PHX MINERALS INC. REPORTS SECOND FISCAL QUARTER 2022 RESULTS, RECORD ROYALTY VOLUMES AND A QUARTERLY DIVIDEND INCREASE OF 33%

Rhea-AI Summary

PHX Minerals Inc. (PHX) reported second-quarter results for fiscal 2022, highlighting a net loss of $4 million ($0.12 per share), a significant decline from net income of $6.7 million in the previous quarter. Royalty production volumes surged 26% to a record 1,548 Mmcfe, while total production rose 16% to 2,460 Mmcfe. Adjusted EBITDA improved to $5.8 million, up from $3.6 million year-over-year. The company made significant acquisitions, closing on $9.3 million in net royalty acres. Additionally, the quarterly dividend increased by 33% to $0.02 per share, payable June 3, 2022.

Positive

• Royalty production increased 26% to 1,548 Mmcfe.
• Total production increased 16% to 2,460 Mmcfe.
• Adjusted EBITDA rose to $5.8 million, up from $3.6 million YoY.
• Quarterly dividend increased by 33% to $0.02 per share.

Negative

• Net loss of $4 million, compared to net income of $6.7 million in the previous quarter.
• Unrealized losses on derivative contracts totaled $12.9 million.
• G&A expenses rose 33% due to legal expenses related to reincorporation.

OKLAHOMA CITY, May 9, 2022 /PRNewswire/ -- PHX MINERALS INC., "PHX" or the "Company" (NYSE: PHX), today reported financial and operating results for the second fiscal quarter ended March 31, 2022.

SUMMARY OF RESULTS FOR THE PERIOD ENDED MARCH 31, 2022, AND SUBSEQUENT EVENTS

• Royalty production volumes for the second fiscal quarter of 2022 increased 26% to a record 1,548 Mmcfe, and total production volumes for the second fiscal quarter of 2022 increased 16% to 2,460 Mmcfe compared to the first fiscal quarter of 2022.
• 82% of royalty production volumes and 78% of total production volumes in the second fiscal quarter of 2022 were attributable to natural gas.
• 108 gross (0.48 net) wells converted to PDP, including 35 gross (0.04 net) in the SCOOP and 31 gross (0.33 net) in the Haynesville, during the second fiscal quarter of 2022.
• 134 gross (0.60 net) wells in progress as of March 31, 2022.
• Net loss in the second fiscal quarter of 2022 was ($4.0) million, or ($0.12) per share, compared to net income of $6.7 million, or $0.20 per share, in the first fiscal quarter of 2022.
• Pretax net income excluding non-cash derivative gains (losses) ⁽¹⁾ in the second fiscal quarter of 2022 was $7.8 million, or $0.23 per share, compared to $2.9 million, or $0.09 per share, in the first fiscal quarter of 2022.
• Adjusted EBITDA⁽¹⁾ of $5.8 million for the second fiscal quarter of 2022, increased from $3.6 million in the second fiscal quarter of 2021 and from $4.4 million in the first fiscal quarter of 2022.
• Total debt as of March 31, 2022, equaled $24.0 million and debt to adjusted EBITDA (TTM) ⁽¹⁾ ratio was 1.23x at March 31, 2022.
• During the second quarter of fiscal year 2022, PHX closed on an acquisition of 825 net royalty acres located in the SCOOP play of Oklahoma and the Haynesville play of East Texas and Louisiana for approximately $9.3 million in cash.
• Since March 31, 2022, PHX has closed on an additional acquisition of 185 net royalty acres located in the SCOOP play of Oklahoma and the Haynesville play of Louisiana for approximately $1.5 million in cash. PHX has an additional 983 net royalty acres pending acquisition and under purchase and sale agreements, which the Company expects to close by the end of May 2022 for approximately $9.4 million in cash.
• PHX announced that the quarterly dividend increased to $0.02 per share, a 33% increase, payable on June 3, 2022, to stockholders of record on May 19, 2022.

(1)	This is a non-GAAP measure. Refer to the Non-GAAP Reconciliation section.

Chad L. Stephens, President and CEO, commented, "We are very pleased to report excellent financial results for our second quarter. First, I would like to recognize our employees for their dedication and hard work, for they are our greatest resource. None of our accomplishments would have been achieved without them.

"Royalty volumes increased by over 20% on a quarter over quarter basis for the second consecutive quarter to a record 1.55 Bcfe, and non-operated working interest volumes continue to decline as a percentage of total volumes to 37% and will continue to become less material going forward.  Higher sales volumes along with the serendipitous commodity price environment provided a 32% increase quarter over sequential quarter in adjusted EBITDA.

"Our active mineral acquisition program has closed a year-to-date total of $25.6 million in transactions with another $9.4 million scheduled to close by the end of May – all in our core focus areas in the SCOOP of southern Oklahoma and the Haynesville. These recent acquisitions are in areas of active drilling and will drive our increasing royalty volumes and cash flow over the coming quarters. Additionally, the Board approved a 33% increase in our quarterly dividend payable in June 2022, which highlights our confidence in our financial strength and earnings power of our growing asset base. PHX remains committed to increasing our return of capital to stockholders via future dividends as we grow our asset base."

 

OPERATING HIGHLIGHTS
	Second Quarter Ended				Second Quarter Ended				Six Months Ended				Six Months Ended
	March 31, 2022				March 31, 2021				March 31, 2022				March 31, 2021
Mcfe Sold		2,460,042				2,296,802				4,588,290				4,371,139
Average Sales Price per Mcfe	$	6.01			$	3.63			$	6.21			$	3.38
Gas Mcf Sold		1,908,030				1,735,820				3,482,295				3,211,276
Average Sales Price per Mcf	$	4.47			$	2.52			$	4.95			$	2.44
Oil Barrels Sold		51,631				56,269				99,705				114,945
Average Sales Price per Barrel	$	91.26			$	55.89			$	83.12			$	47.73
NGL Barrels Sold		40,371				37,228				84,627				78,365
Average Sales Price per Barrel	$	38.05			$	22.24			$	34.94			$	18.54

Total Production for the last five quarters was as follows:

Quarter ended		Mcf Sold				Oil Bbls Sold				NGL Bbls Sold				Mcfe Sold
3/31/2022			1,908,030				51,631				40,371				2,460,042
12/31/2021			1,574,265				48,074				44,256				2,128,248
9/30/2021			1,609,101				54,043				46,369				2,211,570
6/30/2021			1,879,343				55,492				46,753				2,492,813
3/31/2021			1,735,820				56,269				37,228				2,296,802

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

Quarter ended		Mcf Sold				Oil Bbls Sold				NGL Bbls Sold				Mcfe Sold
3/31/2022			1,261,949				28,758				18,852				1,547,609
12/31/2021			949,523				25,996				19,953				1,225,220
9/30/2021			705,397				29,442				19,364				998,230
6/30/2021			908,471				31,095				18,255				1,204,571
3/31/2021			924,969				31,768				19,088				1,230,105

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

Quarter ended		Mcf Sold				Oil Bbls Sold				NGL Bbls Sold				Mcfe Sold
3/31/2022			646,081				22,873				21,519				912,433
12/31/2021			624,742				22,078				24,303				903,028
9/30/2021			903,704				24,601				27,005				1,213,340
6/30/2021			970,872				24,397				28,498				1,288,242
3/31/2021			810,851				24,501				18,140				1,066,697

 

FINANCIAL HIGHLIGHTS
		Second Quarter Ended				Second Quarter Ended				Six Months Ended				Six Months Ended
		March 31, 2022				March 31, 2021				March 31, 2022				March 31, 2021
Working Interest Sales		$	5,904,871			$	3,851,478			$	11,871,518			$	7,759,002
Royalty Interest Sales		$	8,878,994			$	4,494,347			$	16,599,511			$	7,011,802
Natural Gas, Oil and NGL Sales		$	14,783,865			$	8,345,825			$	28,471,029			$	14,770,804
Lease Bonuses and Rental Income		$	161,908			$	58,554			$	240,823			$	59,987
Total Revenue		$	1,962,367			$	6,056,236			$	18,564,614			$	12,228,612
LOE per Working Interest Mcfe		$	1.02			$	0.97			$	1.20			$	0.85
LOE per total Mcfe		$	0.38			$	0.45			$	0.48			$	0.47
Transportation, Gathering and Marketing
per Mcfe		$	0.61			$	0.57			$	0.59			$	0.59
Production Tax per Mcfe		$	0.28			$	0.19			$	0.30			$	0.16
Cash G&A Expense per Mcfe (1)		$	0.93			$	0.80			$	0.88			$	0.78
G&A Expense per Mcfe		$	1.12			$	0.90			$	1.05			$	0.87
Interest Expense per Mcfe		$	0.09			$	0.12			$	0.09			$	0.13
DD&A per Mcfe		$	0.86			$	0.77			$	0.81			$	0.92
Total Expense per Mcfe		$	3.34			$	3.00			$	3.32			$	3.14
Net Income (Loss)		$	(4,020,455)			$	(499,723)			$	2,661,794			$	(1,096,443)
Adjusted EBITDA (2)		$	5,819,415			$	3,582,486			$	10,235,479			$	6,494,198
Cash Flow from Operations		$	7,296,330			$	4,205,726			$	15,934,320			$	4,677,107
CapEx		$	86,671			$	297,015			$	279,348			$	425,098
CapEx - Mineral Acquisitions		$	9,274,447			$	64,758			$	20,918,274			$	7,934,504
Borrowing Base										$	32,000,000			$	29,400,000
Debt										$	24,000,000			$	23,500,000
Debt to Adjusted EBITDA (TTM) (2)											1.23				2.35

(1)	G&A excluding restricted stock and deferred director's expense.
(2)	This is a non-GAAP measure. Refer to the Non-GAAP Reconciliation section.

SECOND FISCAL QUARTER ENDED MARCH 31, 2022, RESULTS

The Company recorded a second fiscal quarter 2022 net loss of ($4,020,455), or ($0.12) per share, as compared to a net loss of ($499,723), or ($0.02) per share, in the second fiscal quarter 2021. The change in net loss was principally the result of unrealized losses associated with the Company's derivative contracts, offset by increased natural gas, oil and NGL sales and gains on asset sales.

Natural gas, oil and NGL revenue increased $6,438,040, or 77%, for the second quarter 2022, compared to the corresponding 2021 quarter due to increases in natural gas, oil and NGL prices of 77%, 63% and 71%, respectively, and an increase in natural gas and NGL volumes of 10% and 8%, respectively, partially offset by an 8% decrease in oil volumes.

The production increase in royalty volumes during the three months ended March 31, 2022, as compared to the three months ended March 31, 2021, resulted from acquired wells in the Haynesville Shale and SCOOP plays coming online.  The decrease in working interest volumes resulted from naturally declining production in high-interest wells in the Arkoma Stack and the divestiture of low-value legacy working interests in Oklahoma.

The Company had a net loss on derivative contracts of ($12,983,406) in the second fiscal 2022 quarter, as compared to a net loss of ($2,348,143) in the second fiscal 2021 quarter, of which ($11,772,640) is unrealized with respect to the second fiscal 2022 quarter. Realized net loss on derivative contracts for the second fiscal 2022 quarter excludes $2,493,481 of cash paid to settle off-market derivative contracts. The change in net loss on derivative contracts was principally due to the Company's natural gas and oil collars and fixed price swaps being less beneficial in the quarter ended March 31, 2022, in relation to their respective contracted volumes and prices, as compared to the corresponding 2021 quarter.

The 11% increase in total cost per Mcfe in the second fiscal 2022 quarter, relative to the second fiscal 2021 quarter, was primarily driven by an increase in general and administrative costs, or G&A, and depreciation, depletion and amortization, or DD&A. G&A increased $684,788, or 33%, in the second fiscal 2022 quarter compared to the corresponding 2021 quarter due to legal expenses associated with reincorporating in the state of Delaware, increased transaction activity and restricted stock expense. DD&A increased $343,299, or 19%, in the second fiscal 2022 quarter to $0.86 per Mcfe, as compared to $0.77 per Mcfe in the second fiscal 2021 quarter. Of the DD&A increase, $217,604 was a result of a $0.09 increase in the DD&A rate per Mcfe, and $125,695 of such increase resulted from production increasing 7% in the second fiscal 2022 quarter.

SIX MONTHS ENDED MARCH 31, 2022, RESULTS

The Company recorded net income of $2,661,794, or $0.08 per share, in the fiscal six-month period ended March 31, 2022 (the "fiscal six-month 2022 period"), as compared to a net loss of ($1,096,443), or ($0.05) per share, in the corresponding 2021 period. The change in net income was principally the result of increased natural gas, oil and NGL sales and lease bonuses and rental income, and decreased DD&A and interest expense, partially offset by an increase in losses on derivative contracts, lease operating expense, or LOE, transportation, gathering and marketing expenses, production taxes and a reduction in income tax benefit.

Natural gas, oil and NGL sales increased $13,700,225, or 93%, for the fiscal six-month 2022 period, compared to the corresponding 2021 period, due to increases in natural gas, oil and NGL prices of 103%, 74% and 88%, respectively, and an increase in natural gas and NGL volumes of 8% and 8%, respectively, partially offset by a decrease in oil volumes of 13%.

Natural gas volumes increased during the fiscal six-month 2022 period, as compared to the corresponding 2021 period, primarily as a result of new wells associated with recent acquisitions in the Haynesville Shale and SCOOP plays coming online. These gas volumes were partially offset by naturally declining production in high-interest wells in the Arkoma Stack and divestitures in the Fayetteville.  NGL production also increased as a result of new wells brought online in the SCOOP, as well as increased production from liquids-rich gas wells in the Anadarko Granite Wash. The decrease in oil production was a result of naturally declining production in working interest wells in the Eagle Ford play and royalty wells in the Bakken play, due to the Company's strategy of no longer participating with working interests in new drilling in the Eagle Ford, and reduced drilling activity in the Bakken, as well as naturally declining production in high-interest wells brought online in the STACK during fiscal year 2021. Oil production decreases were partially offset by new wells in the SCOOP.

The Company had a net loss on derivative contracts of ($10,147,238) in the fiscal six-month 2022 period, as compared to a net loss of ($2,602,179) in the corresponding 2021 period, of which ($7,222,140) is unrealized with respect to the fiscal six-month 2022 period. Realized net loss on derivative contracts for the fiscal six-month 2022 period excludes $5,181,572 of cash paid to settle off-market derivative contracts. The change in net loss on derivative contracts was principally due to the Company's natural gas and oil collars and fixed price swaps being less beneficial in the fiscal six-month 2022 period in relation to their respective contracted volumes and prices, as compared to the corresponding 2021 period.

The 6% increase in total cost per Mcfe in the fiscal six-month 2022 period, relative to the corresponding 2021 period, was primarily driven by an increase in G&A and production tax, partially offset by a decrease in DD&A. G&A increased $1,049,248, or 28%, in the fiscal six-month 2022 period compared to the corresponding 2021 period due to legal expenses associated with reincorporating in the state of Delaware, increased transaction activity and restricted stock expense. DD&A decreased $333,590, or 8%, in the fiscal six-month 2022 period to $0.81 per Mcfe, as compared to $0.92 per Mcfe in the corresponding 2021 period. Of the DD&A decrease, $533,366 was a result of an $0.11 decrease in the DD&A rate per Mcfe, partially offset by an increase of $199,776 resulting from production increasing 5% in the fiscal six-month 2022 period compared to the corresponding 2021 period. The DD&A rate per Mcfe decrease was mainly due an increase in reserves during the fiscal six-month 2022 period, as compared to the corresponding 2021 period.

OPERATIONS UPDATE 

During the second fiscal quarter of 2022, the Company converted 108 gross (0.48 net) wells to producing status, including 35 gross (0.04 net) in the SCOOP and 31 gross (0.33 net) in the Haynesville.

At March 31, 2022, the Company had a total of 134 gross wells (0.60 net wells) in progress across its mineral positions and 52 gross (0.23 net) active permitted wells. As of March 31, 2022, 18 rigs were operating on the Company's acreage with 86 rigs operating within 2.5 miles of its acreage.

										Bakken/
										Three				Arkoma
		SCOOP				STACK				Forks				Stack				Fayetteville				Haynesville				Other				Total
As of March 31, 2022:
Gross Wells in Progress on PHX Acreage			61				14				6				6				-				40				7				134
Net Wells in Progress on PHX Acreage			0.17				0.07				0.01				0.00				-				0.33				0.02				0.60
Gross Active Permits on PHX Acreage			10				11				11				4				-				12				4				52
As of March 31, 2022:
Rigs Present on PHX Acreage			7				1				1				1				-				7				1				18
Rigs Within 2.5 Miles of PHX Acreage			19				13				10				2				-				29				13				86

 

Leasing Activity

During the second quarter of fiscal 2022, the Company leased 385 net mineral acres for an average bonus payment of $942 per net mineral acre and an average royalty of 22%. 

										Bakken/
										Three				Arkoma
		SCOOP				STACK				Forks				Stack				Fayetteville				Haynesville				Other				Total
During Three Months Ended March 31, 2022:
Net Mineral Acres Leased			41				67				-				125				9				-				143				385
Average Bonus per Net Mineral Acre		$	1,679			$	1,000				-			$	185			$	100				-			$	467			$	942
Average Royalty per Net Mineral Acre		25%				25%					-			19%				$	17				-			19%				22%

 

ACQUISITION AND DIVESTITURE UPDATE

During the second quarter of fiscal year 2022, the Company purchased 825 net royalty acres for approximately $9.3 million and sold 7,208 net mineral acres, which were predominantly undeveloped and unleased, for approximately $2.1 million. 

										Bakken/
										Three				Arkoma
		SCOOP				STACK				Forks				Stack				Fayetteville				Haynesville				Other				Total
During Three Months Ended March 31, 2022:
Net Mineral Acres Purchased			184				-				-				-				-				421				-				605
Net Royalty Acres Purchased			224				-				-				-				-				601				-				825
Price per Net Royalty Acre		$	8,027				-				-				-				-			$	12,511				-			$	11,294
Net Mineral Acres Sold			-				-				-				-				-				-				7,208				7,208
Net Royalty Acres Sold			-				-				-				-				-				-				7,708				7,708
Price per Net Royalty Acre			-				-				-				-				-				-			$	272			$	272

 

SECOND QUARTER EARNINGS CALL 

PHX will host a conference call to discuss the Company's second fiscal quarter results at 11:00 a.m. EST tomorrow May 10, 2022. 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 (domestic) or 201-389-0927 (international). 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 13729283.

 

FINANCIAL RESULTS
Statements of Operations
	Three Months Ended March 31,								Six Months Ended March 31,
	2022				2021				2022				2021
Revenues:
Natural gas, oil and NGL sales	$	14,783,865			$	8,345,825			$	28,471,029			$	14,770,804
Lease bonuses and rental income		161,908				58,554				240,823				59,987
Gains (losses) on derivative contracts		(12,983,406)				(2,348,143)				(10,147,238)				(2,602,179)
		1,962,367				6,056,236				18,564,614				12,228,612
Costs and expenses:
Lease operating expenses		929,454				1,030,651				2,185,465				2,035,063
Transportation, gathering and marketing		1,488,518				1,319,514				2,702,122				2,600,479
Production taxes		697,393				443,154				1,376,340				719,180
Depreciation, depletion and amortization		2,121,116				1,777,817				3,704,876				4,038,466
Provision for impairment		-				-				5,585				-
Interest expense		230,212				267,865				406,931				569,763
General and administrative		2,744,264				2,059,476				4,839,821				3,790,573
Losses (gains) on asset sales and other		(2,261,135)				(125,518)				(113,320)				(142,469)
Total costs and expenses		5,949,822				6,772,959				15,107,820				13,611,055
Income (loss) before provision (benefit) for income taxes		(3,987,455)				(716,723)				3,456,794				(1,382,443)
Provision (benefit) for income taxes		33,000				(217,000)				795,000				(286,000)
Net income (loss)	$	(4,020,455)			$	(499,723)			$	2,661,794			$	(1,096,443)
Basic and diluted earnings (loss) per common share	$	(0.12)			$	(0.02)			$	0.08			$	(0.05)
Basic and diluted weighted average shares outstanding:
Common shares		34,056,316				22,429,777				33,449,594				22,403,678
Unissued, directors' deferred compensation shares		236,139				178,597				234,091				177,923
		34,292,455				22,608,374				33,683,685				22,581,601
Dividends per share of
common stock paid in period	$	0.015			$	0.01			$	0.025			$	0.02
Dividends declared per share of
common stock and to be paid in quarter ended June 30	$	-			$	0.01

 

Balance Sheets
	March 31, 2022				Sept. 30, 2021
Assets
Current assets:
Cash and cash equivalents	$	1,703,675			$	2,438,511
Natural gas, oil, and NGL sales receivables (net of $0		9,451,366				6,428,982
allowance for uncollectable accounts)
Refundable income taxes		-				2,413,942
Other		1,188,312				942,082
Total current assets		12,343,353				12,223,517
Properties and equipment at cost, based on
successful efforts accounting:
Producing natural gas and oil properties		264,135,242				319,984,874
Non-producing natural gas and oil properties		48,878,130				40,466,098
Other		844,582				794,179
		313,857,954				361,245,151
Less accumulated depreciation, depletion and amortization		(196,960,903)				(257,643,661)
Net properties and equipment		116,897,051				103,601,490
Operating lease right-of-use assets		564,034				607,414
Other, net		537,199				578,593
Total assets	$	130,341,637			$	117,011,014
Liabilities and Stockholders' Equity
Current liabilities:
Accounts payable	$	602,415			$	772,717
Derivative contracts, net		14,793,396				12,087,988
Income taxes payable		253,733				334,050
Current portion of operating lease liability		134,955				132,287
Accrued liabilities and other		1,506,836				1,809,337
Total current liabilities		17,291,335				15,136,379
Long-term debt		24,000,000				17,500,000
Deferred income taxes, net		370,906				343,906
Asset retirement obligations		2,178,023				2,836,172
Derivative contracts, net		1,031,639				1,696,479
Operating lease liability, net of current portion		721,188				789,339
Total liabilities		45,593,091				38,302,275
Stockholders' equity:
Common Stock, $0.01666 par value; 54,000,500
shares authorized and 34,469,449 issued at March 31, 2022;
36,000,500 shares authorized and 32,770,433 issued at Sept. 30, 2021		574,261				545,956
Capital in excess of par value		37,596,944				33,213,645
Deferred directors' compensation		1,407,423				1,768,151
Retained earnings		50,778,525				48,966,420
		90,357,153				84,494,172
Less treasury stock, at cost; 377,232 shares at March 31,
2022, and 388,545 shares at Sept. 30, 2021		(5,608,607)				(5,785,433)
Total stockholders' equity		84,748,546				78,708,739
Total liabilities and stockholders' equity	$	130,341,637			$	117,011,014

 

Condensed Statements of Cash Flows
	Six Months Ended March 31,
	2022				2021
Operating Activities
Net income (loss)	$	2,661,794			$	(1,096,443)
Adjustments to reconcile net income (loss) to net cash provided
by operating activities:
Depreciation, depletion and amortization		3,704,876				4,038,466
Impairment of producing properties		5,585				-
Provision for deferred income taxes		27,000				(288,000)
Gain from leasing fee mineral acreage		(239,751)				(57,493)
Proceeds from leasing fee mineral acreage		328,783				64,047
Net (gain) loss on sales of assets		(171,285)				(62,097)
Directors' deferred compensation expense		103,031				100,254
Total (gain) loss on derivative contracts		10,147,238				2,602,179
Cash receipts (payments) on settled derivative contracts		(176,510)				315,883
Restricted stock awards		688,981				284,148
Other		28,483				31,544
Cash provided (used) by changes in assets and liabilities:
Natural gas, oil and NGL sales receivables		(3,022,384)				(1,732,801)
Other current assets		(205,489)				(388,864)
Accounts payable		(91,587)				(340,404)
Income taxes receivable		2,413,942				1,356,356
Other non-current assets		64,975				56,545
Income taxes payable		(80,317)				-
Accrued liabilities		(253,045)				(206,213)
Total adjustments		13,272,526				5,773,550
Net cash provided by operating activities		15,934,320				4,677,107
Investing Activities
Capital expenditures		(279,348)				(425,098)
Acquisition of minerals and overriding royalty interests		(20,918,274)				(7,934,504)
Net proceeds from sales of assets		6,880,972				21,000
Net cash provided (used) by investing activities		(14,316,650)				(8,338,602)
Financing Activities
Borrowings under credit facility		10,000,000				-
Payments of loan principal		(3,500,000)				(5,250,000)
Net cost of equity issuance		(72,657)				(53,482)
Cash receipts from (payments on) off-market derivative contracts		(7,930,160)				-
Payments of dividends		(849,689)				(454,936)
Net cash provided (used) by financing activities		(2,352,506)				(5,758,418)
Increase (decrease) in cash and cash equivalents		(734,836)				(9,419,913)
Cash and cash equivalents at beginning of period		2,438,511				10,690,395
Cash and cash equivalents at end of period	$	1,703,675			$	1,270,482
Supplemental Schedule of Noncash Investing and Financing Activities
Dividends declared and unpaid	$	-			$	289,997
Gross additions to properties and equipment	$	24,522,684			$	8,759,616
Value of shares used for acquisitions		(3,510,001)				(250,000)
Net (increase) decrease in accounts payable for properties
and equipment additions		184,939				(150,014)
Capital expenditures and acquisitions	$	21,197,622			$	8,359,602

 

Proved Reserves
	Proved Reserves SEC Pricing
	March 31, 2022				Sept. 30, 2021
Proved Developed Reserves:
Mcf of Gas		57,105,505				60,287,881
Barrels of Oil		1,407,747				1,439,860
Barrels of NGL		1,413,001				1,467,092
Mcfe (1)		74,029,993				77,729,593
Proved Undeveloped Reserves:
Mcf of Gas		6,649,529				4,664,787
Barrels of Oil		49,819				64,980
Barrels of NGL		39,120				34,761
Mcfe (1)		7,183,163				5,263,233
Total Proved Reserves:
Mcf of Gas		63,755,034				64,952,668
Barrels of Oil		1,457,566				1,504,840
Barrels of NGL		1,452,121				1,501,853
Mcfe (1)		81,213,156				82,992,826
10% Discounted Estimated Future
Net Cash Flows (before income taxes):
Proved Developed	$	136,886,508			$	86,793,303
Proved Undeveloped		18,800,039				9,731,035
Total	$	155,686,547			$	96,524,338
SEC Pricing
Gas/Mcf	$	4.24			$	2.79
Oil/Barrel	$	75.00			$	56.51
NGL/Barrel	$	31.44			$	20.58
Proved Reserves - Projected Future Pricing (2)
10% Discounted Estimated Future	Proved Reserves
Net Cash Flows (before income taxes):	March 31, 2022				Sept. 30, 2021
Proved Developed	$	132,544,462			$	111,007,369
Proved Undeveloped		18,291,047				11,989,928
Total	$	150,835,509			$	122,997,297
(1) Crude oil and NGL converted to natural gas on a one barrel of crude oil or NGL equals six Mcf of natural gas basis.
(2) Projected futures pricing as of March 31, 2022, and Sept. 30, 2021, basis adjusted to Company wellhead price.

 

Derivative Contracts as of May 6, 2022
												Collar Average				Collar Average
Fiscal Period		Product		Volume Mcf/Bbl				Swap Price				Floor Price				Ceiling Price
Remaining 2022		Natural Gas			585,000							$	3.95			$	5.69
Remaining 2022		Natural Gas			1,785,000			$	2.98
2023		Natural Gas			890,000							$	4.49			$	8.10
2023		Natural Gas			2,100,000			$	3.24
2024		Natural Gas			60,000							$	3.00			$	4.70
2024		Natural Gas			380,000			$	3.41
Remaining 2022		Crude Oil			64,500			$	45.03
2023		Crude Oil			15,000							$	75.00			$	96.00
2023		Crude Oil			66,750			$	62.11
2024		Crude Oil			11,250			$	73.35

 

Non-GAAP Reconciliation

This news 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

We define "adjusted EBITDA" as earnings before interest, taxes, depreciation and amortization, or EBITDA, excluding unrealized 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. We have included a presentation of adjusted EBITDA because we recognize that certain investors consider this amount to be a useful means of measuring our ability to meet our debt service obligations and evaluating our 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 presentation of net income (loss) to adjusted EBITDA for the periods indicated:

	Second Quarter Ended				Second Quarter Ended				Six Months Ended				Six Months Ended				First Quarter Ended
	March 31, 2022				March 31, 2021				March 31, 2022				March 31, 2021				Dec. 31, 2021
Net Income (Loss)	$	(4,020,455)			$	(499,723)			$	2,661,794			$	(1,096,443)			$	6,682,249
Plus:
Income tax expense
(benefit)		33,000				(217,000)				795,000				(286,000)				762,000
Interest expense		230,212				267,865				406,931				569,763				176,719
DD&A		2,121,116				1,777,817				3,704,876				4,038,466				1,583,760
Impairment		-				-				5,585				-				5,585
Less:
Unrealized gains (losses)
on derivatives		(11,772,640)				(2,050,712)				(7,222,140)				(2,918,062)				4,550,499
Gains (losses) on asset sales		2,292,215				14,082				171,288				30,559				(2,120,927)
Plus:
Cash receipts from (payments on)
off-market derivative contracts(1)		(2,493,481)				-				(5,181,572)				-				(2,688,091)
Restricted stock and deferred
director's expense		468,598				216,897				792,013				384,402				323,415
Adjusted EBITDA	$	5,819,415			$	3,582,486			$	10,235,479			$	6,497,691			$	4,416,065
(1) The initial receipt of $8.8 million of cash from BP Energy Company, or BP, for entering into the off-market derivative contracts had no effect on the Company's statement of operations and was considered cash flow from financing activities. A portion of subsequent settlements with BP has no effect on the Company's statement of operations.

 

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. We have included a presentation of debt to adjusted EBITDA (TTM) because we recognize that certain investors consider such ratios to be useful means of measuring our ability to meet our debt service obligations and for evaluating our 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 presentation 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, 2022				March 31, 2021
Net Income (Loss)	$	(2,459,000)			$	(6,485,780)
Plus:
Income tax expense (benefit)		429,949				(1,842,000)
Interest expense		832,295				1,139,313
DD&A		7,412,214				9,023,030
Impairment		56,060				358,826
Less:
Unrealized gains (losses)
on derivatives		(8,580,898)				(7,842,624)
Gains (losses) on asset sales		450,074				738,432
Plus:
Cash receipts from (payments on)
off-market derivative contracts(1)		3,618,428				-
Restricted stock and deferred
director's expense		1,443,276				721,944
Adjusted EBITDA	$	19,464,046			$	10,019,525
Debt	$	24,000,000			$	23,500,000
Debt to Adjusted EBITDA (TTM)		1.23				2.35
(1) The initial receipt of $8.8 million of cash from BP for entering into the off-market derivative contracts had no effect on the Company's statement of operations and was considered cash flow from financing activities. A portion of subsequent settlements with BP has no effect on the Company's statement of operations.

 

Pretax Net Income (Loss) Excluding Non-cash Derivative Gains (Losses) Reconciliation

"Pretax net income (loss) excluding non-cash derivative gains (losses)" is defined as earnings before taxes, excluding unrealized gains (losses) on derivatives. We have included a presentation of pretax net income (loss) excluding non-cash derivative gains (losses) because we recognize that certain investors consider this amount to be a useful means of measuring our ability to meet our debt service obligations and evaluating our financial performance. Pretax net income (loss) excluding non-cash derivative gains (losses) 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 pretax net income (loss) excluding non-cash derivative gains (losses) may not be comparable to a similarly titled measure of other companies. The following table provides a presentation of net income (loss) to pretax net income (loss) excluding non-cash derivative gains (losses) for the periods indicated:

	Second Quarter Ended				First Quarter Ended
	March 31, 2022				Dec. 31, 2021
Net Income (Loss)	$	(4,020,455)			$	6,682,249
Plus:
Income tax expense (benefit)		33,000				762,000
Less:
Unrealized gains (losses)
on derivatives		(11,772,640)				4,550,499
Pretax Net Income (Loss) excluding
Non-cash Derivative Gains (Losses)	$	7,785,185			$	2,893,750
Basic and diluted weighted average
shares outstanding		34,292,455				33,127,722
Pretax Net Income (Loss) excluding
Non-cash Derivative Gains (Losses) per share	$	0.23			$	0.09

PHX Minerals Inc. (NYSE: PHX) Oklahoma City-based, PHX Minerals Inc. is a natural gas and oil mineral company with a strategy to proactively grow its mineral position in its core areas of focus. PHX owns mineral acreage principally located in Oklahoma, Texas, Louisiana, North Dakota, and Arkansas. Additional information on PHX 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 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 the 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 statements are not guarantees of future performance and that actual results or developments may differ materially from those projected in forward-looking statements. 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.

View original content:https://www.prnewswire.com/news-releases/phx-minerals-inc-reports-second-fiscal-quarter-2022-results-record-royalty-volumes-and-a-quarterly-dividend-increase-of-33-301543011.html

SOURCE PHX MINERALS INC.

FAQ

What are the latest financial results for PHX Minerals (PHX)?

PHX reported a net loss of $4 million for Q2 2022, with total production volumes at 2,460 Mmcfe.

How much did PHX increase its dividend in May 2022?

PHX announced a 33% increase in its quarterly dividend to $0.02 per share.

What factors contributed to the change in PHX's earnings?

Increased revenue from natural gas, oil, and NGL sales was offset by substantial unrealized losses on derivative contracts.

How much did PHX spend on acquisitions in the second quarter of 2022?

PHX closed on acquisitions totaling approximately $9.3 million for 825 net royalty acres.

What was PHX's adjusted EBITDA for the second quarter?

PHX's adjusted EBITDA for Q2 2022 was $5.8 million, up from $3.6 million in Q2 2021.