All financial information contained within this news release
has been prepared in accordance with U.S. GAAP. This news release
includes forward-looking statements and information within the
meaning of applicable securities laws. Readers are advised to
review the "Forward-Looking Information and Statements" at the
conclusion of this news release. Readers are also referred to
"Notice Regarding Information Contained in this News
Release", "Non-GAAP and Other Financial Measures" in Enerplus'
first quarter 2022 MD&A for supplementary financial measures,
which information is incorporated by reference to this new release,
and "Non-GAAP and Other Financial Measures" at the end of this news
release for information regarding the presentation of the financial
and operational information in this news release, as well as the
use of certain financial measures that do not have standard meaning
under U.S. GAAP. A copy of Enerplus' first quarter 2022 and annual
2021 Financial Statements and associated MD&A are or will be
available on our website at www.enerplus.com, under our profile on
SEDAR at www.sedar.com and on the EDGAR website at www.sec.gov. All
amounts in this news release are stated in United States dollars unless otherwise
specified.
CALGARY, AB, May 5, 2022 /CNW/ - Enerplus Corporation
("Enerplus" or the "Company") (TSX: ERF) (NYSE: ERF) today
announced financial and operating results for the first quarter of
2022, along with an increase to its return of capital plans, and
updated guidance. The Company reported first quarter 2022 cash flow
from operating activities and adjusted funds flow(1) of
$196.0 million and $261.9 million, respectively, compared to
$28.7 million and $100.9 million, respectively, in the first
quarter of 2021. Cash flow from operating activities and adjusted
funds flow increased from the prior year period primarily due to
improved realized commodity prices and higher production.
HIGHLIGHTS
- Adjusted funds flow(1) was $262 million in the first quarter, which exceeded
capital spending of $99 million,
generating free cash flow(1) of $163 million
- Estimated 2022 free cash flow(1) is $675 million based on rest of year prices of
$85 WTI and $5.00 NYMEX
- Increasing total 2022 cash returns to shareholders to a minimum
of $350 million or 50% of annual free
cash flow, whichever is greater, through dividends and share
repurchases
- Increased quarterly dividend by 30% to $0.043 per share
- Production guidance for 2022 increased to 96,000 – 101,000 BOE
per day (from 95,500 – 100,500 BOE per day) due to strong
operational execution and optimizations
- Capital spending guidance for 2022 revised to $400 – $440 million
(from $370 – $430 million) primarily due to inflationary
impacts
- Realized 2022 Bakken oil price expected to be at par with
WTI
(1) This is a non-GAAP financial
measure. Refer to "Non-GAAP and Other Financial Measures" section
for more information.
|
"Our strong operating performance year to date is
continuing to support a robust production outlook," said
Ian C. Dundas, President and CEO.
"Enerplus remains well positioned to execute its 2022 plan which is
expected to deliver record free cash flow and meaningful cash
returns to shareholders."
"In conjunction with this outlook, we are enhancing our 2022
return of capital plan by committing to a minimum of $350 million or 50% of free cash flow, whichever
is greater, returned to shareholders through dividends and share
repurchases."
Dundas continued, "High commodity prices and supply chain
tightness are creating inflationary pressures across the industry.
We are not immune to these pressures. However, actions we took last
year to secure services, equipment and supplies have significantly
mitigated the impacts and are enabling us to execute our operating
plan efficiently, with no plans to increase activity levels or
chase higher, less efficient growth.
FIRST QUARTER SUMMARY
Production in the first quarter of 2022 was 92,196 BOE per day,
an increase of 25% compared to the same period a year ago, and 10%
lower than the prior quarter. Crude oil and natural gas
liquids production in the first quarter of 2022 was 56,011 barrels
per day, an increase of 42% compared to the same period a year ago,
and 14% lower than the prior quarter. The higher production
compared to the same period in 2021 was primarily due to the
Company's 2021 Bakken acquisitions and development program. The
lower production compared to the prior quarter was due to the
planned sequencing of the Company's completions program in
North Dakota which included a
break in onstream activity between early November 2021 through late March 2022, and the divestment of Montana and Russian Creek interests in the
fourth quarter of 2021.
Enerplus reported first quarter 2022 net income of $33.2 million, or $0.13 per share (diluted), compared to net income
of $10.3 million, or $0.04 per share (diluted), in the same period in
2021. Adjusted net income(1) for the first quarter of
2022 was $145.8 million, or
$0.58 per share (diluted), compared
to $43.9 million, or $0.18 per share (diluted), during the same period
in 2021. Net income and adjusted net income were higher compared to
the prior year period primarily due to higher production and
benchmark commodity prices and stronger commodity price
realizations during the first quarter of 2022.
Enerplus' first quarter 2022 realized Bakken oil price
differential was $0.35 per barrel
below WTI, compared to $3.19 per
barrel below WTI in the first quarter of 2021. The improved
year-over-year Bakken differential was due to an improvement in the
supply and demand balance, excess pipeline capacity in the region,
and strong prices for crude oil delivered to the U.S. Gulf Coast.
Given the constructive outlook for Bakken crude oil prices and
strong realizations year to date, Enerplus expects its 2022
realized Bakken oil price to be at par with WTI, compared to
$0.50 per barrel below WTI
previously.
The Company's realized Marcellus natural gas price differential
was $0.01 per Mcf above NYMEX during
the first quarter of 2022, compared to $0.15 per Mcf below NYMEX in the first quarter of
2021. Realized Marcellus differentials are expected to widen for
the remainder of the year due to the seasonal impact on natural gas
prices in the region. As a result, Enerplus' full-year 2022
Marcellus differential guidance is unchanged at $0.75 per Mcf below NYMEX.
In the first quarter of 2022, Enerplus' operating costs were
$10.03 per BOE, compared to
$7.71 per BOE during the first
quarter of 2021. The increase in per unit operating expenses was
due to the Company's higher crude oil weighting in its production
mix, contracts with price escalators linked to WTI and the Consumer
Price Index, and increased well service activity.
Capital spending totaled $99.0
million in the first quarter of 2022. The Company paid
$7.9 million in dividends in the
quarter and repurchased 3.1 million shares at an average price of
$11.87 per share, for total
consideration of $37.2 million.
Subsequent to March 31, 2022, and up
to and including May 4, 2022,
Enerplus repurchased 1.5 million shares at an average price of
$12.61 per share, for total
consideration of $18.9 million.
Enerplus ended the first quarter of 2022 with total debt of
$595.0 million and cash of
$22.7 million.
(1) This is a non-GAAP financial
measure. Refer to "Non-GAAP and Other Financial Measures" section
for more information.
|
ASSET HIGHLIGHTS
Williston Basin production
averaged 57,343 BOE per day during the first quarter of 2022, an
increase of 51% compared to the same period a year ago, driven by
Enerplus' 2021 acquisitions and ongoing development. Williston Basin production was 15% lower than
the prior quarter due to the planned sequencing of the Company's
completions program which included a break in onstream activity
between early November 2021 through
late March 2022, and the divestment
of Montana and Russian Creek
interests in the fourth quarter of 2021. The Company brought two
operated wells (100% working interest) on production from a
six-well pad at the end of March
2022. The remaining four wells were brought on production
subsequent to the quarter-end. Enerplus drilled 14 gross operated
wells (12 net) during the first quarter and is continuing to
operate two drilling rigs. The second quarter is expected to be
Enerplus' most active operational quarter in 2022 with
approximately 18 – 21 net wells projected to be brought on
production.
Marcellus production averaged 162 MMcf per day during the first
quarter of 2022, approximately flat compared to the same period in
2021 and the prior quarter. Canadian waterflood production averaged
5,495 BOE per day during the first quarter of 2022, approximately
flat compared to the same period in 2021, and 4% lower than the
prior quarter.
INCREASING RETURN OF CAPITAL TO SHAREHOLDERS
Assuming commodity prices of $85
per barrel WTI and $5.00 per Mcf
NYMEX for the rest of 2022, Enerplus expects to generate
approximately $675 million of annual
free cash flow(1), representing a reinvestment
rate(1) of less than 40%. Enerplus remains committed to
both returning a significant portion of free cash flow to
shareholders and reducing debt.
Enerplus' board of directors has approved an increase to the
Company's 2022 return of capital plan to a minimum of $350 million or 50% of annual free cash flow,
whichever is greater, through dividends and share repurchases.
In connection with this plan, the board has approved a 30%
increase to the Company's quarterly dividend to $0.043 per share payable on June 15, 2022 to shareholders of record on
May 27, 2022. The increased dividend
is equal to approximately $40 million
on an annualized basis.
The remaining $310 million or
greater of shareholder returns in 2022 are expected to be delivered
via the Company's share repurchase program, based on current market
conditions. Enerplus plans to repurchase its remaining 8.0 million
share authorization under its normal course issuer bid ("NCIB") by
the end of July 2022 and renew its
NCIB in August 2022 for approximately
10% of the outstanding shares.
Enerplus' approach to share repurchases continues to be grounded
in its assessment that its intrinsic value, based on its mid-cycle
commodity price view, is not adequately reflected in its current
trading value. If this view changes such that Enerplus believes
share repurchases no longer represent an attractive capital
allocation opportunity, the Company will distribute the capital to
shareholders through dividends to ensure it meets its shareholder
returns commitment.
The remaining 50% of 2022 free cash flow not allocated to
shareholder returns is expected to be directed to reinforcing the
balance sheet.
(1) This is a non-GAAP financial
measure. Refer to "Non-GAAP and Other Financial Measures" section
for more information.
|
2022 GUIDANCE UPDATE
Enerplus is revising its capital spending guidance to
$400 to $440
million, from $370 to
$430 million previously. The updated
guidance is a result of inflationary pressures due to the high
commodity price environment and supply chain tightness, along with
increased non-operated activity and associated costs. On its
operated activity in North Dakota,
Enerplus currently projects 2022 wells costs will average
approximately $6.5 million compared
to its initial budget of $6.0
million, with the increase primarily due to higher diesel
and steel costs.
In April, severe winter weather in North Dakota temporarily impacted Enerplus'
operations. The Company estimates that it lost approximately 1,000
BOE per day of annual average 2022 production due to the storm
impacts. However, through strong operational execution and the
continued optimization of the Company's development plan, Enerplus
has more than offset the impact from weather-related downtime to
its annual production forecast. As a result, Enerplus is increasing
its guidance to 96,000 to 101,000 BOE per day, compared to 95,500
to 100,500 BOE per day previously. Liquids production guidance has
been increased to 58,500 to 62,500 barrels per day, compared to
58,000 to 62,000 barrels per day previously.
Given the constructive outlook for Bakken crude oil prices and
strong realizations year to date, Enerplus expects its 2022
realized Bakken oil price to be at par with WTI, compared to
$0.50 per barrel below WTI
previously.
Due to additional costs incurred to restore production following
weather-related downtime, Enerplus is increasing the lower end of
its operating cost guidance to $9.75
per BOE, from $9.50 per BOE
previously.
As a result of the higher commodity price environment, Enerplus
is updating its current tax guidance from $10 million to $20
to $30 million (2% – 3% of adjusted
funds flow before tax) for 2022 assuming WTI of $85.00 per barrel and NYMEX of $5.00 per Mcf.
2022 Guidance Summary
|
Updated
Guidance
|
Previous
Guidance
|
Capital
spending
|
$400
– 440
million
|
$370 – 430
million
|
Average total
production
|
96,000 – 101,000
BOE/day
|
95,500 – 100,500
BOE/day
|
Average liquids
production
|
58,500 – 62,500
bbls/day
|
58,000 – 62,000
bbls/day
|
Average production tax
rate
(% of net sales, before
transportation)
|
7%
|
7%
|
Operating
expense
|
$9.75 –
10.50/BOE
|
$9.50 –
10.50/BOE
|
Transportation
expense
|
$4.15/BOE
|
$4.15/BOE
|
Cash G&A
expense
|
$1.25/BOE
|
$1.25/BOE
|
Current tax
expense
|
$20 – $30
million
(2-3% of adjusted funds
flow before tax)
|
$10 million
|
2022 Differential/Basis Outlook(1)
|
Updated
Guidance
|
Previous
Guidance
|
U.S. Bakken crude oil
differential
(compared to WTI crude
oil)
|
$0/bbl
|
$(0.50)/bbl
|
Marcellus natural gas
sales price differential
(compared to NYMEX
natural gas)
|
$(0.75)/Mcf
|
$(0.75)/Mcf
|
(1) Excluding transportation
costs.
|
Q1 2022 Conference Call Details
A conference call hosted by Ian C.
Dundas, President and CEO will be held at 9:00 AM MT (11:00 AM
ET) on May 6, 2022 to discuss
these results. Details of the conference call are as follows:
Date:
|
Friday, May 6,
2022
|
Time:
|
9:00 AM MT (11:00 AM
ET)
|
Dial-In:
|
587-880-2171
(Alberta)
|
|
1-888-390-0546 (Toll
Free)
|
Conference
ID:
|
14832308
|
Audiocast:
|
https://produceredition.webcasts.com/starthere.jsp?ei=1542034&tp_key=861128c0b5
|
To ensure timely participation in the conference call, callers
are encouraged to join 15 minutes prior to the start time to
register for the event. A telephone replay will be available for 30
days following the conference call and can be accessed at the
following numbers:
Replay
Dial-In:
|
1-888-390-0541
(Toll Free)
|
Replay
Passcode:
|
832308 #
|
PRICE RISK MANAGEMENT
The following is a summary of Enerplus' financial commodity
hedging contracts at May 4, 2022.
|
|
|
|
|
|
|
|
|
|
|
|
|
WTI Crude Oil
($/bbl)(1)(2)(3)
|
|
NYMEX Natural
Gas
($/Mcf)(2)
|
|
|
Apr 1,
2022 –
|
|
Apr 1,
2022 –
|
|
Jan 1,
2023 –
|
|
Jan 1,
2023 –
|
|
Apr 1, 2022 –
|
|
|
June 30,
2022
|
|
Dec 31,
2022
|
|
June 30,
2023
|
|
Dec 31,
2023
|
|
Oct
31, 2022
|
Swaps
|
|
|
|
|
|
|
|
|
|
|
Volume
(Mcf/day)
|
|
–
|
|
–
|
|
–
|
|
–
|
|
40,000
|
Sold Puts
|
|
–
|
|
–
|
|
–
|
|
–
|
|
$ 3.40
|
|
|
|
|
|
|
|
|
|
|
|
Collars
|
|
|
|
|
|
|
|
|
|
|
Volume
(Mcf/day)
|
|
–
|
|
–
|
|
–
|
|
–
|
|
60,000
|
Volume
(bbls/day)
|
|
12,500
|
|
17,000
|
|
10,000
|
|
2,000
|
|
–
|
Sold Puts
|
|
$ 58.00
|
|
$ 40.00
|
|
$ 60.00
|
|
–
|
|
–
|
Purchased
Puts
|
|
$ 75.00
|
|
$ 50.00
|
|
$ 76.50
|
|
$ 5.00
|
|
$ 3.77
|
Sold Calls
|
|
$ 87.63
|
|
$ 57.91
|
|
$ 107.38
|
|
$ 75.00
|
|
$ 4.50
|
(1) The total average
deferred premium spent on outstanding hedges is $1.50/bbl from
April 1, 2022 - December 31, 2022 and $1.25/bbl from January 1,
2023 – June 30, 2023.
(2) Transactions with a common term have
been aggregated and presented at weighted average prices and
volumes.
(3) Upon closing of the Bruin acquisition,
Bruin's outstanding crude oil contracts were recorded at a fair
value liability of $76.4 million. At March 31, 2022, the balance
was a liability of $16.3 million on the Condensed Consolidated
Balance Sheets. Realized and unrealized gains and losses on the
acquired contracts are recognized in Condensed Consolidated
Statement of Income/(Loss) and the Condensed Consolidated Balance
Sheets to reflect changes in crude oil prices from the date of
closing of the Bruin Acquisition. See Note 16 to the Interim
Financial Statements for further details.
|
FIRST QUARTER 2022 PRODUCTION AND OPERATIONAL SUMMARY
TABLES
Summary of Average Daily Production(1)
|
Three months ended
March 31, 2022
|
|
Williston
Basin
|
Marcellus
|
Canadian
Waterfloods
|
Other(2)
|
Total
|
Tight oil
(bbl/d)
|
41,554
|
-
|
-
|
874
|
42,428
|
Light & medium oil
(bbl/d)
|
-
|
-
|
2,150
|
22
|
2,172
|
Heavy oil
(bbl/d)
|
-
|
-
|
3,027
|
7
|
3,034
|
Total crude oil
(bbl/d)
|
41,554
|
-
|
5,177
|
903
|
47,634
|
|
|
|
|
|
|
Natural gas liquids
(bbl/d)
|
7,979
|
-
|
88
|
310
|
8,377
|
|
|
|
|
|
|
Shale gas
(Mcf/d)
|
46,858
|
162,138
|
-
|
922
|
209,918
|
Conventional natural
gas (Mcf/d)
|
-
|
-
|
1,380
|
5,813
|
7,193
|
Total natural gas
(Mcf/d)
|
46,858
|
162,138
|
1,380
|
6,735
|
217,111
|
|
|
|
|
|
|
Total production
(BOE/d)
|
57,343
|
27,023
|
5,495
|
2,335
|
92,196
|
(1) Table
may not add due to rounding.
(2) Comprises DJ Basin and other properties in
Canada.
|
Summary of Wells Drilled(1)
|
Three months ended
March 31, 2022
|
|
Operated
|
Non-Operated
|
|
Gross
|
Net
|
Gross
|
Net
|
Williston
Basin
|
14
|
12.0
|
12
|
1.5
|
Marcellus
|
-
|
-
|
16
|
1.4
|
Canadian
Waterfloods
|
-
|
-
|
-
|
-
|
Other(2)
|
-
|
-
|
-
|
-
|
Total
|
14
|
12.0
|
28
|
2.9
|
(1) Table may not add due to
rounding.
(2) Comprises DJ Basin and other properties
in Canada.
|
Summary of Wells Brought On-Stream(1)
|
Three months ended
March 31, 2022
|
|
Operated
|
Non-Operated
|
|
Gross
|
Net
|
Gross
|
Net
|
Williston
Basin
|
2
|
2.0
|
-
|
-
|
Marcellus
|
-
|
-
|
25
|
1.5
|
Canadian
Waterfloods
|
-
|
-
|
-
|
-
|
Other(2)
|
-
|
-
|
-
|
-
|
Total
|
2
|
2.0
|
25
|
1.5
|
(1) Table may not add due to
rounding.
(2) Comprises DJ Basin and other properties
in Canada.
|
|
|
|
|
|
|
|
SELECTED FINANCIAL
RESULTS
|
|
Three months
ended
March 31,
|
|
|
2022
|
|
2021
|
Financial (US$,
thousands, except ratios)
|
|
|
|
|
|
|
Net
Income/(Loss)
|
|
$
|
33,243
|
|
$
|
10,349
|
Adjusted Net
Income/(Loss)(1)
|
|
|
145,828
|
|
|
43,871
|
Cash Flow from
Operating Activities
|
|
|
195,992
|
|
|
28,662
|
Adjusted Funds
Flow(1)
|
|
|
261,895
|
|
|
100,854
|
Dividends to
Shareholders - Declared
|
|
|
7,918
|
|
|
5,634
|
Net Debt
|
|
|
572,271
|
|
|
632,200
|
Capital
Spending
|
|
|
99,013
|
|
|
51,818
|
Property and Land
Acquisitions
|
|
|
1,941
|
|
|
497,139
|
Property
Divestments
|
|
|
6,581
|
|
|
4,010
|
Net Debt to Adjusted
Funds Flow Ratio(1)
|
|
|
0.7x
|
|
|
2.2x
|
|
|
|
|
|
|
|
Financial per
Weighted Average Shares Outstanding
|
|
|
|
|
|
|
Net Income /(Loss) -
Basic
|
|
$
|
0.14
|
|
$
|
0.04
|
Net Income/(Loss) -
Diluted
|
|
|
0.13
|
|
|
0.04
|
Weighted Average Number
of Shares Outstanding (000's) - Basic
|
|
|
242,787
|
|
|
244,066
|
Weighted Average Number
of Shares Outstanding (000's) - Diluted
|
|
|
249,337
|
|
|
246,898
|
|
|
|
|
|
|
|
Selected Financial
Results per BOE(2)(3)
|
|
|
|
|
|
|
Crude Oil & Natural
Gas Sales(4)
|
|
$
|
61.84
|
|
$
|
34.43
|
Commodity Derivative
Instruments
|
|
|
(8.81)
|
|
|
(2.32)
|
Operating
Expenses
|
|
|
(10.03)
|
|
|
(7.71)
|
Transportation
Costs
|
|
|
(4.32)
|
|
|
(3.91)
|
Production
Taxes
|
|
|
(4.26)
|
|
|
(2.09)
|
General and
Administrative Expenses
|
|
|
(1.35)
|
|
|
(1.57)
|
Cash Share-Based
Compensation
|
|
|
(0.25)
|
|
|
(0.32)
|
Interest, Foreign
Exchange and Other Expenses
|
|
|
(0.66)
|
|
|
(1.31)
|
Current Income Tax
Recovery/(Expense)
|
|
|
(0.60)
|
|
|
—
|
Adjusted Funds
Flow(1)
|
|
$
|
31.56
|
|
$
|
15.20
|
|
|
|
|
|
|
|
SELECTED OPERATING
RESULTS
|
|
Three months
ended
March 31,
|
|
|
2022
|
|
2021
|
Average Daily
Production(3)
|
|
|
|
|
|
|
Crude Oil
(bbls/day)
|
|
|
47,634
|
|
|
34,112
|
Natural Gas Liquids
(bbls/day)
|
|
|
8,377
|
|
|
5,270
|
Natural Gas
(Mcf/day)
|
|
|
217,111
|
|
|
205,949
|
Total
(BOE/day)
|
|
|
92,196
|
|
|
73,707
|
|
|
|
|
|
|
|
% Crude Oil and Natural
Gas Liquids
|
|
|
61%
|
|
|
53%
|
|
|
|
|
|
|
|
Average Selling
Price(3)(4)
|
|
|
|
|
|
|
Crude Oil (per
bbl)
|
|
$
|
91.95
|
|
$
|
53.24
|
Natural Gas Liquids
(per bbl)
|
|
|
37.78
|
|
|
28.55
|
Natural Gas (per
Mcf)
|
|
|
4.62
|
|
|
2.76
|
|
|
|
|
|
|
|
Net Wells
Drilled
|
|
|
15
|
|
|
1
|
(1)
These non‑GAAP measures may not be directly comparable to similar
measures presented by other entities See "Non-GAAP and Other
Financial
Measures" section in this news
release.
(2) Non‑cash amounts have been excluded.
(3) Based on net production volumes. See "Basis
of Presentation" section in this news release.
(4) Before transportation costs and commodity
derivative instruments.
|
Condensed Consolidated Balance Sheets
|
|
|
|
|
|
|
(US$ thousands) unaudited
|
|
March 31, 2022
|
|
December 31, 2021
|
Assets
|
|
|
|
|
|
|
Current
assets
|
|
|
|
|
|
|
Cash and cash
equivalents
|
|
$
|
22,731
|
|
$
|
61,348
|
Accounts
receivable
|
|
|
282,644
|
|
|
227,988
|
Other current
assets
|
|
|
9,118
|
|
|
10,956
|
Derivative financial
assets
|
|
|
—
|
|
|
5,668
|
|
|
|
314,493
|
|
|
305,960
|
Property, plant and
equipment:
|
|
|
|
|
|
|
Crude oil and natural
gas properties (full cost method)
|
|
|
1,303,239
|
|
|
1,253,505
|
Other capital
assets
|
|
|
13,234
|
|
|
13,887
|
Property, plant and
equipment
|
|
|
1,316,473
|
|
|
1,267,392
|
Other long-term
assets
|
|
|
7,526
|
|
|
9,756
|
Right-of-use
assets
|
|
|
24,492
|
|
|
26,118
|
Deferred income tax
asset
|
|
|
374,238
|
|
|
380,858
|
Total
Assets
|
|
$
|
2,037,222
|
|
$
|
1,990,084
|
|
|
|
|
|
|
|
Liabilities
|
|
|
|
|
|
|
Current
liabilities
|
|
|
|
|
|
|
Accounts
payable
|
|
$
|
404,192
|
|
$
|
367,008
|
Current portion of
long-term debt
|
|
|
100,600
|
|
|
100,600
|
Derivative financial
liabilities
|
|
|
257,038
|
|
|
143,200
|
Current portion of
lease liabilities
|
|
|
10,852
|
|
|
10,618
|
|
|
|
772,682
|
|
|
621,426
|
|
|
|
|
|
|
|
Long-term
debt
|
|
|
494,402
|
|
|
601,171
|
Asset retirement
obligation
|
|
|
144,591
|
|
|
132,814
|
Derivative financial
liabilities
|
|
|
13,866
|
|
|
7,098
|
Lease
liabilities
|
|
|
16,310
|
|
|
18,265
|
|
|
|
669,169
|
|
|
759,348
|
Total
Liabilities
|
|
|
1,441,851
|
|
|
1,380,774
|
|
|
|
|
|
|
|
Shareholders'
Equity
|
|
|
|
|
|
|
Share capital –
authorized unlimited common shares, no par value
Issued and outstanding:
March 31, 2022 – 242 million shares
December 31, 2021 – 244 million shares
|
|
|
3,070,678
|
|
|
3,094,061
|
Paid-in
capital
|
|
|
36,110
|
|
|
50,881
|
Accumulated
deficit
|
|
|
(2,218,865)
|
|
|
(2,238,325)
|
Accumulated other
comprehensive loss
|
|
|
(292,552)
|
|
|
(297,307)
|
|
|
|
595,371
|
|
|
609,310
|
Total Liabilities
& Shareholders' Equity
|
|
$
|
2,037,222
|
|
$
|
1,990,084
|
|
|
|
|
|
|
|
Condensed Consolidated Statements of Income/(Loss) and
Comprehensive Income/(Loss)
|
|
|
|
|
|
|
|
|
Three months
ended
|
|
|
March 31,
|
(US$ thousands,
except per share amounts) unaudited
|
|
2022
|
|
2021
|
Revenues
|
|
|
|
|
|
|
Crude oil and natural
gas sales
|
|
$
|
513,152
|
|
$
|
228,390
|
Commodity derivative
instruments loss
|
|
|
(206,810)
|
|
|
(56,263)
|
|
|
|
306,342
|
|
|
172,127
|
Expenses
|
|
|
|
|
|
|
Operating
|
|
|
83,244
|
|
|
51,162
|
Transportation
|
|
|
35,807
|
|
|
25,927
|
Production
taxes
|
|
|
35,355
|
|
|
13,845
|
General and
administrative
|
|
|
17,581
|
|
|
12,841
|
Depletion, depreciation
and accretion
|
|
|
66,691
|
|
|
36,698
|
Asset
impairment
|
|
|
—
|
|
|
3,420
|
Interest
|
|
|
6,055
|
|
|
5,633
|
Foreign exchange
(gain)/loss
|
|
|
887
|
|
|
(24)
|
Transaction costs and
other expense/(income)
|
|
|
12,697
|
|
|
3,619
|
|
|
|
258,317
|
|
|
153,121
|
Income/(Loss) before
taxes
|
|
|
48,025
|
|
|
19,006
|
Current income tax
expense
|
|
|
5,000
|
|
|
—
|
Deferred income tax
expense/(recovery)
|
|
|
9,782
|
|
|
8,657
|
Net
Income/(Loss)
|
|
$
|
33,243
|
|
$
|
10,349
|
|
|
|
|
|
|
|
Other Comprehensive
Income/(Loss)
|
|
|
|
|
|
|
Unrealized gain/(loss)
on foreign currency translation
|
|
|
(620)
|
|
|
(807)
|
Foreign exchange
gain/(loss) on net investment hedge, net of tax
|
|
|
5,375
|
|
|
5,714
|
Total Comprehensive
Income/(Loss)
|
|
$
|
37,998
|
|
$
|
15,256
|
|
|
|
|
|
|
|
Net Income/(Loss)
per share
|
|
|
|
|
|
|
Basic
|
|
$
|
0.14
|
|
$
|
0.04
|
Diluted
|
|
$
|
0.13
|
|
$
|
0.04
|
Condensed Consolidated Statements of Cash Flows
|
|
|
|
|
|
|
|
|
Three months
ended
|
|
|
March 31,
|
(US$ thousands) unaudited
|
|
2022
|
|
2021
|
Operating
Activities
|
|
|
|
|
|
|
Net
income/(loss)
|
|
$
|
33,243
|
|
$
|
10,349
|
Non-cash items
add/(deduct):
|
|
|
|
|
|
|
Depletion, depreciation
and accretion
|
|
|
66,691
|
|
|
36,698
|
Asset
impairment
|
|
|
—
|
|
|
3,420
|
Changes in fair value
of derivative instruments
|
|
|
133,332
|
|
|
40,358
|
Deferred income tax
expense/(recovery)
|
|
|
9,782
|
|
|
8,657
|
Foreign exchange
(gain)/loss on debt and working capital
|
|
|
1,171
|
|
|
157
|
Share-based
compensation and general and administrative
|
|
|
4,660
|
|
|
802
|
Other
expense
|
|
|
12,653
|
|
|
—
|
Amortization of debt
issuance costs
|
|
|
353
|
|
|
57
|
Translation of U.S.
dollar cash held in parent company
|
|
|
10
|
|
|
356
|
Asset retirement
obligation settlements
|
|
|
(8,795)
|
|
|
(5,625)
|
Changes in non-cash
operating working capital
|
|
|
(57,108)
|
|
|
(66,567)
|
Cash flow from/(used
in) operating activities
|
|
|
195,992
|
|
|
28,662
|
|
|
|
|
|
|
|
Financing
Activities
|
|
|
|
|
|
|
Proceeds
from/(repayment of) bank credit facilities
|
|
|
(104,409)
|
|
|
400,000
|
Debt issuance
costs
|
|
|
—
|
|
|
(2,834)
|
Proceeds from the
issuance of shares
|
|
|
—
|
|
|
98,339
|
Purchase of common
shares under Normal Course Issuer Bid
|
|
|
(37,207)
|
|
|
—
|
Share-based
compensation – tax withholdings settled in cash
|
|
|
(11,567)
|
|
|
(3,551)
|
Dividends
|
|
|
(7,918)
|
|
|
(5,337)
|
Cash flow from/(used
in) financing activities
|
|
|
(161,101)
|
|
|
486,617
|
|
|
|
|
|
|
|
Investing
Activities
|
|
|
|
|
|
|
Capital and office
expenditures
|
|
|
(75,027)
|
|
|
(40,345)
|
Bruin
acquisition
|
|
|
—
|
|
|
(418,241)
|
Property and land
acquisitions
|
|
|
(1,941)
|
|
|
(2,471)
|
Property
divestments
|
|
|
6,581
|
|
|
4,010
|
Cash flow from/(used
in) investing activities
|
|
|
(70,387)
|
|
|
(457,047)
|
Effect of exchange rate
changes on cash & cash equivalents
|
|
|
(3,121)
|
|
|
2,289
|
Change in cash and cash
equivalents
|
|
|
(38,617)
|
|
|
60,521
|
Cash and cash
equivalents, beginning of period
|
|
|
61,348
|
|
|
89,945
|
Cash and cash
equivalents, end of period
|
|
$
|
22,731
|
|
$
|
150,466
|
About Enerplus
Enerplus is an independent North American oil and gas
exploration and production company focused on creating long-term
value for its shareholders through a disciplined, returns-based
capital allocation strategy and a commitment to safe, responsible
operations. For more information, visit the Company's website at
www.enerplus.com.
Follow @EnerplusCorp on Twitter at
https://twitter.com/EnerplusCorp.
NOTICE REGARDING INFORMATION CONTAINED IN THIS NEWS
RELEASE
Currency and Accounting Principles
All amounts in this news release are stated in U.S. dollars
unless otherwise specified. All financial information in this news
release has been prepared and presented in accordance with U.S.
GAAP, except as noted below under "Non-GAAP and Other Financial
Measures".
Barrels of Oil Equivalent
This news release contains references to "BOE" (barrels of
oil equivalent), "MBOE" (one thousand barrels of oil equivalent),
and "MMBOE" (one million barrels of oil equivalent). Enerplus has
adopted the standard of six thousand cubic feet of gas to one
barrel of oil (6 Mcf: 1 bbl) when converting natural gas to
BOEs. BOE, MBOE and MMBOE may be misleading, particularly if
used in isolation. The foregoing conversion ratios are based
on an energy equivalency conversion method primarily applicable at
the burner tip and do not represent a value equivalency at the
wellhead. Given that the value ratio based on the current price of
oil as compared to natural gas is significantly different from the
energy equivalent of 6:1, utilizing a conversion on a 6:1 basis may
be misleading.
Basis of Presentation
All production volumes presented in this news release are
reported on a "net" basis (the Company's working interest share
after deduction of royalty obligations, plus the Company's royalty
interests), unless expressly indicated that it is being presented
on a "gross" basis. Previously, the Company presented production
volumes on a "company interest" basis, which was calculated as its
working interest share before deduction of royalties plus the
Company's royalty interests. With these changes, production volumes
presented by the Company on a "net" basis are expected to be lower
than those presented historically.
All references to "liquids" in this news release include
light and medium crude oil, heavy oil and tight oil (all together
referred to as "crude oil") and NGLs on a combined basis. All
references to "natural gas" in this news release include
conventional natural gas and shale gas on a combined basis.
Readers are urged to review the 2021 Management's Discussion
& Analysis and financial statements filed on SEDAR and as part
of our Form 40-F on EDGAR concurrently with this news release for
more complete disclosure on our operations.
FORWARD-LOOKING INFORMATION AND STATEMENTS
This news release contains certain forward-looking
information and statements ("forward-looking information") within
the meaning of applicable securities laws. The use of any of the
words "expect", "anticipate", "continue", "estimate", "guidance",
"ongoing", "may", "will", "project", "plans", "budget", "strategy"
and similar expressions are intended to identify forward-looking
information. In particular, but without limiting the foregoing,
this news release contains forward-looking information pertaining
to the following: updated 2022 production and capital spending
guidance; expected capital spending levels in 2022; expectations
regarding 2022 and future shareholder returns, including payment of
dividends and Enerplus' share repurchase program, the timing and
amounts thereof and funding dividends and the share repurchase
program from free cash flow; expectations regarding free cash flow
generation and capital spending reinvestment rates; expected
operating strategy in 2022 and expectations regarding our drilling
program and well costs; 2022 average production volumes and the
anticipated production mix; the proportion of our anticipated oil
and gas production that is hedged and the expected effectiveness of
such hedges in protecting our cash flow from operating activities
and adjusted funds flow; oil and natural gas prices and
differentials and expectations regarding the market environment and
our commodity risk management program in 2022; updated and existing
2022 Bakken and Marcellus differential guidance; expectations
regarding realized oil and natural gas prices; expected operating,
transportation and cash G&A expenses and production taxes and
updated 2022 guidance with respect thereto; expectations regarding
net debt and debt reduction; expectations regarding increases to
dividends and timing thereof; and expectations regarding renewal of
our normal course issuer bid, including timing and size
thereof.
The forward-looking information contained in this news
release reflects several material factors and expectations and
assumptions of Enerplus including, without limitation: that we will
conduct our operations and achieve results of operations as
anticipated; the continued operation of the Dakota Access
Pipeline; that our development plans will achieve the expected
results; that lack of adequate infrastructure will not result in
curtailment of production and/or reduced realized prices beyond our
current expectations; current and anticipated commodity prices,
differentials and cost assumptions; the general continuance of
current or, where applicable, assumed industry conditions, the
impact of inflation, weather conditions, storage fundamentals and
expectations regarding the duration and overall impact of COVID-19;
the continuation of assumed tax, royalty and regulatory regimes;
the accuracy of the estimates of our reserve and contingent
resource volumes; the continued availability of adequate debt
and/or equity financing and adjusted funds flow to fund our
capital, operating and working capital requirements, and dividend
payments as needed; the ability to fund increased dividend payments
and the share purchase program from free cash flow as expected and
discussed in this news release; our ability to comply with our debt
covenants; the availability of third party services; expected
transportation expenses; the extent of our liabilities; and the
availability of technology and process to achieve environmental
targets. In addition, our 2022 guidance described in this news
release is based on: a WTI price of $85.00/bbl, a NYMEX price of $5.00/Mcf, a Bakken crude oil price at par with
WTI, a Marcellus natural gas price differential of $0.75/Mcf below NYMEX and a CDN/USD exchange rate
of 0.79. Enerplus believes the material factors, expectations and
assumptions reflected in the forward-looking information are
reasonable but no assurance can be given that these factors,
expectations and assumptions will prove to be correct. Current
conditions, economic and otherwise, render assumptions, although
reasonable when made, subject to greater uncertainty.
The forward-looking information included in this news release
is not a guarantee of future performance and should not be unduly
relied upon. Such information involves known and unknown risks,
uncertainties and other factors that may cause actual results or
events to differ materially from those anticipated in such
forward-looking information including, without limitation:
continued instability, or further deterioration, in global economic
and market environment, including from COVID-19, inflation and/or
the Ukraine/Russia conflict and heightened geopolitical
risks; decreases in commodity prices or volatility in commodity
prices; changes in realized prices of Enerplus' products from those
currently anticipated; changes in the demand for or supply of our
products; unanticipated operating results, results from our capital
spending activities or production declines; legal proceedings or
other events inhibiting or preventing operation of the Dakota
Access Pipeline; curtailment of our production due to low realized
prices or lack of adequate infrastructure; changes in tax or
environmental laws, royalty rates or other regulatory matters;
changes in our capital plans or by third party operators of our
properties; increased debt levels or debt service requirements;
inability to comply with debt covenants under our bank credit
facilities and/or outstanding senior notes; inaccurate estimation
of our oil and gas reserve and contingent resource volumes;
limited, unfavourable or a lack of access to capital markets;
increased costs; a lack of adequate insurance coverage; the impact
of competitors; reliance on industry partners and third party
service providers; changes in law or government programs or
policies in Canada or the United States; and certain other risks
detailed from time to time in our public disclosure documents
(including, without limitation, those risks identified in our first
quarter 2022 MD&A, our annual information form for the year
ended December 31, 2021, our 2021
annual MD&A and Form 40-F as at December
31, 2021).
The forward-looking information contained in this news
release speaks only as of the date of this news release. Enerplus
does not undertake any obligation to publicly update or revise any
forward-looking information contained herein, except as required by
applicable laws.
NON-GAAP AND OTHER FINANCIAL MEASURES
Non-GAAP Financial Measures
This news release includes references to certain non-GAAP
financial measures and non-GAAP ratios used by the Company to
evaluate its financial performance, financial position or cash
flow. Non-GAAP financial measures are financial measures disclosed
by a company that (a) depict historical or expected future
financial performance, financial position or cash flow of a
company, (b) with respect to their composition, exclude amounts
that are included in, or include amounts that are excluded from,
the composition of the most directly comparable financial measure
disclosed in the primary financial statements of the company, (c)
are not disclosed in the financial statements of the company and
(d) are not a ratio, fraction, percentage or similar
representation. Non-GAAP ratios are financial measures disclosed by
a company that are in the form of a ratio, fraction, percentage or
similar representation that has a non-GAAP financial measure as one
or more of its components, and that are not disclosed in the
financial statements of the company.
These non-GAAP financial measures and non-GAAP ratios do not
have standardized meanings or definitions as prescribed by
U.S. GAAP and may not be comparable with the calculation of
similar financial measures by other entities. For each
measure, we have indicated the composition of the measure,
identified the GAAP equivalency to the extent one exists, provided
comparative detail where appropriate, indicated the reconciliation
of the measure to the mostly directly comparable GAAP financial
measure and provided details on the usefulness of the measure for
the reader. These non-GAAP financial measures and non-GAAP ratios
should not be considered as a substitute for, or superior to,
measures of financial performance prepared in accordance with
GAAP.
"Adjusted funds flow" is used by Enerplus and is
useful to investors and securities analysts, in analyzing operating
and financial performance, leverage and liquidity. The most
directly comparable GAAP measure is cash flow from operating
activities. Adjusted funds flow is calculated as cash flow from
operating activities before asset retirement obligation
expenditures and changes in non‑cash operating working capital.
|
|
|
|
|
|
|
|
|
Three months ended
March 31,
|
(US$
millions)
|
|
2022
|
|
2021
|
Cash flow from/(used
in) operating activities
|
|
$
|
196.0
|
|
$
|
28.7
|
Asset retirement
obligation settlements
|
|
|
8.8
|
|
|
5.6
|
Changes in non-cash
operating working capital
|
|
|
57.1
|
|
|
66.6
|
Adjusted funds
flow
|
|
$
|
261.9
|
|
$
|
100.9
|
"Adjusted net income" is used by Enerplus and is
useful to investors and securities analysts in evaluating the
financial performance of the company by adjusting for certain
unrealized items and other items that the company considers
appropriate to adjust given their irregular nature. The most
directly comparable GAAP measure is net income/(loss). No income
tax rate adjustment on deferred taxes or goodwill impairment, or
valuation allowance on deferred taxes were recorded for the three
months ended March 31, 2022 and 2021.
The calculation follows:
|
|
|
|
|
|
|
|
|
|
Three months ended
March 31,
|
(US$ millions)
|
|
2022
|
|
2021
|
Net
income/(loss)
|
|
$
|
33.2
|
|
$
|
10.3
|
Unrealized non-cash
derivative instrument (gain)/loss
|
|
|
133.3
|
|
|
40.4
|
Asset
impairment
|
|
|
—
|
|
|
3.4
|
Other expense related
to investing activities
|
|
|
13.1
|
|
|
—
|
Unrealized non-cash
foreign exchange (gain)/loss
|
|
|
1.2
|
|
|
0.2
|
Tax effect on above
items
|
|
|
(35.0)
|
|
|
(10.4)
|
Adjusted net
income/(loss)
|
|
$
|
145.8
|
|
$
|
43.9
|
|
|
|
|
|
|
|
|
|
|
|
|
|
"Free cash flow" is used by Enerplus and is useful to
investors and securities analysts in analyzing operating and
financial performance, leverage and liquidity. Free cash flow is
calculated as adjusted funds flow minus capital spending. There is
no directly comparable related GAAP equivalent for this measure.
Adjusted funds flow is reconciled above.
|
|
|
|
|
|
|
Three months ended
March 31,
|
(US$ millions)
|
2022
|
|
2021
|
Adjusted funds
flow
|
$
|
261.9
|
|
$
|
100.9
|
Capital
spending
|
|
(99.0)
|
|
|
(51.8)
|
Free cash
flow
|
$
|
162.9
|
|
$
|
49.1
|
"Net debt to adjusted funds flow ratio" is used by
Enerplus and is useful to investors and securities analysts in
analyzing leverage and liquidity. The net debt to adjusted funds
flow ratio is calculated as net debt divided by a trailing
twelve months of adjusted funds flow. There is no directly
comparable GAAP equivalent for this measure, and it is not
equivalent to any of our debt covenants. The calculation
follows:
|
|
|
|
|
|
|
|
|
Three months ended
March 31,
|
|
(US$
millions)
|
|
2022
|
|
2021
|
|
Net debt
|
|
$
|
572.3
|
|
$
|
632.2
|
Trailing adjusted funds
flow
|
|
|
873.5
|
|
|
282.5
|
Net debt to adjusted
funds flow ratio
|
|
|
0.7x
|
|
|
2.2x
|
|
|
|
|
|
|
|
|
|
"Reinvestment rate" is used by Enerplus and is useful to
investors and securities analysts in analyzing the reinvestment of
capital spending by comparing the amount of our capitals spending
as compared to adjusted funds flow (as a percentage). There is no
directly comparable GAAP measure. The calculation follows:
|
|
|
|
|
|
|
|
|
Three months ended
March 31,
|
(US$
millions)
|
|
2022
|
|
2021
|
Capital
spending
|
|
$
|
99.0
|
|
$
|
51.8
|
Adjusted funds
flow
|
|
|
261.9
|
|
|
100.9
|
Reinvestment rate
(%)
|
|
|
38%
|
|
|
51%
|
Other Financial Measures
CAPITAL MANAGEMENT MEASURES
Capital management measures are financial measures disclosed by
a company that (a) are intended to enable an individual to evaluate
a company's objectives, policies and processes for managing the
company's capital, (b) are not a component of a line item disclosed
in the primary financial statements of the company, (c) are
disclosed in the notes to the financial statements of the company,
and (d) are not disclosed in the primary financial statements of
the company. The following section provides an explanation of the
composition of those capital management measures if not previously
provided:
"Net Debt" is calculated as current and long-term debt
associated with senior notes plus any outstanding bank credit
facilities balances, less cash and cash equivalents. "Net debt" is
useful to investors and securities analysts in analyzing financial
liquidity and Enerplus considers net debt to be a key measure of
capital management. For further details, see Note 8 to the Interim
Financial Statements.
Electronic copies of Enerplus' first quarter 2022 and annual
2021 Financial Statements and associated MD&As, along with
other public information including investor presentations, are or
will be available on the Company's website at www.enerplus.com. For
further information, please contact Investor Relations at
1-800-319-6462 or email investorrelations@enerplus.com.
SOURCE Enerplus Corporation