjusted EBITDA on a trailing 12-month (TTM) basis. The Company has included a presentation of debt-to-adjusted EBITDA (TTM) because it recognizes that certain investors consider such ratios to be a useful means of measuring the Company’s ability to meet its debt service obligations and for evaluating its financial performance. The debt-to-adjusted EBITDA (TTM) ratio has limitations and should not be considered in isolation or as a substitute for net income, operating income, cash flow from operations or other consolidated income or cash flow data prepared in accordance with GAAP. Because not all companies use identical calculations, this presentation of debt-to-adjusted EBITDA (TTM) may not be comparable to a similarly titled measure of other companies. The following table provides a reconciliation of net income (loss) to adjusted EBITDA on a TTM basis and of the resulting debt-to-adjusted EBITDA (TTM) ratio:
|
|
TTM Ended |
|
|
TTM Ended |
|
||
|
|
June 30, 2024 |
|
|
June 30, 2023 |
|
||
|
Net Income |
$ |
5,521,003 |
|
|
$ |
22,016,554 |
|
|
Plus: |
|
|
|
|
|
||
|
Income tax expense |
|
2,231,943 |
|
|
|
6,313,000 |
|
|
Interest expense |
|
2,647,494 |
|
|
|
2,191,181 |
|
|
DD&A |
|
9,090,473 |
|
|
|
7,452,846 |
|
|
Impairment expense |
|
36,460 |
|
|
|
6,105,472 |
|
|
Less: |
|
|
|
|
|
||
|
Non-cash gains (losses) |
|
|
|
|
|
||
|
on derivatives |
|
(649,354 |
) |
|
|
10,211,207 |
|
|
Gains (losses) on asset sales |
|
812,230 |
|
|
|
8,921,031 |
|
|
Plus: |
|
|
|
|
|
||
|
Cash payments on off-market derivative |
|
|
|
|
|
||
|
contracts |
|
- |
|
|
|
(2,334,403 |
) |
|
Restricted stock and deferred |
|
|
|
|
|
||
|
director's expense |
|
2,494,021 |
|
|
|
2,944,517 |
|
|
Adjusted EBITDA |
$ |
21,858,518 |
|
|
$ |
25,556,929 |
|
|
|
|
|
|
|
|
||
|
Debt |
$ |
28,750,000 |
|
|
$ |
23,750,000 |
|
|
Debt-to-Adjusted EBITDA (TTM) |
|
1.32 |
|
|
|
0.93 |
|
|
|
|
|
|
|
|
||
PHX Minerals Inc. Fort Worth-based, PHX Minerals Inc. is a natural gas and oil mineral company with a strategy to proactively grow its mineral position in its core focus areas. PHX owns mineral acreage principally located in Oklahoma, Texas, Louisiana, North Dakota and Arkansas. Additional information about the Company can be found at www.phxmin.com.
Cautionary Statement Regarding Forward-Looking Statements
This press release includes “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. Words such as “anticipates,” “plans,” “estimates,” “believes,” “expects,” “intends,” “will,” “should,” “may” and similar expressions may be used to identify forward-looking statements. Forward-looking statements are not statements of historical fact and reflect PHX’s current views about future events. Forward-looking statements may include, but are not limited to, statements relating to: the Company’s operational outlook; the Company’s ability to execute its business strategies; the volatility of realized natural gas and oil prices; the level of production on the Company’s properties; estimates of quantities of natural gas, oil and NGL reserves and their values; general economic or industry conditions; legislation or regulatory requirements; conditions of the securities markets; the Company’s ability to raise capital; changes in accounting principles, policies or guidelines; financial or political instability; acts of war or terrorism; title defects in the properties in which the Company invests; and other economic, competitive, governmental, regulatory or technical factors affecting properties, operations or prices. Although the Company believes expectations reflected in these and other forward-looking statements are reasonable, the Company can give no assurance such expectations will prove to be correct. Such forward-looking statements are subject to a number of assumptions, risks and uncertainties, many of which are beyond the control of the Company. These forward-looking statements involve certain risks and uncertainties that could cause results to differ materially from those expected by the Company’s management. Information concerning these risks and other factors can be found in the Company’s filings with the SEC, including its Annual Reports on Form 10-K and Quarterly Reports on Form 10-Q, available on the Company’s website or the SEC’s website at www.sec.gov.
Investors are cautioned that any such forward-looking statements are not guarantees of future performance and that actual results or developments may differ materially from those projected. The forward-looking statements in this press release are made as of the date hereof, and the Company does not undertake any obligation to update the forward-looking statements as a result of new information, future events or otherwise.
Investor Contact:
Rob Fink / Stephen Lee
FNK IR
646.809.4048
Corporate Contact:
405.948.1560