FORT WORTH, May 8, 2024 - PHX Minerals Inc., "PHX" or the "Company" (NYSE: PHX), today reported financial and operating results for the quarter ended March 31, 2024.
Summary of Results for the Quarter Ended March 31, 2024
Net loss was ($0.2) million, or ($0.01) per diluted share, compared to net income of $2.5 million, or $0.07 per diluted share, for the quarter ended Dec. 31, 2023.
Adjusted EBITDA(1) was $4.6 million, compared to $4.5 million for the quarter ended Dec. 31, 2023.
Royalty production volumes decreased 5% to 1,857 Mmcfe compared to the quarter ended Dec. 31, 2023.
Total production volumes decreased 6% to 2,117 Mmcfe compared to the quarter ended Dec. 31, 2023.
Converted 85 gross (0.32 net) wells to producing status, compared to 46 gross (0.098 net) during the quarter ended Dec. 31, 2023.
Inventory of 230 gross (1.099 net) wells in progress and permits as of March 31, 2024, compared to 263 gross (1.295 net) wells in progress and permits as of Dec. 31, 2023.
Total debt was $30.8 million and the debt to adjusted EBITDA (TTM) (1) ratio was 1.58x at March 31, 2024.
Subsequent Events
PHX entered into the sixth amendment to its credit agreement on April 18, 2024, pursuant to which, among other changes, the maturity date was extended to Sept. 1, 2028, and the borrowing base under PHX's credit facility was reaffirmed at $50.0 million in connection with its regularly scheduled semi-annual redetermination.
(1)
This is a non-GAAP measure. Refer to the Non-GAAP Reconciliation section.
Chad L. Stephens, President and CEO, commented, "PHX Minerals continues to deliver positive Adjusted EBITDA and cash flow, servicing our dividend and lowering our debt by $2.0 million from last quarter, despite the significant commodity headwinds. With 0.32 net wells converted to production this quarter, the highest since the quarter ended March 31, 2023, it demonstrates the acreage quality through our asset acquisition strategy. The number of rigs operating on the Company's acreage and its surrounding area increased since our last update, even during the current challenging pricing environment with reduced drilling activities industry-wide, further validates our methodical strategy of acquiring acreage ahead of the drill-bits.
"In addition to the LNG export demand I have previously mentioned," continued Mr. Stephens, "artificial intelligence/data center related power demand is an emerging driver for the natural gas markets going forward. With our strong financial position and a proven business strategy, we expect to continue to unlock stockholder value as we navigate through the current commodity cycle."
Financial Highlights
Three Months Ended
Three Months Ended
March 31, 2024
March 31, 2023
Royalty Interest Sales
$
6,176,274
$
10,123,741
Working Interest Sales
$
913,934
$
1,733,506
Natural Gas, Oil and NGL Sales
$
7,090,208
$
11,857,247
Gains (Losses) on Derivative Contracts
$
627,492
$
3,802,820
Lease Bonuses and Rental Income
$
151,718
$
313,150
Total Revenue
$
7,869,418
$
15,973,217
Lease Operating Expense
per Working Interest Mcfe
$
1.28
$
1.48
Transportation, Gathering and Marketing
per Mcfe
$
0.40
$
0.45
Production and Ad Valorem Tax per Mcfe
$
0.19
$
0.22
G&A Expense per Mcfe
$
1.58
$
1.20
Cash G&A Expense per Mcfe (1)
$
1.25
$
0.95
Interest Expense per Mcfe
$
0.34
$
0.22
DD&A per Mcfe
$
1.11
$
0.76
Total Expense per Mcfe
$
3.78
$
3.08
Net Income (Loss)
$
(183,615)
$
9,553,244
Adjusted EBITDA (2)
$
4,607,034
$
7,740,240
Cash Flow from Operations (3)
$
5,246,651
$
8,933,477
CapEx (4)
$
7,440
$
190,826
CapEx - Mineral Acquisitions
$
1,406,248
$
10,236,615
Borrowing Base
$
50,000,000
$
50,000,000
Debt
$
30,750,000
$
26,000,000
Debt to Adjusted EBITDA (TTM) (2)
1.58
0.91
(1)
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.
(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, 2024
March 31, 2023
Gas Mcf Sold
1,700,108
1,959,010
Average Sales Price per Mcf before the
effects of settled derivative contracts
$
2.10
$
3.53
Average Sales Price per Mcf after the
effects of settled derivative contracts
$
3.08
$
3.83
% of sales subject to hedges
62
%
48
%
Oil Barrels Sold
37,260
54,107
Average Sales Price per Bbl before the
effects of settled derivative contracts
$
76.01
$
76.01
Average Sales Price per Bbl after the
effects of settled derivative contracts
$
76.19
$
69.90
% of sales subject to hedges
37
%
45
%
NGL Barrels Sold
32,184
33,104
Average Sales Price per Bbl(1)
$
21.51
$
25.18
Mcfe Sold
2,116,776
2,482,276
Natural gas, oil and NGL sales before the
effects of settled derivative contracts
$
7,090,208
$
11,857,247
Natural gas, oil and NGL sales after the
effects of settled derivative contracts
$
8,759,517
$
12,113,923
(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
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
6/30/2023
1,854,485
41,009
33,929
2,304,113
Total production volumes attributable to natural gas were 80% for the quarter ended March 31, 2024.
Royalty Interest Production for the last four quarters was as follows:
Quarter ended
Mcf Sold
Oil Bbls Sold
NGL Bbls Sold
Mcfe Sold
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
6/30/2023
1,673,346
35,599
20,516
2,010,036
Royalty production volumes attributable to natural gas were 83% for the quarter ended March 31, 2024.
Working Interest Production for the last four quarters was as follows:
Quarter ended
Mcf Sold
Oil Bbls Sold
NGL Bbls Sold
Mcfe Sold
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
6/30/2023
181,139
5,410
13,413
294,077
Quarter Ended March 31, 2024 Results
The Company recorded net loss of ($0.2) million, or ($0.01) per diluted share, for the quarter ended March 31, 2024, as compared to net income of $9.6 million, or $0.27 per diluted share, for the quarter ended March 31, 2023. The change in net income was principally the result of decreased natural gas, oil and NGL sales, decreased gains associated with our derivative contracts and decreased gains on asset sales, partially offset by decreased income tax provision.
Natural gas, oil and NGL revenue decreased $4.8 million, or 40%, for the quarter ended March 31, 2024, compared to the quarter ended March 31, 2023, due to decreases in natural gas and NGL prices of 41% and 15%, respectively, and decreases in natural gas, oil and NGL volumes of 13%, 31% and 3%, respectively.
The decrease in royalty production volumes during the quarter ended March 31, 2024, as compared to the quarter ended March 31, 2023, resulted from fewer new wells being brought online in the Haynesville Shale due to low gas prices. The production decrease in working interest volumes during the quarter ended March 31, 2024, as compared to the quarter ended March 31, 2023, resulted from the divestiture of working interest properties.
The Company had a net gain on derivative contracts of $0.6 million for the quarter ended March 31, 2024, comprised of a $1.7 million gain on settled derivatives and a ($1.0) million non-cash loss on derivatives, as compared to a net gain of $3.8 million for the quarter ended March 31, 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 March 31, 2024 pricing relative to the strike price on open derivative contracts.
Operations Update
During the quarter ended March 31, 2024, the Company converted 85 gross (0.32 net) wells to producing status, including 29 gross (0.10 net) wells in the Haynesville and 27 gross (0.13 net) wells in the SCOOP, compared to 117 gross (0.46 net) wells in the quarter ended March 31, 2023.
At March 31, 2024, the Company had a total of 230 gross (1.099 net) wells in progress and permits across its mineral positions, compared to 263 gross (1.295 net) wells in progress and permits at Dec. 31, 2023. As of April 30, 2024, 15 rigs were operating on the Company's acreage and 62 rigs operating within 2.5 miles of its acreage.
Bakken/
Three
Arkoma
SCOOP
STACK
Forks
Stack
Haynesville
Other
Total
As of March 31, 2024:
Gross Wells in Progress on PHX Acreage (1)
56
3
2
-
70
5
136
Net Wells in Progress on PHX Acreage (1)
0.248
0.006
0.001
-
0.568
0.026
0.849
Gross Active Permits on PHX Acreage
41
5
-
7
37
4
94
Net Active Permits on PHX Acreage
0.095
0.006
-
0.003
0.126
0.020
0.250
As of April 30, 2024:
Rigs Present on PHX Acreage
10
1
-
-
4
-
15
Rigs Within 2.5 Miles of PHX Acreage
19
7
6
1
19
10
62
(1)
Wells in progress includes drilling wells and drilled but uncompleted wells, or DUCs.
Leasing Activity
During the quarter ended March 31, 2024, the Company leased 381 net mineral acres to third-party exploration and production companies for an average bonus payment of $439 per net mineral acre and an average royalty of 23%.
Acquisition and Divestiture Update
During the quarter ended March 31, 2024, the Company purchased 146 net royalty acres for approximately $1.4 million and had no significant divestitures.
Acquisitions
SCOOP
Haynesville
Other
Total
During Three Months Ended March 31, 2024:
Net Mineral Acres Purchased
111
-
-
111
Net Royalty Acres Purchased
146
-
-
146
Quarterly Conference Call
PHX will host a conference call to discuss the Company's results for the quarter ended March 31, 2024, at 11 a.m. EDT on May 9, 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 13746174.
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 March 31,
2024
2023
Revenues:
Natural gas, oil and NGL sales
$
7,090,208
$
11,857,247
Lease bonuses and rental income
151,718
313,150
Gains (losses) on derivative contracts
627,492
3,802,820
7,869,418
15,973,217
Costs and expenses:
Lease operating expenses
332,409
574,942
Transportation, gathering and marketing
843,504
1,128,756
Production and ad valorem taxes
392,327
552,258
Depreciation, depletion and amortization
2,356,326
1,889,990
Provision for impairment
-
2,073
Interest expense
714,886
557,473
General and administrative
3,347,037
2,981,909
Losses (gains) on asset sales and other
24,212
(4,334,428)
Total costs and expenses
8,010,701
3,352,973
Income (loss) before provision for income taxes
(141,283)
12,620,244
Provision for income taxes
42,332
3,067,000
Net income (loss)
$
(183,615)
$
9,553,244
Basic and diluted earnings per common share
$
(0.01)
$
0.27
Weighted average shares outstanding:
Basic
36,303,392
35,935,791
Diluted
36,303,392
35,935,791
Dividends per share of
common stock paid in period
$
0.0300
$
0.0225
Balance Sheets
March 31, 2024
Dec. 31, 2023
Assets
Current assets:
Cash and cash equivalents
$
1,625,749
$
806,254
Natural gas, oil, and NGL sales receivables (net of $0
3,683,671
4,900,126
allowance for uncollectable accounts)
Refundable income taxes
455,553
455,931
Derivative contracts, net
2,400,390
3,120,607
Other
668,705
878,659
Total current assets
8,834,068
10,161,577
Properties and equipment at cost, based on
successful efforts accounting:
Producing natural gas and oil properties
212,852,807
209,082,847
Non-producing natural gas and oil properties
56,150,263
58,820,445
Other
1,360,614
1,360,614
270,363,684
269,263,906
Less accumulated depreciation, depletion and amortization
(116,177,898)
(114,139,423)
Net properties and equipment
154,185,786
155,124,483
Derivative contracts, net
-
162,980
Operating lease right-of-use assets
537,685
572,610
Other, net
429,486
486,630
Total assets
$
163,987,025
$
166,508,280
Liabilities and Stockholders' Equity
Current liabilities:
Accounts payable
$
621,191
$
562,607
Current portion of operating lease liability
236,465
233,390
Accrued liabilities and other
1,100,976
1,215,275
Total current liabilities
1,958,632
2,011,272
Long-term debt
30,750,000
32,750,000
Deferred income taxes, net
6,782,969
6,757,637
Asset retirement obligations
1,073,025
1,062,139
Derivative contracts, net
158,620
-
Operating lease liability, net of current portion
635,506
695,818
Total liabilities
41,358,752
43,276,866
Stockholders' equity:
Common Stock, $0.01666 par value; 54,000,500 shares authorized and
36,121,723 issued at Mar. 31, 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
42,403,417
41,676,417
Deferred directors' compensation
1,425,523
1,487,590
Retained earnings
78,717,910
80,022,839
123,148,638
123,788,634
Less treasury stock, at cost; 122,785 shares at Mar. 31,
2024, and 131,477 shares at Dec. 31, 2023
(520,365)
(557,220)
Total stockholders' equity
122,628,273
123,231,414
Total liabilities and stockholders' equity
$
163,987,025
$
166,508,280
Condensed Statements of Cash Flows
Three Months Ended
Three Months Ended
March 31, 2024
March 31, 2023
Operating Activities
Net income (loss)
$
(183,615)
$
9,553,244
Adjustments to reconcile net income (loss) to net cash provided
by operating activities:
Depreciation, depletion and amortization
2,356,326
1,889,990
Impairment of producing properties
-
2,073
Provision for deferred income taxes
25,332
2,934,000
Gain from leasing fee mineral acreage
(151,718)
(313,150)
Proceeds from leasing fee mineral acreage
151,718
373,878
Net (gain) loss on sales of assets
(66,500)
(4,417,983)
Directors' deferred compensation expense
45,132
53,589
Total (gain) loss on derivative contracts
(627,492)
(3,802,820)
Cash receipts (payments) on settled derivative contracts
1,669,309
816,838
Restricted stock award expense
656,656
580,998
Other
35,731
35,904
Cash provided (used) by changes in assets and liabilities:
Natural gas, oil and NGL sales receivables
1,216,455
2,328,673
Income taxes receivable
378
(776,077)
Other current assets
207,497
123,948
Accounts payable
67,986
(175,207)
Other non-current assets
56,338
40,576
Income taxes payable
-
(576,427)
Accrued liabilities
(212,882)
261,430
Total adjustments
5,430,266
(619,767)
Net cash provided by operating activities
5,246,651
8,933,477
Investing Activities
Capital expenditures
(7,440)
(190,826)
Acquisition of minerals and overriding royalty interests
(1,406,248)
(10,236,615)
Net proceeds from sales of assets
66,500
9,210,005
Net cash provided by (used in) investing activities
(1,347,188)
(1,217,436)
Financing Activities
Borrowings under credit facility
1,000,000
6,000,000
Payments of loan principal
(3,000,000)
(13,300,000)
Payments on off-market derivative contracts
-
(560,162)
Payments of dividends
(1,079,968)
(810,071)
Net cash provided by (used in) financing activities
(3,079,968)
(8,670,233)
Increase (decrease) in cash and cash equivalents
819,495
(954,192)
Cash and cash equivalents at beginning of period
806,254
2,115,652
Cash and cash equivalents at end of period
$
1,625,749
$
1,161,460
Supplemental Disclosures of Cash Flow Information:
Interest paid (net of capitalized interest)
$
733,799
$
611,922
Income taxes paid (net of refunds received)
$
16,623
$
1,485,505
Supplemental Schedule of Noncash Investing and Financing Activities:
Dividends declared and unpaid
$
41,346
$
50,034
Gross additions to properties and equipment
$
1,406,743
$
10,996,880
Net increase (decrease) in accounts receivable for properties
and equipment additions
6,945
(569,439)
Capital expenditures and acquisitions
$
1,413,688
$
10,427,441
Derivative Contracts as of March 31, 2024
Production volume
Contract period
covered per month
Index
Contract price
Natural gas costless collars
April - September 2024
30,000 Mmbtu
NYMEX Henry Hub
$3.00 floor / $3.60 ceiling
April 2024
90,000 Mmbtu
NYMEX Henry Hub
$3.50 floor / $4.70 ceiling
May 2024
95,000 Mmbtu
NYMEX Henry Hub
$3.50 floor / $4.70 ceiling
June 2024
90,000 Mmbtu
NYMEX Henry Hub
$3.50 floor / $4.70 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
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
Natural gas fixed price swaps
April - June 2024
10,000 Mmbtu
NYMEX Henry Hub
$3.21
April - October 2024
50,000 Mmbtu
NYMEX Henry Hub
$3.17
April - 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
March 2024
1,750 Bbls
NYMEX WTI
$63.00 floor / $76.00 ceiling
April 2024
1,700 Bbls
NYMEX WTI
$63.00 floor / $76.00 ceiling
May 2024
1,750 Bbls
NYMEX WTI
$63.00 floor / $76.00 ceiling
June 2024
1,650 Bbls
NYMEX WTI
$63.00 floor / $76.00 ceiling
March 2024
1,650 Bbls
NYMEX WTI
$65.00 floor / $76.50 ceiling
April - 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
March 2024
750 Bbls
NYMEX WTI
$71.75
April - October 2024
1,000 Bbls
NYMEX WTI
$66.10
April - June 2024
1,300 Bbls
NYMEX WTI
$70.59
July - October 2024
1,500 Bbls
NYMEX WTI
$69.50
November - December 2024
2,000 Bbls
NYMEX WTI
$69.50
November 2024 - March 2025
1,600 Bbls
NYMEX WTI
$64.80
January - March 2025
500 Bbls
NYMEX WTI
$69.50
January - June 2025
2,000 Bbls
NYMEX WTI
$70.90
April - June 2025
750 Bbls
NYMEX WTI
$69.50
April - June 2025
1,000 Bbls
NYMEX WTI
$68.00
July - September 2025
500 Bbls
NYMEX WTI
$69.50
July - December 2025
1,500 Bbls
NYMEX WTI
$68.90
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
Three Months Ended
March 31, 2024
March 31, 2023
Dec. 31, 2023
Net Income
$
(183,615)
$
9,553,244
$
2,513,444
Plus:
Income tax expense
42,332
3,067,000
1,245,460
Interest expense
714,886
557,473
723,685
DD&A
2,356,326
1,889,990
2,443,154
Impairment expense
-
2,073
-
Less:
Non-cash gains (losses)
on derivatives
(1,041,817)
3,172,399
2,936,659
Gains (losses) on asset sales
66,500
4,417,983
57,505
Plus:
Cash payments on off-market derivative
contracts
-
(373,745)
-
Restricted stock and deferred
director's expense
701,788
634,587
572,709
Adjusted EBITDA
$
4,607,034
$
7,740,240
$
4,504,288
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, 2024
March 31, 2023
Net Income
$
4,183,941
$
30,646,855
Plus:
Income tax expense
1,710,792
7,455,000
Interest expense
2,519,806
1,953,232
DD&A
9,032,521
7,265,346
Impairment expense
36,460
6,111,749
Less:
Non-cash gains (losses)
on derivatives
88,315
14,360,063
Gains (losses) on asset sales
377,276
9,604,551
Plus:
Cash payments on off-market derivative
contracts
-
(3,618,427)
Restricted stock and deferred
director's expense
2,501,129
2,815,183
Adjusted EBITDA
$
19,519,058
$
28,664,324
Debt
$
30,750,000
$
26,000,000
Debt to Adjusted EBITDA (TTM)
1.58
0.91
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 on the Company can be found at www.phxmin.com.
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.
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