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PHX Minerals Reports Results for the Quarter Ended March 31, 2025 and Announces Dividend Payment

PHX Minerals Reports Results for the Quarter Ended March 31, 2025 and Announces Dividend Payment

FORT WORTH, Texas, May 8, 2025 – PHX MINERALS INC., “PHX” or the “Company” (NYSE: PHX), today reported financial and operating results for the quarter ended March 31, 2025.

 

Summary of Results for the Quarter Ended March 31, 2025

  • Net income was $4.4 million, or $0.12 per diluted share, compared to net income of $0.1 million, or $0.00 per diluted share, for the quarter ended Dec. 31, 2024, and net loss of ($0.2) million, or ($0.01) per diluted share, for the quarter ended March 31, 2024.
  • Adjusted EBITDA(1) was $6.2 million, compared to $5.4 million for the quarter ended Dec. 31, 2024 and $4.6 million for the quarter ended March 31, 2024.
  • Royalty production volumes decreased 9% to 1,910 Mmcfe compared to the quarter ended Dec. 31, 2024, and increased 3% compared to the quarter ended March 31, 2024.
  • Total production volumes decreased 9% to 2,159 Mmcfe compared to the quarter ended Dec. 31, 2024, and increased 2% compared to the quarter ended March 31, 2024.
  • Converted 65 gross (0.113 net) wells to producing status, compared to a conversion of 71 gross (0.22 net) wells to producing status during the quarter ended Dec. 31, 2024 and 85 gross (0.32 net) during the quarter ended March 31, 2024.
  • Inventory of 247 gross (1.017 net) wells in progress and permits as of March 31, 2025, compared to 225 gross (0.91 net) wells in progress and permits as of Dec. 31, 2024 and 230 gross (1.099 net) wells in progress and permits as of March 31, 2024.
  • Total debt was $19.8 million, down $9.8 million since Dec. 31, 2024, and the debt-to-adjusted EBITDA (TTM) (1) ratio was 0.86x at March 31, 2025.

 

Subsequent Events

  • PHX announced a $0.04 per share quarterly dividend, payable on June 4, 2025, to stockholders of record on May 20, 2025.
  • In a separate press release also issued today, WhiteHawk Income Corporation (together with WhiteHawk Energy, LLC and their respective subsidiaries, “WhiteHawk”) and PHX announced that they have entered into a definitive agreement under which WhiteHawk will acquire PHX in an all-cash transaction that values PHX at $4.35 per share, or total value of approximately $187 million, including PHX’s net debt. The joint press release announcing the transaction is available at https://phxmin.com/news/press-releases.
  • In light of the pending all-cash transaction with WhiteHawk, PHX is canceling its previously scheduled quarterly conference call to discuss the Company's results for the quarter ended March 31, 2025.
  1. This is a non-GAAP measure. Refer to the Non-GAAP Reconciliation section.

Chad L. Stephens, President and CEO, commented,“PHX had a strong start to 2025, delivering solid cash flow and adjusted EBITDA on both a sequential and year-over-year basis.  The closing of our recent divestiture of non-producing minerals in January, along with strong cash generation, enabled us to further reduce our debt to $19.8 million as of March 31, 2025, resulting in a debt-to-adjusted EBITDA (TTM) ratio under 1x. A strong and flexible balance sheet continues to be an important part of our strategy.”

 “The natural gas environment showed meaningful improvement during the first quarter driven by tightening supply-demand dynamics, colder-than-expected winter weather, and increasing liquefied natural gas (LNG) export demand. This backdrop is translating into heightened operator activity across our mineral acreage as demonstrated by a higher gross and net number of wells in progress as of the quarter end. We expect this trend to continue throughout 2025 and into 2026, supporting the increased production volumes and enhanced cash flow from our assets.”

 

Financial Highlights

 

 

 

Three Months Ended

 

 

Three Months Ended

 

 

 

March 31, 2025

 

 

March 31, 2024

 

Royalty Interest Sales

 

$

9,288,424

 

 

$

6,176,274

 

Working Interest Sales

 

$

1,144,863

 

 

$

913,934

 

Natural Gas, Oil and NGL Sales

 

$

10,433,287

 

 

$

7,090,208

 

 

 

 

 

 

 

 

Gains (Losses) on Derivative Contracts

 

$

(3,163,178

)

 

$

627,492

 

Lease Bonuses and Rental Income

 

$

328,203

 

 

$

151,718

 

Total Revenue

 

$

7,598,312

 

 

$

7,869,418

 

 

 

 

 

 

 

 

Lease Operating Expense

 

 

 

 

 

 

per Working Interest Mcfe

 

$

1.10

 

 

$

1.28

 

Transportation, Gathering and

 

 

 

 

 

 

Marketing per Mcfe

 

$

0.51

 

 

$

0.40

 

Production and Ad Valorem Tax

 

 

 

 

 

 

per Mcfe

 

$

0.20

 

 

$

0.19

 

G&A Expense per Mcfe

 

$

1.74

 

 

$

1.58

 

Cash G&A Expense per Mcfe (1)

 

$

1.15

 

 

$

1.25

 

Interest Expense per Mcfe

 

$

0.21

 

 

$

0.34

 

DD&A per Mcfe

 

$

1.13

 

 

$

1.11

 

Total Expense per Mcfe

 

$

3.92

 

 

$

3.78

 

 

 

 

 

 

 

 

Net Income (Loss)

 

$

4,383,882

 

 

$

(183,615

)

Adjusted EBITDA (2)

 

$

6,161,219

 

 

$

4,607,034

 

 

 

 

 

 

 

 

Cash Flow from Operations (3)

 

$

4,276,440

 

 

$

5,246,651

 

CapEx (4)

 

$

6,336

 

 

$

7,440

 

CapEx - Mineral Acquisitions

 

$

630,296

 

 

$

1,406,248

 

 

 

 

 

 

 

 

Borrowing Base

 

$

50,000,000

 

 

$

50,000,000

 

Debt

 

$

19,750,000

 

 

$

30,750,000

 

Debt-to-Adjusted EBITDA (TTM) (2)

 

 

0.86

 

 

 

1.58

 

 

  1. Cash G&A expense is G&A excluding professional fees associated with announced strategic alternatives process and restricted stock and deferred director’s expense from the adjusted EBITDA table in the Non-GAAP Reconciliation section.
  2. This is a non-GAAP measure. Refer to the Non-GAAP Reconciliation section.
  3. GAAP cash flow from operations.
  4. Includes legacy working interest expenditures and fixtures and equipment.

 

Operating Highlights

 

Three Months Ended

 

 

Three Months Ended

 

 

March 31, 2025

 

 

March 31, 2024

 

Gas Mcf Sold

 

1,729,256

 

 

 

1,700,108

 

Average Sales Price per Mcf before the

 

 

 

 

 

effects of settled derivative contracts

$

3.85

 

 

$

2.10

 

Average Sales Price per Mcf after the

 

 

 

 

 

effects of settled derivative contracts

$

3.75

 

 

$

3.08

 

% of sales subject to hedges

 

75

%

 

 

62

%

Oil Barrels Sold

 

42,355

 

 

 

37,260

 

Average Sales Price per Bbl before the

 

 

 

 

 

effects of settled derivative contracts

$

70.52

 

 

$

76.01

 

Average Sales Price per Bbl after the

 

 

 

 

 

effects of settled derivative contracts

$

69.25

 

 

$

76.19

 

% of sales subject to hedges

 

40

%

 

 

37

%

NGL Barrels Sold

 

29,316

 

 

 

32,184

 

Average Sales Price per Bbl(1)

$

27.18

 

 

$

21.51

 

 

 

 

 

 

 

Mcfe Sold

 

2,159,284

 

 

 

2,116,776

 

Natural gas, oil and NGL sales before the

 

 

 

 

 

effects of settled derivative contracts

$

10,433,287

 

 

$

7,090,208

 

Natural gas, oil and NGL sales after the

 

 

 

 

 

effects of settled derivative contracts

$

10,214,808

 

 

$

8,759,517

 

 

 

 

 

 

 

(1) There were no NGL settled derivative contracts during the 2025 and 2024 periods.

 

Total Production for the last five quarters was as follows:

Quarter ended

 

Mcf Sold

 

 

Oil Bbls Sold

 

 

NGL Bbls Sold

 

 

Mcfe Sold

 

3/31/2025

 

 

1,729,256

 

 

 

42,355

 

 

 

29,316

 

 

 

2,159,284

 

12/31/2024

 

 

1,906,552

 

 

 

43,571

 

 

 

35,099

 

 

 

2,378,569

 

9/30/2024

 

 

1,898,442

 

 

 

45,698

 

 

 

34,332

 

 

 

2,378,622

 

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

 

 

The percentage of total production volumes attributable to natural gas was 80% for the quarter ended March 31, 2025.

 

Royalty Interest Production for the last five quarters was as follows:

 

Quarter ended

 

Mcf Sold

 

 

Oil Bbls Sold

 

 

NGL Bbls Sold

 

 

Mcfe Sold

 

3/31/2025

 

 

1,567,816

 

 

 

38,200

 

 

 

18,747

 

 

 

1,909,502

 

12/31/2024

 

 

1,728,225

 

 

 

39,592

 

 

 

21,778

 

 

 

2,096,435

 

9/30/2024

 

 

1,724,635

 

 

 

41,170

 

 

 

21,011

 

 

 

2,097,722

 

6/30/2024(1)

 

 

2,304,176

 

 

 

47,024

 

 

 

20,461

 

 

 

2,709,090

 

3/31/2024

 

 

1,533,580

 

 

 

33,083

 

 

 

20,844

 

 

 

1,857,147

 

 

(1) Increase in royalty production for the quarter ended June 30, 2024 was due to high interest high impact wells coming online in the Haynesville.

 

The percentage of royalty production volumes attributable to natural gas was 82% for the quarter ended March 31, 2025.

 

Working Interest Production for the last five quarters was as follows:

 

Quarter ended

 

Mcf Sold

 

 

Oil Bbls Sold

 

 

NGL Bbls Sold

 

 

Mcfe Sold

 

3/31/2025

 

 

161,440

 

 

 

4,155

 

 

 

10,569

 

 

 

249,782

 

12/31/2024

 

 

178,327

 

 

 

3,979

 

 

 

13,321

 

 

 

282,134

 

9/30/2024

 

 

173,807

 

 

 

4,528

 

 

 

13,321

 

 

 

280,900

 

6/30/2024

 

 

160,670

 

 

 

4,804

 

 

 

11,533

 

 

 

258,689

 

3/31/2024

 

 

166,528

 

 

 

4,177

 

 

 

11,340

 

 

 

259,629

 

 

Quarter Ended March 31, 2025 Results

The Company recorded net income of $4.4 million, or $0.12 per diluted share, for the quarter ended March 31, 2025, as compared to net loss of $(0.2) million, or $(0.01) per diluted share, for the quarter ended March 31, 2024. The change in net income was principally the result of an increase in natural gas, oil and NGL sales and an increase in gain on asset sales, partially offset by an increase in losses associated with derivative contracts, an increase in general and administrative expenses, and an increase in transportation, gathering and marketing expenses.

Natural gas, oil and NGL revenue increased $3.3 million, or 47%, for the quarter ended March 31, 2025, compared to the quarter ended March 31, 2024, due to increases in natural gas and NGL prices of 83% and 26%, respectively, and increases in natural gas and oil volumes of 2% and 14%, respectively, partially offset by a decrease in oil price of 7% and a decrease in NGL volumes of 9%.

The increase in royalty production volumes during the quarter ended March 31, 2025, as compared to the quarter ended March 31, 2024, resulted primarily from new wells being brought online in the Haynesville Shale and SCOOP plays.

The Company had a net loss on derivative contracts of ($3.2) million for the quarter ended March 31, 2025, comprised of a ($0.2) million loss on settled derivatives and a ($2.9) million non-cash loss on derivatives, as compared to a net gain of $0.6 million for the quarter ended March 31, 2024. The change in net gain (loss) 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 March 31, 2025 pricing relative to the strike price on open derivative contracts.

Operations Update

During the quarter ended March 31, 2025, the Company converted 65 gross (0.113 net) wells to producing status, including 5 gross (0.009 net) wells in the Haynesville and 26 gross (0.036 net) wells in the SCOOP, compared to 85 gross (0.32 net) wells converted in the quarter ended March 31, 2024.

At March 31, 2025, the Company had a total of 247 gross (1.017 net) wells in progress and permits across its mineral positions, compared to 225 gross (0.91 net) wells in progress and permits at Dec 31, 2024. As of March 31, 2025, 18 rigs were operating on the Company’s acreage and 70 rigs were operating within 2.5 miles of its acreage.

 

 

 

 

 

 

 

Bakken/

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Three

 

 

Arkoma

 

 

 

 

 

 

 

 

 

 

 

SCOOP

 

 

STACK

 

 

Forks

 

 

Stack

 

 

Haynesville

 

 

Other

 

 

Total

 

As of March 31, 2025:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Gross Wells in Progress on PHX Acreage (1)

 

61

 

 

 

14

 

 

 

11

 

 

 

3

 

 

 

70

 

 

 

13

 

 

 

172

 

Net Wells in Progress on PHX Acreage (1)

 

0.222

 

 

 

0.025

 

 

 

0.044

 

 

 

0.015

 

 

 

0.362

 

 

 

0.067

 

 

 

0.735

 

Gross Active Permits on PHX Acreage

 

28

 

 

 

9

 

 

 

3

 

 

 

4

 

 

 

28

 

 

 

3

 

 

 

75

 

Net Active Permits on PHX Acreage

 

0.090

 

 

 

0.083

 

 

 

0.003

 

 

 

0.028

 

 

 

0.066

 

 

 

0.012

 

 

 

0.282

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

As of March 31, 2025:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Rigs Present on PHX Acreage

 

6

 

 

 

1

 

 

 

1

 

 

 

-

 

 

 

3

 

 

 

7

 

 

 

18

 

Rigs Within 2.5 Miles of PHX Acreage

 

18

 

 

 

10

 

 

 

9

 

 

 

2

 

 

 

17

 

 

 

14

 

 

 

70

 

(1) Wells in progress includes drilling wells and drilled but uncompleted wells, or DUCs.

 

Leasing Activity

During the quarter ended March 31, 2025, the Company leased 397 net mineral acres to third-party exploration and production companies for an average bonus payment of $911 per net mineral acre and an average royalty of 25%.

 

Acquisition and Divestiture Update

During the quarter ended March 31, 2025, the Company purchased 50 net royalty acres for approximately $0.6 million and sold 165,326 acres, which were outside the Company’s core focus areas and predominately undeveloped and unleased, for approximately $7.9 million.

 

 

Acquisitions

 

 

 

SCOOP

 

 

Haynesville

 

 

Other

 

 

Total

 

During Three Months Ended March 31, 2025:

 

 

 

 

 

 

 

 

 

 

 

 

Net Mineral Acres Purchased

 

 

35

 

 

 

-

 

 

 

-

 

 

 

35

 

Net Royalty Acres Purchased

 

 

50

 

 

 

-

 

 

 

-

 

 

 

50

 

Quarterly Conference Call

In light of the pending all-cash transaction with WhiteHawk, PHX is canceling its previously scheduled quarterly conference call to discuss the Company's results for the quarter ended March 31, 2025.

 

 

FINANCIAL RESULTS

Statements of Income

 

Three Months Ended March 31,

 

 

2025

 

 

2024

 

Revenues:

(unaudited)

 

Natural gas, oil and NGL sales

$

10,433,287

 

 

$

7,090,208

 

Lease bonuses and rental income

 

328,203

 

 

 

151,718

 

Gains (losses) on derivative contracts

 

(3,163,178

)

 

 

627,492

 

 

 

7,598,312

 

 

 

7,869,418

 

Costs and expenses:

 

 

 

 

 

Lease operating expenses

 

273,713

 

 

 

332,409

 

Transportation, gathering and marketing

 

1,103,966

 

 

 

843,504

 

Production and ad valorem taxes

 

422,787

 

 

 

392,327

 

Depreciation, depletion and amortization

 

2,430,207

 

 

 

2,356,326

 

Interest expense

 

452,051

 

 

 

714,886

 

General and administrative

 

3,754,248

 

 

 

3,347,037

 

Losses (gains) on asset sales and other

 

(6,519,747

)

 

 

24,212

 

Total costs and expenses

 

1,917,225

 

 

 

8,010,701

 

Income (loss) before provision (benefit) for income taxes

 

5,681,087

 

 

 

(141,283

)

 

 

 

 

 

 

Provision (benefit) for income taxes

 

1,297,205

 

 

 

42,332

 

 

 

 

 

 

 

Net income (loss)

$

4,383,882

 

 

$

(183,615

)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Basic earnings per common share

$

0.12

 

 

$

(0.01

)

 

 

 

 

 

 

Diluted earnings per common share

$

0.12

 

 

$

(0.01

)

 

 

 

 

 

 

Weighted average shares outstanding:

 

 

 

 

 

Basic

 

36,808,766

 

 

 

36,303,392

 

Diluted

 

38,009,410

 

 

 

36,303,392

 

 

 

 

 

 

 

Dividends per share of

 

 

 

 

 

common stock paid in period

$

0.0400

 

 

$

0.0300

 

 

 

 

 

 

 

Balance Sheets

 

 

 

March 31, 2025

 

 

 

 

 

(unaudited)

 

 

Dec. 31, 2024

 

Assets

 

 

 

 

 

Current assets:

 

 

 

 

 

Cash and cash equivalents

$

2,536,133

 

 

$

2,242,102

 

Natural gas, oil, and NGL sales receivables (net of $0

 

6,577,696

 

 

 

6,128,954

 

allowance for uncollectable accounts)

 

 

 

 

 

Refundable income taxes

 

80,621

 

 

 

328,560

 

Other

 

721,062

 

 

 

857,317

 

Total current assets

 

9,915,512

 

 

 

9,556,933

 

 

 

 

 

 

 

Properties and equipment at cost, based on

 

 

 

 

 

   successful efforts accounting:

 

 

 

 

 

Producing natural gas and oil properties

 

223,655,459

 

 

 

223,043,942

 

Non-producing natural gas and oil properties

 

45,544,346

 

 

 

51,806,911

 

Other

 

1,361,064

 

 

 

1,361,064

 

 

 

270,560,869

 

 

 

276,211,917

 

Less accumulated depreciation, depletion and amortization

 

(120,293,049

)

 

 

(122,835,668

)

Net properties and equipment

 

150,267,820

 

 

 

153,376,249

 

 

 

 

 

 

 

Operating lease right-of-use assets

 

392,263

 

 

 

429,494

 

Other, net

 

509,837

 

 

 

553,090

 

Total assets

$

161,085,432

 

 

$

163,915,766

 

 

 

 

 

 

 

Liabilities and Stockholders' Equity

 

 

 

 

 

Current liabilities:

 

 

 

 

 

Accounts payable

$

656,711

 

 

$

804,693

 

Derivative contracts, net

 

3,178,706

 

 

 

316,336

 

Current portion of operating lease liability

 

252,436

 

 

 

247,786

 

Accrued liabilities and other

 

1,420,856

 

 

 

1,866,930

 

Total current liabilities

 

5,508,709

 

 

 

3,235,745

 

 

 

 

 

 

 

Long-term debt

 

19,750,000

 

 

 

29,500,000

 

Deferred income taxes, net

 

8,318,416

 

 

 

7,286,315

 

Asset retirement obligations

 

1,098,536

 

 

 

1,097,750

 

Derivative contracts, net

 

480,401

 

 

 

398,072

 

Operating lease liability, net of current portion

 

383,070

 

 

 

448,031

 

Total liabilities

 

35,539,132

 

 

 

41,965,913

 

 

 

 

 

 

 

Stockholders' equity:

 

 

 

 

 

Common Stock, $0.01666 par value; 75,000,000 shares authorized and

 

 

 

 

 

36,796,496 issued at March 31, 2025; 75,000,000 shares authorized and 36,796,496 issued at Dec. 31, 2024

 

613,030

 

 

 

613,030

 

Capital in excess of par value

 

44,749,269

 

 

 

44,029,492

 

Deferred directors' compensation

 

1,313,492

 

 

 

1,323,760

 

Retained earnings

 

79,940,318

 

 

 

77,073,332

 

 

 

126,616,109

 

 

 

123,039,614

 

Less treasury stock, at cost; 274,478 shares at March 31,

 

 

 

 

 

2025, and 279,594 shares at Dec. 31, 2024

 

(1,069,809

)

 

 

(1,089,761

)

Total stockholders' equity

 

125,546,300

 

 

 

121,949,853

 

Total liabilities and stockholders' equity

$

161,085,432

 

 

$

163,915,766

 

 

 

Condensed Statements of Cash Flows

 

 

Three Months Ended

 

 

March 31, 2025

 

 

March 31, 2024

 

Operating Activities

(unaudited)

 

Net income (loss)

$

4,383,882

 

 

$

(183,615

)

Adjustments to reconcile net income (loss) to net cash provided

 

 

 

 

 

  by operating activities:

 

 

 

 

 

Depreciation, depletion and amortization

 

2,430,207

 

 

 

2,356,326

 

Provision for deferred income taxes

 

1,032,101

 

 

 

25,332

 

Gain from leasing fee mineral acreage

 

(328,203

)

 

 

(151,718

)

Proceeds from leasing fee mineral acreage

 

332,331

 

 

 

151,718

 

Net (gain) loss on sales of assets

 

(6,625,686

)

 

 

(66,500

)

Directors' deferred compensation expense

 

47,738

 

 

 

45,132

 

Total (gain) loss on derivative contracts

 

3,163,178

 

 

 

(627,492

)

Cash receipts (payments) on settled derivative contracts

 

(218,479

)

 

 

1,669,309

 

Restricted stock award expense

 

681,723

 

 

 

656,656

 

Other

 

25,333

 

 

 

35,731

 

Cash provided (used) by changes in assets and liabilities:

 

 

 

 

 

Natural gas, oil and NGL sales receivables

 

(448,742

)

 

 

1,216,455

 

Income taxes receivable

 

247,939

 

 

 

378

 

Other current assets

 

202,745

 

 

 

207,497

 

Accounts payable

 

(145,867

)

 

 

67,986

 

Other non-current assets

 

58,642

 

 

 

56,338

 

Accrued liabilities

 

(562,402

)

 

 

(212,882

)

Total adjustments

 

(107,442

)

 

 

5,430,266

 

Net cash provided by operating activities

 

4,276,440

 

 

 

5,246,651

 

 

 

 

 

 

 

Investing Activities

 

 

 

 

 

Capital expenditures

 

(6,336

)

 

 

(7,440

)

Acquisition of minerals and overriding royalty interests

 

(630,296

)

 

 

(1,406,248

)

Net proceeds from sales of assets

 

7,865,103

 

 

 

66,500

 

Net cash provided by (used in) investing activities

 

7,228,471

 

 

 

(1,347,188

)

 

 

 

 

 

 

Financing Activities

 

 

 

 

 

Borrowings under credit facility

 

-

 

 

 

1,000,000

 

Payments of loan principal

 

(9,750,000

)

 

 

(3,000,000

)

Payments of dividends

 

(1,460,880

)

 

 

(1,079,968

)

Net cash provided by (used in) financing activities

 

(11,210,880

)

 

 

(3,079,968

)

 

 

 

 

 

 

Increase (decrease) in cash and cash equivalents

 

294,031

 

 

 

819,495

 

Cash and cash equivalents at beginning of period

 

2,242,102

 

 

 

806,254

 

Cash and cash equivalents at end of period

$

2,536,133

 

 

$

1,625,749

 

 

 

 

 

 

 

Supplemental Disclosures of Cash Flow Information:

 

 

 

 

 

 

 

 

 

 

 

Interest paid (net of capitalized interest)

$

503,184

 

 

$

733,799

 

Income taxes paid (net of refunds received)

$

17,165

 

 

$

16,623

 

 

 

 

 

 

 

Supplemental Schedule of Noncash Investing and Financing Activities:

 

 

 

 

 

 

 

 

 

 

 

Dividends declared and unpaid

$

56,016

 

 

$

41,346

 

 

 

 

 

 

 

Gross additions to properties and equipment

$

568,026

 

 

$

1,406,743

 

Net increase (decrease) in accounts receivable for properties

 

 

 

 

 

and equipment additions

 

68,606

 

 

 

6,945

 

Capital expenditures and acquisitions

$

636,632

 

 

$

1,413,688

 

 

 

Derivative Contracts as of March 31, 2025

 

 

Production volume

 

 

 

 

Contract period

 

covered per month

 

Index

 

Contract price

 

 

 

 

 

 

 

Natural gas costless collars

 

 

 

 

 

 

May - June 2025

 

30,000 Mmbtu

 

NYMEX Henry Hub

 

$3.00 floor / $5.00 ceiling

May - 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

 

50,000 Mmbtu

 

NYMEX Henry Hub

 

$3.50 floor / $3.87 ceiling

November 2025 - March 2026

 

15,000 Mmbtu

 

NYMEX Henry Hub

 

$3.50 floor / $5.15 ceiling

April - June 2026

 

75,000 Mmbtu

 

NYMEX Henry Hub

 

$3.00 floor / $3.60 ceiling

July - September 2026

 

100,000 Mmbtu

 

NYMEX Henry Hub

 

$3.00 floor / $3.60 ceiling

Natural gas fixed price swaps

 

 

 

 

 

 

May 2025

 

25,000 Mmbtu

 

NYMEX Henry Hub

 

$3.23

May - August 2025

 

125,000 Mmbtu

 

NYMEX Henry Hub

 

$3.01

May - October 2025

 

100,000 Mmbtu

 

NYMEX Henry Hub

 

$3.28

June 2025

 

10,000 Mmbtu

 

NYMEX Henry Hub

 

$3.23

July 2025

 

45,000 Mmbtu

 

NYMEX Henry Hub

 

$3.23

August 2025

 

40,000 Mmbtu

 

NYMEX Henry Hub

 

$3.23

September 2025

 

50,000 Mmbtu

 

NYMEX Henry Hub

 

$3.23

September - October 2025

 

100,000 Mmbtu

 

NYMEX Henry Hub

 

$3.01

October 2025

 

100,000 Mmbtu

 

NYMEX Henry Hub

 

$3.23

November 2025 - January 2026

 

25,000 Mmbtu

 

NYMEX Henry Hub

 

$4.21

February 2026

 

15,000 Mmbtu

 

NYMEX Henry Hub

 

$4.21

March 2026

 

25,000 Mmbtu

 

NYMEX Henry Hub

 

$4.21

April - June 2026

 

50,000 Mmbtu

 

NYMEX Henry Hub

 

$3.10

Oil fixed price swaps

 

 

 

 

 

 

March - August 2025

 

1,000 Bbls

 

NYMEX WTI

 

$68.80

March 2025

 

1,600 Bbls

 

NYMEX WTI

 

$64.80

March 2025

 

500 Bbls

 

NYMEX WTI

 

$69.50

March - June 2025

 

2,000 Bbls

 

NYMEX WTI

 

$70.90

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 - August 2025

 

1,250 Bbls

 

NYMEX WTI

 

$70.81

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

September 2025

 

1,500 Bbls

 

NYMEX WTI

 

$68.80

October 2025

 

750 Bbls

 

NYMEX WTI

 

$71.12

October 2025

 

2,000 Bbls

 

NYMEX WTI

 

$68.80

November 2025

 

750 Bbls

 

NYMEX WTI

 

$70.99

November 2025 - March 2026

 

1,500 Bbls

 

NYMEX WTI

 

$68.80

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

April - June 2026

 

1,000 Bbls

 

NYMEX WTI

 

$68.80

April - June 2026

 

1,000 Bbls

 

NYMEX WTI

 

$65.80

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, but including cash receipts from (payments on) off-market derivatives, and further excluding professional fees associated with announced strategic alternatives process and restricted stock and deferred directors’ expense. In prior releases, the Company generally has not excluded professional fees in defining adjusted EBITDA, but has excluded professional fees associated with the announced strategic alternatives process in defining adjusted EBITDA in this press release as the Company believes excluding these particular fees in the presentation of adjusted EBITDA may be useful to investors in their evaluation of the Company’s financial performance. 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

 

 

Three Months Ended

 

 

March 31, 2025

 

 

March 31, 2024

 

 

Dec. 31, 2024

 

Net Income

$

4,383,882

 

 

$

(183,615

)

 

$

109,400

 

Plus:

 

 

 

 

 

 

 

 

Income tax expense

 

1,297,205

 

 

 

42,332

 

 

 

(27,551

)

Interest expense

 

452,051

 

 

 

714,886

 

 

 

573,920

 

DD&A

 

2,430,207

 

 

 

2,356,326

 

 

 

2,605,809

 

Impairment expense

 

-

 

 

 

-

 

 

 

52,673

 

Professional  fees associated with announced strategic alternatives process

 

549,400

 

 

 

-

 

 

 

-

 

Less:

 

 

 

 

 

 

 

 

Non-cash gains (losses)

 

 

 

 

 

 

 

 

on derivatives

 

(2,944,699

)

 

 

(1,041,817

)

 

 

(1,509,661

)

Gains (losses) on asset sales

 

6,625,686

 

 

 

66,500

 

 

 

-

 

Plus:

 

 

 

 

 

 

 

 

Restricted stock and deferred

 

 

 

 

 

 

 

 

director's expense

 

729,461

 

 

 

701,788

 

 

 

561,603

 

Adjusted EBITDA

$

6,161,219

 

 

$

4,607,034

 

 

$

5,385,515

 

 

 

 

 

 

 

 

 

 

 

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

 

 

March 31, 2025

 

 

March 31, 2024

 

Net Income

$

6,889,363

 

 

$

4,183,941

 

Plus:

 

 

 

 

 

Income tax expense

 

2,082,060

 

 

 

1,710,792

 

Interest expense

 

2,300,433

 

 

 

2,519,806

 

DD&A

 

9,680,325

 

 

 

9,032,521

 

Professional fees associated with announced

 

 

 

 

 

strategic alternatives process

 

549,400

 

 

 

-

 

Impairment expense

 

52,673

 

 

 

36,460

 

Less:

 

 

 

 

 

Non-cash gains (losses)

 

 

 

 

 

on derivatives

 

(5,900,877

)

 

 

88,315

 

Gains (losses) on asset sales

 

7,077,578

 

 

 

377,276

 

Plus:

 

 

 

 

 

Restricted stock and deferred

 

 

 

 

 

director's expense

 

2,500,682

 

 

 

2,501,129

 

Adjusted EBITDA

$

22,878,235

 

 

$

19,519,058

 

 

 

 

 

 

 

Debt

$

19,750,000

 

 

$

30,750,000

 

Debt-to-Adjusted EBITDA (TTM)

 

0.86

 

 

 

1.58

 

 

 

 

 

 

 

 

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; the transaction with WhiteHawk; 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

PHX@fnkir.com

 

Corporate Contact:

405.948.1560

inquiry@phxmin.com