OKLAHOMA
CITY, Nov. 14, 2022 /PRNewswire/ -- Riley
Exploration Permian, Inc. (NYSE American: REPX) ("Riley Permian" or
the "Company"), today reported financial and operating results for
the third quarter ended September 30,
2022.
HIGHLIGHTS FOR THE THIRD QUARTER ENDING SEPTEMBER 30, 2022
- Averaged oil production of 9.4 MBbls per day, which exceeds the
high end of guidance and represents an increase of 36% as compared
year-over-year to the third quarter 2021 and an increase of 13% as
compared quarter-over-quarter to the second quarter 2022
- Began water injection on our EOR project during the third
quarter and CO2 injection during the fourth quarter
- Reported net income of $60
million, which includes $35
million of non-cash gain on derivative contracts and income
from operations of $59 million
- Generated $51 million of Adjusted
EBITDAX(1) and $55 million
of operating cash flow, representing an increase of 14% and 25%,
respectively, over the prior quarter
- Incurred total accrual (activity-based) capital expenditures of
$37 million and total cash capital
expenditures of $35 million
- Paid dividends of $0.31 per share
for a total of $6 million during the
third quarter and paid dividends of $0.34 per share in the fourth quarter
- Completed change in fiscal year end to December 31st from September 30th
"During our calendar third quarter, we generated several
record-high metrics, including oil and total production, cash flow
from operations and earnings per share," said Riley Permian
Chairman and CEO, Bobby Riley. "We
continue to benefit from a decreased impact of financial hedges
this quarter, relative to prior quarters and to 2021, and we see a
continuation of that trend into 2023. Like others in our industry,
we continue to manage a number of operational challenges, including
variable service company availability, slower inventory procurement
and generally increasing costs. We're pleased with the water
injection phase of our EOR project and excited to have recently
begun CO2 injection. Based on the strength of our
results this year, we raised the dividend by ten percent, as
declared in October 2022. Our
liquidity profile also strengthened with the combination of lower
borrowings on our credit facility and an increased borrowing
base."
___________________
|
(1)
|
See non-GAAP financial
measures section for definition and reconciliation.
|
Selected Operating
and Financial Data
|
|
|
|
|
|
|
|
|
|
|
(Unaudited)
|
|
Three Months
Ended
|
|
Nine Months
Ended
|
|
|
September 30,
2022
|
|
June 30,
2022
|
|
September 30,
2021
|
|
September 30,
2022
|
|
September 30,
2021
|
Select Financial
Data (in thousands):
|
|
|
|
|
|
|
|
|
|
|
Oil and natural gas
sales, net
|
|
$
87,471
|
|
$
87,781
|
|
$
48,014
|
|
$
241,897
|
|
$
126,222
|
Net income
(loss)
|
|
$
59,817
|
|
$
38,555
|
|
$
15,654
|
|
$
91,204
|
|
$
(57,725)
|
Adjusted
EBITDAX(1)
|
|
$
51,240
|
|
$
44,797
|
|
$
24,505
|
|
$
130,520
|
|
$
70,206
|
|
|
|
|
|
|
|
|
|
|
|
Production Data,
net:
|
|
|
|
|
|
|
|
|
|
|
Oil (MBbls)
|
|
866
|
|
761
|
|
639
|
|
2,301
|
|
1,793
|
Natural gas
(MMcf)
|
|
985
|
|
572
|
|
807
|
|
2,239
|
|
2,141
|
Natural gas liquids
(MBbls)
|
|
140
|
|
70
|
|
109
|
|
303
|
|
306
|
Total
(MBoe)
|
|
1,170
|
|
926
|
|
882
|
|
2,977
|
|
2,456
|
|
|
|
|
|
|
|
|
|
|
|
Daily combined volumes
(Boe/d)
|
|
12,717
|
|
10,176
|
|
9,581
|
|
10,903
|
|
8,997
|
Daily oil volumes
(Bbls/d)
|
|
9,413
|
|
8,363
|
|
6,940
|
|
8,428
|
|
6,569
|
|
|
|
|
|
|
|
|
|
|
|
Average Realized
Prices:
|
|
|
|
|
|
|
|
|
|
|
Oil ($ per
Bbl)
|
|
$
92.40
|
|
$
108.41
|
|
$
68.95
|
|
$
97.74
|
|
$
63.76
|
Natural gas ($ per
Mcf)
|
|
4.28
|
|
4.98
|
|
2.36
|
|
3.95
|
|
3.45
|
Natural gas liquids ($
per Bbl)
|
|
23.13
|
|
34.71
|
|
19.16
|
|
26.89
|
|
14.79
|
Total average price ($
per Boe)
|
|
$
74.76
|
|
$
94.80
|
|
$
54.46
|
|
$
81.26
|
|
$
51.39
|
|
|
|
|
|
|
|
|
|
|
|
Average Realized
Prices, including the effects
of derivative settlements(2):
|
|
|
|
|
|
|
|
|
|
|
Oil ($ per
Bbl)
|
|
$
75.80
|
|
$
77.31
|
|
$
52.30
|
|
$
73.63
|
|
$
51.97
|
Natural gas ($ per
Mcf)
|
|
1.57
|
|
1.29
|
|
1.69
|
|
1.40
|
|
3.28
|
Natural gas liquids ($
per Bbl)(3)
|
|
23.13
|
|
34.71
|
|
19.16
|
|
26.89
|
|
14.79
|
Total average price ($
per Boe)
|
|
$
60.20
|
|
$
66.97
|
|
$
41.79
|
|
$
60.69
|
|
$
42.65
|
|
|
|
|
|
|
|
|
|
|
|
Cash Costs ($ per
Boe)(1)
|
|
$
16.98
|
|
$
19.63
|
|
$
15.38
|
|
$
17.65
|
|
$
15.51
|
Cash Margin ($ per
Boe)(1)
|
|
$
57.78
|
|
$
75.17
|
|
$
39.08
|
|
$
63.61
|
|
$
35.88
|
Cash Margin, including
derivative settlements
($ per
Boe)(1)
|
|
$
43.22
|
|
$
47.34
|
|
$
26.41
|
|
$
43.04
|
|
$
27.14
|
_____________________
|
(1)
|
See non-GAAP financial
measures section for definition and reconciliation.
|
(2)
|
The Company's
calculation of the effects of derivative settlements includes
losses on the settlement of its commodity derivative contracts.
These losses are included under other income (expense) on the
Company's condensed consolidated statements of
operations.
|
(3)
|
During the periods
presented, the Company did not have any NGL derivative contracts in
place.
|
OPERATIONS AND DEVELOPMENT ACTIVITY UPDATE
Riley Permian averaged oil production of 9.4 MBbls per day for
the three months ended September 30,
2022, representing an increase of 36% as compared
year-over-year to the third quarter 2021 and 13% as compared
quarter-over-quarter to the second quarter 2022. The Company
averaged total equivalent production of 12.7 MBoe per day for the
three months ended September 30,
2022, an increase of 33% as compared to the same period in
2021 and 25% as compared to the prior quarter. Natural gas and NGL
volumes increased quarter-over-quarter at a higher rate than oil
volumes due to the additions in plant processing capacity by our
midstream counterparty.
The Company turned to sales 7 gross (4.2 net) horizontal wells
during the third quarter and 14 gross (10.8 net) horizontal well
during the nine months ended September 30,
2022. On its EOR pilot project, the Company began water
injection, and, subsequent to quarter end, in November 2022, the Company began CO2
injection.
The Company incurred $37 million in total accrued capital
expenditures for the three months ended September 30, 2022, which compares to the
Company's previously released guidance of $28 million to $34
million. Overages on accrued capital expenditures compared
to guidance are primarily related to higher than anticipated costs,
additional capital workovers and increased leasehold
acquisitions. During the quarter, the average completed
lateral length on operated horizontal wells turned to sales was
approximately 7,800 feet, which is a 10% increase in average
completed lateral length per well quarter-over-quarter, with
drilling and completion costs remaining relatively flat
quarter-over-quarter for similar type wells. On a cash basis, the
Company had total capital expenditures of $35 million for the three months ended
September 30, 2022.
FINANCIAL RESULTS
For the three months ended September 30,
2022, the Company reported net income of $60 million and operating income of $59 million. The Company generated Adjusted
EBITDAX(1) of $51 million,
operating cash flow of $55 million
and Free Cash Flow(1) of $15
million.
For the nine months ended September 30,
2022, the Company reported net income of $91 million and operating income of $163 million. The Company generated Adjusted
EBITDAX(1) of $131
million, operating cash flow of $130
million and Free Cash Flow(1) of $41 million. The pattern of the Company's
development activity affects cash capital expenditures and may
continue to cause fluctuations in Free Cash Flow(1) from
quarter to quarter with longer periods more representative of Free
Cash Flow(1) generation potential than an individual
quarter.
Third quarter 2022 average realized prices, before
derivative settlements were $92.40
per barrel of oil, $4.28 per Mcf of
natural gas and $23.13 per barrel of
natural gas liquids, resulting in a total equivalent price, before
derivative settlements, of $74.76 per
Boe. Adjusted for derivative settlements, total equivalent price
was $60.20 per Boe, corresponding to
realized derivative settlement losses of $14.56 per Boe or $17 million. The Company
reported an $18 million gain on
derivatives, which includes $17
million loss on settlements and $35
million non-cash gain due to changes in the fair value of
derivatives. Total oil and natural gas sales revenue net of
derivative settlements was $70 million, an increase of
$8 million or 14% over the second
quarter of 2022. Year-over-year, total oil and natural gas sales
revenue net of derivative settlements increased 91%.
Riley Permian's total Cash Costs(1) for the third
quarter of 2022 were $20 million,
representing an increase of 9% compared to the second quarter of
2022, which is less than the increase in production. Lease
operating expense ("LOE") was $8.8
million, corresponding to approximately the mid-point of
guidance and a 9% increase quarter-over-quarter. Cash G&A
expense(1) was $4.6
million, which was within guidance, and interest expense was
$0.6 million.
During the third quarter 2022, the Company paid common dividends
of $0.31 per share or
$6 million. Subsequent to the quarter end, the Company raised
the dividend by 10% to $0.34 per
share, which was paid in November
2022.
As of September 30, 2022, the
Company had $48 million drawn on its credit facility,
reflecting a paydown of $13 million
during the third quarter. In October
2022, the Company completed an amendment to its credit
facility which increased the borrowing base from $200 million
to $225 million.
__________________
|
(1)
|
See non-GAAP financial
measures section for definition and reconciliation.
|
FOURTH QUARTER 2022 OUTLOOK AND GUIDANCE
Based on currently scheduled development activity, the Company
forecasts fourth quarter 2022 oil production to average 9.4 MBbls
per day to 9.9 MBbls per day, with the midpoint average
representing 2.5% quarter-over-quarter growth and 33%
year-over-year growth. Based on estimates of available gas
processing capacity, we forecast total equivalent production to
average 12.6 MBoe per day to 13.2 MBoe per day for the fourth
quarter.
The Company forecasts fourth quarter 2022 LOE of approximately
$9.0 million to $10.5 million and Cash G&A
expenses(1) of approximately $4.7
million to $5.2 million. The
Company reported an effective tax rate of 21.6% based on taxable
income estimates for the nine months ended September 30, 2022 and is forecasting cash income
taxes of $3.0 million to $5.0 million, representing estimated federal and
state tax payments that will be paid during the fourth quarter,
based on forecasted 2022 taxable income.
Based on current market conditions, management forecasts accrual
basis capital expenditures of $35.0
million to $41.0 million for
the fourth quarter 2022, excluding amounts for corporate or land
acquisitions or other opportunistic investments.
___________________
|
(1)
|
See non-GAAP financial
measures section for definition.
|
CONFERENCE CALL
Riley Permian management will host a
conference call for investors and analysts on November 15, 2022 at 10:00
a.m. CT to discuss the Company's results. Interested parties
are invited to participate by calling:
- U.S./Canada Toll Free, (888) 330-2214
- International, +1 (646) 960-0161
- Conference ID number 5405646
An updated company presentation, which will include certain
items to be discussed on the call, will be posted prior to the call
on the Company's website (www.rileypermian.com). A replay of the
call will be available until November 29,
2022 by calling:
- (800) 770-2030 or (647) 362-9199
- Conference ID number 5405646
About Riley Exploration Permian, Inc.
Riley
Permian is a growth-oriented, independent oil and natural gas
company focused on the acquisition, exploration, development and
production of oil, natural gas and natural gas liquids. For more
information, please visit www.rileypermian.com.
Investor Contact:
Rick
D'Angelo
405-438-0126
IR@rileypermian.com
Cautionary Statement Regarding Forward Looking
Information
This press release contains 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. The statements contained in this release that are not
historical facts are forward-looking statements that represent
management's beliefs and assumptions based on currently available
information. Forward-looking statements include information
concerning our possible or assumed future results of operations,
business strategies, need for financing, competitive position and
potential growth opportunities. Our forward-looking statements do
not consider the effects of future legislation or regulations.
Forward-looking statements include all statements that are not
historical facts and can be identified by the use of
forward-looking terminology such as the words "believes,"
"intends," "may," "should," "anticipates," "expects," "could,"
"plans," "estimates," "projects," "targets," "forecasts" or
comparable terminology or by discussions of strategy or trends. You
should not place undue reliance on these forward-looking
statements. These forward-looking statements are subject to a
number of risks, uncertainties and assumptions. Moreover, we
operate in a very competitive and rapidly changing environment. New
risks emerge from time to time. It is not possible for our
management to predict all risks, nor can we assess the impact of
all factors on our business or the extent to which any factor, or
combination of factors, may cause actual results to differ
materially from those contained in any forward-looking statements
we may make. Although we believe that our plans, intentions and
expectations reflected in or suggested by the forward-looking
statements we make in this release are reasonable, we can give no
assurance that these plans, intentions or expectations will be
achieved or occur, and actual results could differ materially and
adversely from those anticipated or implied by the forward-looking
statements.
Among the factors that could cause actual future results to
differ materially are the risks and uncertainties the Company is
exposed to. While it is not possible to identify all factors, we
continue to face many risks and uncertainties including, but not
limited to: the volatility of oil, natural gas and NGL prices; the
scope, duration, and reoccurrence of any epidemics or pandemics
(including, specifically, the coronavirus disease 2019 ("COVID-19")
pandemic and any related variants), including reactive or proactive
measures taken by governments, regulatory agencies and businesses
related to the pandemic, and the effects of COVID-19 on the oil and
natural gas industry, pricing and demand for oil and natural gas
and supply chain logistics; regional supply and demand factors, any
delays, curtailment delays or interruptions of production, and any
governmental order, rule or regulation that may impose production
limits; cost and availability of gathering, pipeline, refining,
transportation and other midstream and downstream activities;
severe weather and other risks that lead to a lack of any available
markets; our ability to successfully complete mergers, acquisitions
and divestitures; the risk that the Company's EOR project may not
perform as expected or produce the anticipated benefits; risks
relating to our operations, including development drilling and
testing results and performance of acquired properties and newly
drilled wells; any reduction in our borrowing base on our revolving
credit facility from time to time and our ability to repay any
excess borrowings as a result of such reduction; the impact of our
derivative strategy and the results of future settlement; our
ability to comply with the financial covenants contained in our
credit agreement; conditions in the capital, financial and credit
markets and our ability to obtain capital needed for development
and exploration operations on favorable terms or at all; the loss
of certain tax deductions; risks associated with executing our
business strategy, including any changes in our strategy; inability
to prove up undeveloped acreage and maintain production on leases;
risks associated with concentration of operations in one major
geographic area; legislative or regulatory changes, including
initiatives related to hydraulic fracturing, emissions, and
disposal of produced water, which may be negatively impacted by
regulation or legislation; the ability to receive drilling and
other permits or approvals and rights-of-way in a timely manner (or
at all), which may be restricted by governmental regulation and
legislation; risks related to litigation; evolving geopolitical and
military hostilities in other areas of the world; and cybersecurity
threats, technology system failures and data security issues.
Additional factors that could cause results to differ materially
from those described above can be found in Riley Permian's Annual
Report on Form 10-K for the year ended September 30, 2021 filed with the SEC and
available from the Company's website at www.rileypermian.com
under the "Investor" tab, and in other documents the Company
files with the SEC.
The forward-looking statements in this press release are made as
of the date hereof and are based on information available at that
time. The Company does not undertake, and expressly disclaims, any
duty to update or revise our forward-looking statements based on
new information, future events or otherwise.
Cautionary Statement Regarding Guidance
The estimates and guidance presented in this release are based
on assumptions of current and future capital expenditure levels,
prices for oil, natural gas and NGLs, available liquidity,
indications of supply and demand for oil, well results, and
operating costs. The guidance provided in this release does not
constitute any form of guarantee or assurance that the matters
indicated will be achieved. While we believe these estimates and
the assumptions on which they are based are reasonable as of the
date on which they are made, they are inherently uncertain and are
subject to, among other things, significant business, economic,
operational, and regulatory risks, and uncertainties, some of which
are not known as of the date of the statement. Guidance and
estimates, and the assumptions on which they are based, are subject
to material revision. Actual results may differ materially from
estimates and guidance. Please read the "Cautionary Statement
Regarding Forward Looking Information" section above, as well as
"Risk Factors" in our annual report on Form 10-K and our quarterly
reports on Form 10-Q, which are incorporated herein.
Cautionary Statement Regarding Reserves
The reserves information as of September
30, 2022 in this press release, including standardized
measure of future discounted cash flows and PV-10
value(1) are preliminary estimates that have not been
audited or reviewed by Netherland, Sewell & Associates, Inc. or
BDO USA, LLP and are subject to
material revision. These are estimates that should not be regarded
as a representation. Investors should not place undue reliance on
these estimates.
_________________
|
(1)
|
See non-GAAP financial
measures section for definition and reconciliation.
|
RILEY EXPLORATION
PERMIAN, INC.
|
CONDENSED
CONSOLIDATED BALANCE SHEETS
|
|
|
(Unaudited)
|
|
|
|
|
September 30,
2022
|
|
December 31,
2021
|
|
|
(In thousands,
except share amounts)
|
Assets
|
|
|
|
|
Current
Assets:
|
|
|
|
|
Cash and cash
equivalents
|
|
$
17,908
|
|
$
8,317
|
Accounts
receivable
|
|
27,463
|
|
18,002
|
Prepaid expenses and
other current assets
|
|
3,377
|
|
4,902
|
Current derivative
assets
|
|
1,607
|
|
83
|
Total current
assets
|
|
50,355
|
|
31,304
|
Oil and natural gas
properties, net (successful efforts)
|
|
431,067
|
|
359,131
|
Other property and
equipment, net
|
|
4,822
|
|
3,174
|
Non-current derivative
assets
|
|
—
|
|
267
|
Other non-current
assets, net
|
|
4,307
|
|
2,293
|
Total
Assets
|
|
$
490,551
|
|
$
396,169
|
Liabilities and
Shareholders' Equity
|
|
|
|
|
Current
Liabilities:
|
|
|
|
|
Accounts
payable
|
|
$
10,854
|
|
$
7,737
|
Accounts payable -
related parties
|
|
122
|
|
164
|
Accrued
liabilities
|
|
28,785
|
|
12,874
|
Revenue
payable
|
|
17,768
|
|
11,370
|
Current derivative
liabilities
|
|
22,529
|
|
30,984
|
Other current
liabilities
|
|
3,003
|
|
947
|
Total Current
Liabilities
|
|
83,061
|
|
64,076
|
Non-current derivative
liabilities
|
|
2,423
|
|
9,515
|
Asset retirement
obligations
|
|
2,689
|
|
2,261
|
Revolving credit
facility
|
|
48,000
|
|
65,000
|
Deferred tax
liabilities
|
|
40,586
|
|
17,384
|
Other non-current
liabilities
|
|
1,138
|
|
95
|
Total
Liabilities
|
|
177,897
|
|
158,331
|
Commitments and
Contingencies
|
|
|
|
|
Shareholders'
Equity:
|
|
|
|
|
Preferred stock,
$0.0001 par value, 25,000,000 shares authorized; 0 shares
issued
and outstanding
|
|
—
|
|
—
|
Common stock, $0.001
par value, 240,000,000 shares authorized; 20,181,872 and
19,836,885 shares issued and outstanding at September 30, 2022 and
December
31, 2021, respectively
|
|
20
|
|
20
|
Additional paid-in
capital
|
|
273,821
|
|
271,737
|
Retained earnings
(Accumulated deficit)
|
|
38,813
|
|
(33,919)
|
Total Shareholders'
Equity
|
|
312,654
|
|
237,838
|
Total Liabilities
and Shareholders' Equity
|
|
$
490,551
|
|
$
396,169
|
RILEY EXPLORATION
PERMIAN, INC.
|
CONDENSED
CONSOLIDATED STATEMENTS OF OPERATIONS
|
(Unaudited)
|
|
|
Three Months Ended
September 30,
|
|
Nine Months Ended
September 30,
|
|
|
2022
|
|
2021
|
|
2022
|
|
2021
|
|
|
(In
thousands)
|
Revenues:
|
|
|
|
|
|
|
|
|
Oil and natural gas
sales, net
|
|
$
87,471
|
|
$
48,014
|
|
$
241,897
|
|
$
126,222
|
Contract services -
related parties
|
|
600
|
|
600
|
|
1,800
|
|
1,800
|
Total
Revenues
|
|
88,071
|
|
48,614
|
|
243,697
|
|
128,022
|
Costs and
Expenses:
|
|
|
|
|
|
|
|
|
Lease operating
expenses
|
|
8,813
|
|
5,686
|
|
23,705
|
|
17,407
|
Production and ad
valorem taxes
|
|
5,826
|
|
2,575
|
|
14,854
|
|
7,347
|
Exploration
costs
|
|
20
|
|
884
|
|
1,540
|
|
9,142
|
Depletion,
depreciation, amortization and accretion
|
|
8,346
|
|
6,692
|
|
22,167
|
|
20,025
|
General and
administrative:
|
|
|
|
|
|
|
|
|
Administrative
costs
|
|
5,154
|
|
4,790
|
|
13,567
|
|
11,516
|
Unit-based
compensation expense
|
|
—
|
|
—
|
|
—
|
|
276
|
Share-based
compensation expense
|
|
704
|
|
751
|
|
2,274
|
|
6,101
|
Cost of contract
services - related parties
|
|
89
|
|
147
|
|
263
|
|
329
|
Transaction
costs
|
|
—
|
|
198
|
|
2,638
|
|
2,683
|
Total Costs and
Expenses
|
|
28,952
|
|
21,723
|
|
81,008
|
|
74,826
|
Income From
Operations
|
|
59,119
|
|
26,891
|
|
162,689
|
|
53,196
|
Other Income
(Expense):
|
|
|
|
|
|
|
|
|
Interest expense,
net
|
|
(585)
|
|
(963)
|
|
(1,960)
|
|
(3,299)
|
Gain (loss) on
derivatives
|
|
17,600
|
|
(14,987)
|
|
(44,395)
|
|
(75,286)
|
Total Other Income
(Expense)
|
|
17,015
|
|
(15,950)
|
|
(46,355)
|
|
(78,585)
|
Net Income (Loss)
from Continuing Operations Before Income Taxes
|
|
76,134
|
|
10,941
|
|
116,334
|
|
(25,389)
|
Income tax benefit
(expense)
|
|
(16,317)
|
|
3,937
|
|
(25,130)
|
|
(13,539)
|
Net Income (Loss)
from Continuing Operations
|
|
59,817
|
|
14,878
|
|
91,204
|
|
(38,928)
|
Discontinued
Operations:
|
|
|
|
|
|
|
|
|
Gain (loss) from
discontinued operations
|
|
—
|
|
775
|
|
—
|
|
(18,738)
|
Income tax benefit
(expense) on discontinued operations
|
|
—
|
|
1
|
|
—
|
|
(59)
|
Gain (Loss) on
Discontinued Operations
|
|
—
|
|
776
|
|
—
|
|
(18,797)
|
Net Income
(Loss)
|
|
59,817
|
|
15,654
|
|
91,204
|
|
(57,725)
|
Dividends on preferred
units
|
|
—
|
|
—
|
|
—
|
|
(574)
|
Net Income (Loss)
Attributable to Common Shareholders/Unitholders
|
|
$
59,817
|
|
$
15,654
|
|
$
91,204
|
|
$
(58,299)
|
RILEY EXPLORATION
PERMIAN, INC.
|
CONDENSED
CONSOLIDATED STATEMENTS OF CASH FLOWS
|
(Unaudited)
|
|
|
Three Months Ended
September 30,
|
|
Nine Months Ended
September 30,
|
|
|
2022
|
|
2021
|
|
2022
|
|
2021
|
|
|
(In
thousands)
|
Cash Flows from
Operating Activities:
|
|
|
|
|
|
|
|
|
Net income
(loss)
|
|
$
59,817
|
|
$
15,654
|
|
$
91,204
|
|
$
(57,725)
|
Adjustments to
reconcile net income (loss) to net cash provided by operating
activities:
|
|
|
|
|
|
|
|
|
(Gain) loss from
discontinued operations
|
|
—
|
|
(776)
|
|
—
|
|
18,797
|
Oil and gas lease
expirations
|
|
—
|
|
732
|
|
1,465
|
|
8,923
|
Depletion,
depreciation, amortization and accretion
|
|
8,346
|
|
6,692
|
|
22,167
|
|
20,025
|
(Gain) loss on
derivatives
|
|
(17,600)
|
|
14,987
|
|
44,395
|
|
75,286
|
Settlements on
derivative contracts
|
|
(17,040)
|
|
(11,171)
|
|
(61,198)
|
|
(21,477)
|
Amortization of
deferred financing costs
|
|
175
|
|
170
|
|
548
|
|
498
|
Unit-based
compensation expense
|
|
—
|
|
—
|
|
—
|
|
276
|
Share-based
compensation expense
|
|
795
|
|
751
|
|
2,684
|
|
6,101
|
Deferred income tax
expense (benefit)
|
|
15,884
|
|
(4,223)
|
|
23,202
|
|
13,352
|
Changes in operating
assets and liabilities
|
|
4,921
|
|
4,430
|
|
5,885
|
|
6,130
|
Net Cash Provided
by Operating Activities - Continuing Operations
|
|
55,298
|
|
27,246
|
|
130,352
|
|
70,186
|
Cash Flows from
Investing Activities:
|
|
|
|
|
|
|
|
|
Additions to oil and
natural gas properties
|
|
(35,054)
|
|
(19,746)
|
|
(82,101)
|
|
(50,247)
|
Acquisitions of oil
and natural gas properties
|
|
—
|
|
—
|
|
—
|
|
(445)
|
Additions to other
property and equipment
|
|
(61)
|
|
(541)
|
|
(1,081)
|
|
(1,396)
|
Tengasco acquired
cash
|
|
—
|
|
—
|
|
—
|
|
859
|
Net Cash Used in
Investing Activities - Continuing Operations
|
(35,115)
|
|
(20,287)
|
|
(83,182)
|
|
(51,229)
|
Cash Flows from
Financing Activities:
|
|
|
|
|
|
|
|
|
Deferred financing
costs
|
|
(7)
|
|
(4)
|
|
(1,722)
|
|
(86)
|
Proceeds from
revolving credit facility
|
|
—
|
|
—
|
|
4,000
|
|
3,500
|
Repayment under
revolving credit facility
|
|
(13,000)
|
|
(37,500)
|
|
(21,000)
|
|
(41,000)
|
Payment of common
share/unit dividends
|
|
(6,059)
|
|
(5,452)
|
|
(18,257)
|
|
(14,568)
|
Proceeds from issuance
of common stock
|
|
—
|
|
50,000
|
|
—
|
|
50,000
|
Public offering
costs
|
|
—
|
|
(3,316)
|
|
—
|
|
(3,316)
|
Payment of preferred
unit dividends
|
|
—
|
|
—
|
|
—
|
|
(1,491)
|
Common stock
repurchased for tax withholding
|
|
(9)
|
|
(514)
|
|
(600)
|
|
(514)
|
Purchase of common
units under long-term incentive plan
|
|
—
|
|
—
|
|
—
|
|
(191)
|
Net Cash Provided
by (Used in) Financing Activities - Continuing
Operations
|
|
(19,075)
|
|
3,214
|
|
(37,579)
|
|
(7,666)
|
Net Increase in Cash
and Cash Equivalents from Continuing Operations
|
|
1,108
|
|
10,173
|
|
9,591
|
|
11,291
|
Cash Flows from
Discontinued Operations:
|
|
|
|
|
|
|
|
|
Operating
activities
|
|
—
|
|
—
|
|
—
|
|
7
|
Investing
activities
|
|
—
|
|
—
|
|
—
|
|
3,892
|
Net Increase in Cash
and Cash Equivalents from Discontinued Operations
|
|
—
|
|
—
|
|
—
|
|
3,899
|
Net Increase in Cash
and Cash Equivalents
|
|
1,108
|
|
10,173
|
|
9,591
|
|
15,190
|
Cash and Cash
Equivalents, Beginning of Period
|
|
16,800
|
|
6,894
|
|
8,317
|
|
1,877
|
Cash and Cash
Equivalents, End of Period
|
|
$
17,908
|
|
$
17,067
|
|
$
17,908
|
|
$
17,067
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
OIL, NATURAL GAS AND NGL RESERVES
The Company prepared estimates of reserves using an average
price equal to the unweighted arithmetic average of the first day
of each month within the 12-month period ended September 30, 2022 of $92.16 per Bbl for oil and $6.13 per Mcf for gas in accordance with SEC
guidelines. The Company also prepared estimates of proved reserves
as of September 30, 2022 using NYMEX
pricing. Netherland, Sewell & Associates, Inc. ("NSAI") is the
Company's third-party reservoir engineer, which prepares estimates
of the Company's proved reserves annually as of its year-end, in
accordance with the rules and regulations of the SEC. NSAI has not
reviewed our proved reserves at September
30, 2022 using SEC or NYMEX pricing. A summary of these
internal estimates as of September 30,
2022 is presented below.
|
|
SEC
Pricing
|
|
NYMEX
Pricing(2)
|
Reserves as of
September 30, 2022
|
|
Proved
Developed
Reserves
|
|
Total Proved
Reserves
|
|
Proved
Developed
Reserves
|
|
Total Proved
Reserves
|
Oil (MBbls)
|
|
30,479
|
|
51,417
|
|
29,892
|
|
50,378
|
Natural gas
(MMcf)
|
|
66,127
|
|
96,584
|
|
65,018
|
|
94,713
|
Natural gas liquids
(MBbls)
|
|
10,994
|
|
16,599
|
|
10,815
|
|
16,281
|
Total
(MBoe)
|
|
52,494
|
|
84,113
|
|
51,543
|
|
82,444
|
PV-10(1)
(in thousands)
|
|
$
1,120,244
|
|
$
1,571,033
|
|
$
711,402
|
|
$
874,147
|
___________________
(1)
|
See non-GAAP measures
section for definition and reconciliation.
|
(2)
|
See table below for the
NYMEX pricing used to prepare internal reserve
estimates.
|
|
Oil
|
|
Natural Gas
|
|
($ per Bbl)
|
|
($ per Mcf)
|
October 2022-December
2022
|
$
78.35
|
|
$
6.87
|
Calendar year
2023
|
$
72.13
|
|
$
5.44
|
Calendar year
2024
|
$
66.63
|
|
$
4.74
|
Calendar year
2025
|
$
63.25
|
|
$
4.58
|
Calendar year
2026
|
$
60.72
|
|
$
4.45
|
After 2026
|
$
59.76
|
|
$
4.87
|
OIL, NATURAL GAS AND NGL RESERVES, Continued
Estimates of reserves were prepared using an average price equal
to the unweighted arithmetic average of the first day of each month
within the 12-month period ended December
31, 2021 of $66.55 per Bbl for
oil and $3.60 per Mcf for gas in
accordance with SEC guidelines. Additionally, the Company prepared
estimates of proved reserves as of December
31, 2021 using NYMEX pricing. The table below presents a
summary of our proved reserves as of December 31, 2021.
|
|
SEC
Pricing
|
|
NYMEX
Pricing(2)
|
Reserves as of
December 31, 2021
|
|
Proved
Developed
Reserves
|
|
Total Proved
Reserves
|
|
Proved
Developed
Reserves
|
|
Total Proved
Reserves
|
Oil (MBbls)
|
|
27,096
|
|
47,021
|
|
26,964
|
|
46,848
|
Natural gas
(MMcf)
|
|
47,974
|
|
77,486
|
|
47,728
|
|
77,185
|
Natural gas liquids
(MBbls)
|
|
7,949
|
|
13,471
|
|
7,910
|
|
13,423
|
Total
(MBoe)
|
|
43,041
|
|
73,406
|
|
42,829
|
|
73,135
|
PV-10(1)
(in thousands)
|
|
$
616,231
|
|
$
879,143
|
|
$
589,287
|
|
$
808,676
|
___________________
(1)
|
Non-GAAP financial
measure, which is defined and reconciled below.
|
(2)
|
See table below for the
NYMEX pricing used to prepare internal reserve
estimates.
|
|
Oil
|
|
Natural Gas
|
|
($ per Bbl)
|
|
($ per Mcf)
|
Calendar year
2022
|
$
72.23
|
|
$
3.69
|
Calendar year
2023
|
$
66.39
|
|
$
3.36
|
Calendar year
2024
|
$
62.66
|
|
$
3.13
|
Calendar year
2025
|
$
60.12
|
|
$
3.07
|
After 2025
|
$
59.19
|
|
$
3.33
|
Reserve estimates above do not include any value for probable or
possible reserves that may exist, nor do they include any value for
undeveloped acreage. The reserve estimates represent our net
revenue interest in our properties, all of which are located within
the continental United States.
NYMEX pricing does not comport with the reporting requirements of
the SEC and should not be used as a substitute for or compared with
estimates of proved reserves using SEC pricing.
DERIVATIVE CONTRACTS
The following table summarizes the open financial derivatives as
of November 8, 2022, related to oil
and natural gas production. Derivative positions in the table for
calendar Q3 2022 are as of September 30,
2022(1).
|
|
|
|
Weighted Average
Price
|
Calendar
Quarter
|
|
Notional
Volume
|
|
Fixed
|
|
Put
|
|
Call
|
|
|
|
|
($ per unit)
|
Oil Swaps
(Bbl)
|
|
|
|
|
|
|
|
|
Q4 2022
|
|
270,000
|
|
$
56.03
|
|
$
—
|
|
$
—
|
Q1 2023
|
|
225,000
|
|
$
53.65
|
|
$
—
|
|
$
—
|
Q2 2023
|
|
195,000
|
|
$
53.89
|
|
$
—
|
|
$
—
|
Q3 2023
|
|
150,000
|
|
$
52.58
|
|
$
—
|
|
$
—
|
Q4 2023
|
|
150,000
|
|
$
52.58
|
|
$
—
|
|
$
—
|
|
|
|
|
|
|
|
|
|
Natural Gas Swaps
(Mcf)
|
|
|
|
|
|
|
|
|
Q4 2022
|
|
540,000
|
|
$
3.26
|
|
$
—
|
|
$
—
|
|
|
|
|
|
|
|
|
|
Oil Collars
(Bbl)
|
|
|
|
|
|
|
|
|
Q4 2022
|
|
90,000
|
|
$
—
|
|
$
35.00
|
|
$
42.63
|
Q1 2023
|
|
30,000
|
|
$
—
|
|
$
60.00
|
|
$
109.60
|
Q2 2023
|
|
30,000
|
|
$
—
|
|
$
60.00
|
|
$
109.60
|
Q1 2024
|
|
3,000
|
|
$
—
|
|
$
50.00
|
|
$
88.00
|
|
|
|
|
|
|
|
|
|
Oil Basis
(Bbl)
|
|
|
|
|
|
|
|
|
Q4 2022
|
|
240,000
|
|
$
0.41
|
|
$
—
|
|
$
—
|
___________________
(1)
|
Q4 2022 derivative
positions shown include October 2022 contracts, some of which have
settled as of November 8, 2022.
|
NON-GAAP MEASURES
The Company presents certain non-GAAP financial measures to
supplement its financial statements prepared in accordance with
accounting principles generally accepted in the United States ("GAAP"). The non-GAAP
financial measures include Adjusted Net Income, Adjusted EBITDAX,
Cash G&A, Cash Costs and Cash Margin per Boe, Free Cash Flow
and PV-10. A reconciliation of each non-GAAP measure to the most
directly comparable GAAP financial measure is presented below.
We believe that these non-GAAP measures presented, in
conjunction with our financial and operating results prepared in
accordance with GAAP, provide a more complete understanding of the
Company's performance. We use these non-GAAP measures to compare
our financial and operating performance with that of other
companies in the oil and natural gas industry as well as our
financial and operating performance for current and historical
periods. These non-GAAP measures should not be considered in
isolation or as a substitute for GAAP measures, such as net income
(loss), operating income (loss), total costs and expenses, general
and administrative expenses, net cash provided by operating
activities or standardized measure of discounted future net cash
flows or any other GAAP measure of financial position or results of
operations.
As not all companies use the same calculation, our non-GAAP
measures may not be comparable to similarly titled measures
presented by other companies.
Adjusted Net Income: We define Adjusted Net Income
as net income (loss) plus (gain) loss on discontinued operations,
non-cash (gain) loss on derivatives, transaction costs and other,
income tax expense related to our change in tax status and the
changes in estimated income tax as a result of these adjustments.
We believe that Adjusted Net Income is a widely followed measure of
operating performance and is one of many metrics used by investors
as well as our management team. For example, Adjusted Net Income
can be used to assess our operating performance and return on
capital in comparison to other independent exploration and
production companies without regard to financial or capital
structure and to assess the financial performance of our assets and
our company without regard to capital structure or historical cost
basis. The following table provides a reconciliation of Net Income
(Loss) to Adjusted Net Income for the periods indicated:
|
|
Three Months
Ended
|
|
Nine months
ended
|
|
|
September 30,
2022
|
|
June 30,
2022
|
|
September 30,
2021
|
|
September 30,
2022
|
|
September 30,
2021
|
|
|
(Unaudited, In
thousands)
|
Net Income
(Loss)
|
|
$
59,817
|
|
$
38,555
|
|
$
15,654
|
|
$
91,204
|
|
$
(57,725)
|
(Gain) loss on
discontinued operations
|
|
—
|
|
—
|
|
(776)
|
|
—
|
|
18,797
|
Non-cash (gain) loss
on derivatives
|
|
(34,640)
|
|
(13,420)
|
|
3,816
|
|
(16,803)
|
|
53,809
|
Transaction costs and
other
|
|
—
|
|
—
|
|
458
|
|
2,638
|
|
2,943
|
Income tax expense
from change in tax status
|
|
—
|
|
—
|
|
—
|
|
—
|
|
13,631
|
Tax effect of
adjustments(1)
|
|
7,448
|
|
2,885
|
|
(755)
|
|
3,044
|
|
646
|
Adjusted Net
Income
|
|
$
32,625
|
|
$
28,020
|
|
$
18,397
|
|
$
80,083
|
|
$
32,101
|
___________________
(1)
|
Computed by applying a
combined federal and state statutory rate of 21.5% effective as of
September 30, 2022, June 30, 2022, and September 30, 2021,
respectively. The Company was a flow-through entity for federal and
state income tax purposes for the periods through February 26,
2021.
|
Adjusted EBITDAX: We define Adjusted EBITDAX as
net income (loss) adjusted for (gain) loss on discontinued
operations, exploration costs, depletion, depreciation,
amortization and accretion, equity-based compensation expense,
interest expense, non-cash (gain) loss on derivatives, income taxes
and transaction costs and other. We believe Adjusted EBITDAX is
useful to investors because it provides an effective way to
evaluate our operating performance and compare the results of our
operations from period to period as well as to other companies in
the oil and natural gas industry without regard to our financing
methods or capital structure. The following table provides a
reconciliation from the GAAP measure of Net Income (Loss) to
Adjusted EBITDAX.
|
|
Three Months
Ended
|
|
Nine months
ended
|
|
|
September 30,
2022
|
|
June 30,
2022
|
|
September 30,
2021
|
|
September 30,
2022
|
|
September 30,
2021
|
|
|
(Unaudited, In
thousands)
|
Net Income
(Loss)
|
|
$
59,817
|
|
$
38,555
|
|
$
15,654
|
|
$
91,204
|
|
$
(57,725)
|
(Gain) loss on
discontinued operations
|
|
—
|
|
—
|
|
(776)
|
|
—
|
|
18,797
|
Exploration
costs
|
|
20
|
|
22
|
|
884
|
|
1,540
|
|
9,142
|
Depletion,
depreciation, amortization and accretion
|
|
8,346
|
|
7,188
|
|
6,692
|
|
22,167
|
|
20,025
|
Unit-based
compensation expense
|
|
—
|
|
—
|
|
—
|
|
—
|
|
276
|
Share-based
compensation expense
|
|
795
|
|
828
|
|
751
|
|
2,684
|
|
6,101
|
Interest expense,
net
|
|
585
|
|
697
|
|
963
|
|
1,960
|
|
3,299
|
Non-cash (gain) loss
on derivatives
|
|
(34,640)
|
|
(13,420)
|
|
3,816
|
|
(16,803)
|
|
53,809
|
Income tax expense
(benefit)
|
|
16,317
|
|
10,927
|
|
(3,937)
|
|
25,130
|
|
13,539
|
Transaction costs and
other
|
|
—
|
|
—
|
|
458
|
|
2,638
|
|
2,943
|
Adjusted
EBITDAX
|
|
$
51,240
|
|
$
44,797
|
|
$
24,505
|
|
$
130,520
|
|
$
70,206
|
Cash G&A: Cash G&A is defined as general and
administrative expense, excluding equity-based compensation, plus
cost of contract services–related parties less contract
services–related parties revenue. We believe Cash G&A is used
by analysts and others in valuation, comparison and investment
recommendations of companies in our industry to allow for analysis
of Cash G&A spend without regard to equity-based compensation
programs or amounts related to contract services. Administrative
costs exclude equity-based compensation as those expenses are
presented separately as components of general and administrative
expense on our condensed consolidated statement of operations. The
following table provides a calculation of Cash G&A for the
periods indicated:
|
|
Three Months
Ended
|
|
Nine months
ended
|
|
|
September 30,
2022
|
|
June 30,
2022
|
|
September 30,
2021
|
|
September 30,
2022
|
|
September 30,
2021
|
|
|
(Unaudited, In
thousands)
|
Administrative
costs
|
|
$
5,154
|
|
$
4,399
|
|
$
4,790
|
|
$
13,567
|
|
$
11,516
|
Plus: Costs of contract
services - related parties
|
|
89
|
|
89
|
|
147
|
|
263
|
|
329
|
Less: Contract services
revenues - related parties
|
|
(600)
|
|
(600)
|
|
(600)
|
|
(1,800)
|
|
(1,800)
|
Total Cash
G&A
|
|
$
4,643
|
|
$
3,888
|
|
$
4,337
|
|
$
12,030
|
|
$
10,045
|
Cash Costs and Cash Margin per Boe: Cash Costs is a
non-GAAP financial measure that we use as an indicator of our total
cash-based cost of production and operations. We define Cash Costs
as lease operating expenses plus production and ad valorem taxes,
Cash G&A(1), and interest expense. Management
believes that Cash Costs is an important financial measure for use
in evaluating the Company's operating and financial performance and
for comparison to other companies in the oil and natural gas
industry. We also believe this is a useful measure for investors in
evaluating our results against other oil and natural gas companies.
Cash Costs should be considered in addition to, rather than as a
substitute for, Total Costs and Expenses on our condensed
consolidated statement of operations. The following table provides
a calculation of Cash Costs and Cash Margin for the periods
indicated:
|
|
Three Months
Ended
|
|
Nine months
ended
|
|
|
September 30,
2022
|
|
June 30,
2022
|
|
September 30,
2021
|
|
September 30,
2022
|
|
September 30,
2021
|
|
|
(Unaudited, In
thousands, except per Boe amounts)
|
Cash
Costs:
|
|
|
|
|
|
|
|
|
|
|
Lease operating
expenses
|
|
$
8,813
|
|
$
8,062
|
|
$
5,686
|
|
$
23,705
|
|
$
17,407
|
Production and ad
valorem taxes
|
|
5,826
|
|
5,526
|
|
2,575
|
|
14,854
|
|
7,347
|
Cash
G&A(1)
|
|
4,643
|
|
3,888
|
|
4,337
|
|
12,030
|
|
10,045
|
Interest expense,
net
|
|
585
|
|
697
|
|
963
|
|
1,960
|
|
3,299
|
Total Cash
Costs
|
|
$
19,867
|
|
$
18,173
|
|
$
13,561
|
|
$
52,549
|
|
$
38,098
|
|
|
|
|
|
|
|
|
|
|
|
Total Production
(MBoe)
|
|
1,170
|
|
926
|
|
882
|
|
2,977
|
|
2,456
|
|
|
|
|
|
|
|
|
|
|
|
Cash Margin ($ per
Boe):
|
|
|
|
|
|
|
|
|
|
|
Total average realized
price ($ per Boe)
|
|
$
74.76
|
|
$
94.80
|
|
$
54.46
|
|
$
81.26
|
|
$
51.39
|
Less:
|
|
|
|
|
|
|
|
|
|
|
Lease operating
expenses
|
|
7.53
|
|
8.71
|
|
6.45
|
|
7.96
|
|
7.09
|
Production and ad
valorem taxes
|
|
4.98
|
|
5.97
|
|
2.92
|
|
4.99
|
|
2.99
|
Cash
G&A(1)
|
|
3.97
|
|
4.20
|
|
4.92
|
|
4.04
|
|
4.09
|
Interest expense,
net
|
|
0.50
|
|
0.75
|
|
1.09
|
|
0.66
|
|
1.34
|
Total Cash Costs per
Boe
|
|
16.98
|
|
19.63
|
|
15.38
|
|
17.65
|
|
15.51
|
Cash Margin per
Boe
|
|
$
57.78
|
|
$
75.17
|
|
$
39.08
|
|
$
63.61
|
|
$
35.88
|
|
|
|
|
|
|
|
|
|
|
|
Settlements on
derivatives ($ per Boe)
|
|
(14.56)
|
|
(27.83)
|
|
(12.67)
|
|
(20.57)
|
|
(8.74)
|
Cash Margin per Boe,
including derivative settlements
|
|
$
43.22
|
|
$
47.34
|
|
$
26.41
|
|
$
43.04
|
|
$
27.14
|
______________________
(1)
|
A non-GAAP financial
measure which is reconciled above.
|
Free Cash Flow: Free Cash Flow is a measure that we
use as an indicator of our ability to fund our development
activities and generate excess cash for other corporate purposes.
We define Free Cash Flow as Net Cash Provided by Operating
Activities before changes in working capital and reduced by capital
expenditures before acquisitions. Free Cash Flow should be
considered in addition to, rather than as a substitute for, net
cash provided by operating activities as a measure of our
liquidity. The following table provides a reconciliation of Net
Cash Provided by Operating Activities to Free Cash Flow for the
periods indicated:
|
|
Three Months
Ended
|
|
Nine months
ended
|
|
|
September 30,
2022
|
|
June 30,
2022
|
|
September 30,
2021
|
|
September 30,
2022
|
|
September 30,
2021
|
|
|
(Unaudited, In
thousands)
|
Net Cash Provided by
Operating Activities
|
|
$
55,298
|
|
$
44,159
|
|
$
27,246
|
|
$ 130,352
|
|
$
70,186
|
Exclude changes in
working capital
|
|
(4,921)
|
|
(614)
|
|
(4,430)
|
|
(5,885)
|
|
(6,130)
|
Additions to oil and
natural gas properties
|
|
(35,054)
|
|
(36,876)
|
|
(19,746)
|
|
(82,101)
|
|
(50,247)
|
Additions to other
property and equipment
|
|
(61)
|
|
(92)
|
|
(541)
|
|
(1,081)
|
|
(1,396)
|
Free Cash
Flow
|
|
$
15,262
|
|
$
6,577
|
|
$
2,529
|
|
$
41,285
|
|
$
12,413
|
PV-10: PV-10 is derived from the standardized
measure of discounted future net cash flows ("Standardized
Measure"), which is the most directly comparable financial measure
under GAAP. PV-10 is a computation of the Standardized Measure on a
pre-tax basis. PV-10 is equal to the Standardized Measure at the
applicable date, before deducting future income taxes, discounted
at an annual rate of 10%, determined in accordance with GAAP. We
believe that the presentation of PV-10 is relevant and useful to
investors because it presents the discounted future net cash flows
attributable to our estimated net proved reserves prior to taking
into account future corporate income taxes, and it is a useful
measure for evaluating the relative monetary significance of our
oil and natural gas properties. We believe that securities analysts
and rating agencies use PV-10 in similar ways. Further, investors
may utilize the measure as a basis for comparison of the relative
size and value of our estimated reserves to other companies. We use
this measure when assessing the potential return on investment
related to our oil and natural gas properties. PV-10, however, is
not a substitute for the Standardized Measure. Our PV-10 and the
Standardized Measure do not purport to present the fair value of
our estimated oil and natural gas reserves.
The following table provides a reconciliation of the
Standardized Measure to PV-10 of the Company's estimated total
proved reserves as of September 30,
2022 and December 31,
2021:
|
|
September 30,
2022
|
|
|
December 31,
2021
|
|
|
(Unaudited, In
thousands)
|
Standardized measures
of discounted future net cash flows
|
|
$
1,241,720
|
|
|
$
703,469
|
Future income taxes,
discounted at 10%
|
|
329,313
|
|
|
175,674
|
Present value of
estimated future net revenues (PV-10)
|
|
$
1,571,033
|
|
|
$
879,143
|
Adjustment using NYMEX
pricing (1)
|
|
(696,886)
|
|
|
(70,467)
|
PV-10 adjusted for
pricing
|
|
$
874,147
|
|
|
$
808,676
|
______________________
(1)
|
Adjustment to reflect
the difference between SEC pricing used to calculate Standardized
Measure and PV-10 at NYMEX pricing.
|
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SOURCE Riley Exploration Permian, Inc.