Enerplus Announces Fourth Quarter and Full Year 2023 Financial and Operating Results

News provided by

Enerplus Corporation

Feb 21, 2024, 17:38 ET

All financial information contained within this news release has been prepared in accordance with U.S. GAAP and is presented in U.S. dollars. This news release includes forward-looking statements and information within the meaning of applicable securities laws. Production information, unless otherwise stated, is presented on a net basis (after deduction of royalty obligations). 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" 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' 2023 Financial Statements and MD&A is available on our website at www.enerplus.com, under our profile on SEDAR+ at www.sedarplus.ca 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, Feb. 21, 2024 /CNW/ - Enerplus Corporation ("Enerplus" or the "Company") (TSX: ERF) (NYSE: ERF) today reported fourth quarter 2023 cash flow from operating activities and adjusted funds flow(1) of $297.9 million and $240.5 million, respectively, compared to $316.6 million and $315.4 million, respectively, in the fourth quarter of 2022. Full year 2023 cash flow from operating activities and adjusted funds flow(1) was $938.2 million and $961.2 million, respectively, compared to $1,173.4 million and $1,230.3 million, in 2022.

On February 21, 2024, Enerplus entered into an arrangement agreement with Chord Energy Corporation ("Chord"), pursuant to which, upon completion of the transaction, Enerplus shareholders will receive 0.10125 shares of Chord common stock and $1.84 in cash for each share of Enerplus (90% stock and 10% cash consideration). The transaction is subject to various approvals and conditions to close and is expected to be completed mid-2024. For more information refer to the joint press release of Enerplus and Chord regarding this transaction.

HIGHLIGHTS – FULL YEAR 2023

  • Exceeded 2023 total and liquids production guidance:
    • Total production averaged 100,015 BOE per day (guidance of 98,000 to 99,000 BOE per day).
    • Liquids production averaged 62,208 barrels per day (guidance of 60,500 to 61,500 barrels per day).
  • Generated adjusted funds flow(1) of $961.2 million in 2023, which exceeded capital spending of $532.5 million, generating free cash flow(1) of $428.7 million.
  • Returned $306.9 million to shareholders through dividends and share repurchases, representing 72% of 2023 free cash flow(1).
  • Reduced shares outstanding by 7% since year-end 2022 and 17% since year-end 2021.
  • Reduced net debt(1) by 46% from year-end 2022, ending 2023 with net debt(1) of $119.3 million.
  • Reduced 2023 methane emissions intensity by 45% and Scope 1 and Scope 2 greenhouse gas ("GHG") emissions intensity by 40%, compared to 2021, based on preliminary estimates.

"2023 marked another year of solid operational and financial performance, further demonstrating the quality of our team and North Dakota Bakken position," said Ian C. Dundas, President and CEO. "We exceeded production targets within a disciplined capital allocation framework, helping to drive free cash flow of over $400 million. Consistent with our track record, we returned significant cash to shareholders ­— over 70% of free cash flow in 2023 — through dividends and share repurchases, while also reducing net debt by 46%."

(1)

This is a non-GAAP financial measure. Refer to "Non-GAAP and Other Financial Measures" section for more information.

FOURTH QUARTER 2023 SUMMARY

Total production for the fourth quarter of 2023 was 103,543 BOE per day, a decrease of 3% compared to the same period in 2022. Liquids production in the fourth quarter was 67,097 barrels per day, an increase of 3% compared to the same period in 2022. Strong well performance in North Dakota supported fourth quarter 2023 liquids production, while lower activity levels in the Marcellus throughout 2023 and the impact from the sale of Canadian assets during the fourth quarter of 2022 led to the decrease in total production year-over-year. The Company's fourth quarter production exceeded the top end of the total and liquids production guidance ranges of 95,000 to 99,000 BOE per day and 60,500 to 64,500 barrels per day, respectively.

In North Dakota, Enerplus drilled 19 operated wells (79% average working interest) during the quarter, with no operated wells brought on production. North Dakota production averaged 78,222 BOE per day in the quarter. Marcellus production averaged 143 MMcf per day in the quarter.

Enerplus reported fourth quarter 2023 net income of $116.7 million, or $0.57 per share (basic), compared to net income of $330.7 million, or $1.49 per share (basic), in the fourth quarter of 2022. Excluding certain non-cash or non-recurring items, fourth quarter 2023 adjusted net income(1) was $115.3 million, or $0.56 per share (basic), compared to $181.1 million, or $0.81 per share (basic), during the same period in 2022. The reduction in net income was due to the gain on the sale of the Canadian assets recorded during the fourth quarter of 2022, as well as lower production and commodity prices, which also decreased adjusted net income, relative to the prior year period.

Enerplus' realized fourth quarter 2023 Bakken crude oil price differential was $1.26 per barrel below WTI, compared to $1.05 per barrel above WTI for the same period in 2022. Bakken crude oil prices were weaker than the prior year period due to elevated local production growth driven predominantly by an acceleration in well completion activity resulting in less spare pipeline capacity in 2023, while refinery demand deteriorated in the fourth quarter of 2023 due to a decline in global refinery margins. Enerplus' fourth quarter 2023 Marcellus natural gas price differential was $1.20 per Mcf below NYMEX, compared to $1.18 per Mcf below NYMEX for the same period in 2022.

Operating expenses in the fourth quarter of 2023 were $11.67 per BOE, compared to $9.68 per BOE in the same period in 2022. The increase in per unit operating expenses was primarily due to inflation adjusted contract pricing and higher gas facility and fluid handling charges due to the increase in North Dakota production. Cash general and administrative ("G&A") expenses were $1.41 per BOE in the fourth quarter of 2023, compared to $1.15 per BOE in the prior year period due to inflationary pressures on labour and services.

Capital spending totaled $91.5 million in the fourth quarter. The Company paid $12.2 million in dividends during the quarter and repurchased 5.8 million shares at an average price of $16.09 per share for a total cost of $93.8 million.

Current tax expense was $0.2 million in the fourth quarter.

Enerplus ended the fourth quarter with net debt(1) of $119.3 million and had a net debt to adjusted funds flow ratio(1) of 0.1 times.

(1)

This is a non-GAAP financial measure. Refer to "Non-GAAP and Other Financial Measures" section for more information.

FULL YEAR 2023 SUMMARY

Total production for 2023 was 100,015 BOE per day, broadly flat compared to 2022. Liquids production in 2023 was 62,208, an increase of 1% compared to 2022. Liquids production increased by 9% year-over-year when adjusted for the Canadian asset divestments completed in 2022. The Company's 2023 production exceeded the top end of the total and liquids production guidance ranges of 98,000 to 99,000 BOE per day and 60,500 to 61,500 barrels per day, respectively.

Enerplus reported full year 2023 net income of $456.1 million, or $2.16 per share (basic), compared to net income of $914.3 million, or $3.91 per share (basic), in 2022. Excluding certain non-cash or non-recurring items, 2023 adjusted net income(1) was $477.6 million, or $2.26 per share (basic), compared to $707.1 million, or $3.02 per share (basic), in 2022. The lower net income in 2023 was due to the gain on the sale of the Canadian assets recorded during 2022, as well as lower production and commodity prices, which also decreased adjusted net income, relative to the prior year period.

Enerplus' 2023 realized Bakken crude oil price differential was $0.45 per barrel below WTI, compared to $1.09 per barrel above WTI in 2022. Bakken differentials weakened through the second half of 2023 due to local production growth driven by an acceleration in well completion activity resulting in less spare pipeline capacity in 2023, while refinery demand deteriorated in the fourth quarter of 2023 due to a decline in global refinery margins. Enerplus' 2023 Marcellus natural gas price differential was $0.92 per Mcf below NYMEX, compared to $0.72 per Mcf below NYMEX in 2022.

Operating expenses in 2023 were $10.67 per BOE, compared to $9.99 per BOE in 2022. The increase in per BOE operating expenses was primarily due to inflation adjusted contract pricing and higher gas facility and fluid handling charges as a result of increased production in North Dakota. Cash G&A expenses in 2023 were $1.33 per BOE, compared to $1.17 per BOE in 2022 due to inflationary pressures on labour and services.

Current tax expense was $27.2 million in 2023.

Capital spending totaled $532.5 million in 2023, approximately the midpoint of the Company's guidance range of $520 to $540 million. The Company paid $48.6 million in dividends in 2023 and repurchased 16.4 million shares at an average price of $15.71 per share for a total of $258.3 million. In total, Enerplus returned $306.9 million to shareholders in 2023.

(1)

This is a non-GAAP financial measure. Refer to "Non-GAAP and Other Financial Measures" section for more information.

ENVIRONMENTAL, SOCIAL AND GOVERNANCE (ESG) UPDATE

Enerplus continues to make progress on its ESG initiatives in 2023. Based on preliminary estimates and relative to its 2021 baseline, the Company reduced 2023 methane emissions intensity by 45% and Scope 1 and Scope 2 GHG emissions intensity by 40%.

The Company continues to work towards its longer-term emissions reduction targets, including a methane emissions intensity of 0.02 kg CH4/BOE by 2030, and a Scope 1 and Scope 2 GHG emissions intensity of 13 kg CO2e/BOE by 2030, which equates to an approximate intensity reduction of 45% and 30%, respectively, from Enerplus' preliminary 2023 estimates.

As previously disclosed, as part of its emissions reduction strategy Enerplus is endorsing the World Bank Zero Routine Flaring by 2030 initiative and has established a flare intensity target of less than 2% per thousand cubic feet of natural gas produced by 2026.

2024 OUTLOOK

As previously announced, Enerplus expects 2024 capital spending of approximately $550 million and annual average liquids production of approximately 64,000 barrels per day.  The Company expects 2024 annual average total production of approximately 99,000 BOE per day(1). The Company's 2024 outlook is subject to changes as a result of completion of the transaction with Chord, which is currently expected to close mid-2024.

On February 21, 2024, the Board approved a dividend increase of 8% to the quarterly dividend to $0.065 per share beginning with the March 15, 2024 dividend. It is anticipated that the quarterly dividend payments made by Enerplus until closing of the transaction will be equalized to those made by Chord, after giving effect to the exchange ratio, through an additional Enerplus dividend declared shortly prior to the closing.

(1)

See "Notice Regarding Information Contained in This News Release - Forward-Looking Information and Statements" in this news release. 

PRICE RISK MANAGEMENT UPDATE

The following is a summary of Enerplus' financial contracts in place at February 20, 2024:

WTI Crude Oil ($/bbl)(1)

Leidy Basis ($/Mcf)


Jan 1, 2024 – Jun 30, 2024

Feb 1, 2024 – Feb 29, 2024

Swaps



Volume (Mcf/day)

–

40,000

Swap Strike

–

($ 0.45)





3 Way Collars



Volume (bbls/day)

5,000

–

Sold Puts

$ 65.00

–

Purchased Puts

$ 77.00

–

Sold Calls

$ 95.00

–

(1)

The total average deferred premium spent on our outstanding crude oil contracts is $1.25/bbl from January 1, 2024 – June 30, 2024.

FOURTH QUARTER AND FULL YEAR 2023 PRODUCTION AND OPERATIONAL SUMMARY TABLES

Summary of Average Daily Production(1)

Three months ended December 31, 2023

Twelve months ended December 31, 2023

Williston Basin

Marcellus

Other(2)

Total

Williston Basin

Marcellus

Other(2)

Total

Light & medium oil (bbl/d)

-

-

-

-

-

-

-

-

Heavy oil (bbl/d)

-

-

-

-

-

-

-

-

Tight oil (bbl/d)

52,831

-

1,181

54,011

49,827

-

951

50,779

Total crude oil (bbl/d)

52,831

-

1,181

54,011

49,827

-

951

50,779











Natural gas liquids (bbl/d)

12,952

-

134

13,086

11,323

-

106

11,429











Conventional natural gas (Mcf/d)

-

-

-

-

-

-

-

-

Shale gas (Mcf/d)

74,637

142,926

1,112

218,675

70,645

155,329

866

226,840

Total natural gas (Mcf/d)

74,637

142,926

1,112

218,675

70,645

155,329

866

226,840











Total production (BOE/d)

78,222

23,821

1,500

103,543

72,925

25,888

1,202

100,015

(1)

Table may not add due to rounding.

(2)

Largely comprises the DJ Basin.

Summary of Wells Drilled(1)

Three months ended  
December 31, 2023

Twelve months ended  
December 31, 2023

Operated

Non-Operated

Operated

Non-Operated

Gross

Net

Gross

Net

Gross

Net

Gross

Net

Williston Basin

19

15.1

7

0.3

65

54.7

73

7.1

Marcellus

-

-

16

0.4

-

-

56

1.2

DJ Basin

-

-

-

-

3

2.9

-

-

Total

19

15.1

23

0.7

68

57.6

129

8.3

(1)

Table may not add due to rounding.

Summary of Wells Brought On-Stream(1)

Three months ended  
December 31, 2023

Twelve months ended  
December 31, 2023

Operated

Non-Operated

Operated

Non-Operated

Gross

Net

Gross

Net

Gross

Net

Gross

Net

Williston Basin

-

-

36

3.0

46

40.0

77

9.4

Marcellus

-

-

30

0.6

-

-

52

0.9

DJ Basin

-

-

-

-

3

2.9

10

0.2

Total

-

-

66

3.6

49

43.0

139

10.5

(1)

Table may not add due to rounding.

SUMMARY FINANCIAL AND OPERATING RESULTS

Three months ended


Twelve months ended

SELECTED FINANCIAL RESULTS

December 31, 

December 31, 


2023

2022

2023

2022

Financial (US$, thousands, except ratios)











Net Income/(Loss)

$

116,702

$

330,708

$

456,076

$

914,302

Adjusted Net Income(1)

115,253

181,069

477,570

707,061

Cash Flow from Operating Activities

297,946

316,584

938,190

1,173,382

Adjusted Funds Flow(1)

240,526

315,379

961,243

1,230,289

Dividends to Shareholders - Declared

12,242

12,223

48,603

41,597

Net Debt(1)

119,298

221,516

119,298

221,516

Capital Spending

91,507

85,647

532,450

432,004

Property and Land Acquisitions

1,681

2,853

7,342

22,515

Property and Land Divestments

1,267

211,987

2,969

231,373

Net Debt to Adjusted Funds Flow Ratio(1)

0.1x

0.2x

0.1x

0.2x













Financial per Weighted Average Shares Outstanding











Net Income/(Loss) - Basic

$

0.57

$

1.49

$

2.16

$

3.91

Net Income/(Loss) - Diluted

0.55

1.43

2.09

3.77

Weighted Average Number of Shares Outstanding (000's) - Basic

204,624

222,404

211,353

233,946

Weighted Average Number of Shares Outstanding (000's) - Diluted

211,176

231,149

217,896

242,673













Selected Financial Results per BOE(2)(3)











Crude Oil & Natural Gas Sales(4)

$

45.88

$

55.78

$

45.56

$

64.27

Commodity Derivative Instruments

0.33

(4.83)

1.56

(9.48)

Operating Expenses

(11.67)

(9.68)

(10.67)

(9.99)

Transportation Costs

(3.84)

(4.04)

(3.99)

(4.22)

Production Taxes

(3.81)

(4.03)

(3.70)

(4.56)

General and Administrative Expenses

(1.41)

(1.15)

(1.33)

(1.17)

Cash Share-Based Compensation Recovery/(Expense)

0.15

(0.21)

0.01

(0.16)

Interest, Foreign Exchange and Other Expenses

(0.36)

0.56

(0.36)

(0.32)

Current Income Tax Recovery/(Expense)

(0.02)

(0.34)

(0.75)

(0.77)

Adjusted Funds Flow(1)

$

25.25

$

32.06

$

26.33

$

33.60


Three months ended


Twelve months ended

SELECTED OPERATING RESULTS

December 31, 

December 31, 


2023

2022

2023

2022

Average Daily Production(3)











Crude Oil (bbls/day)

54,011

54,601

50,779

52,017

Natural Gas Liquids (bbls/day)

13,086

10,755

11,429

9,681

Natural Gas (Mcf/day)

218,675

249,351

226,840

231,770

Total (BOE/day)

103,543

106,915

100,015

100,326













% Crude Oil and Natural Gas Liquids

65 %

61 %

62 %

61 %













Average Selling Price(3)(4)











Crude Oil (per bbl)

$

77.21

$

83.06

$

77.42

$

93.63

Natural Gas Liquids (per bbl)

16.86

21.88

17.93

30.70

Natural Gas (per Mcf)

1.65

4.76

1.85

5.51













Net Wells Drilled

15.8

9.9

65.8

51.7

(1)

This financial measure is a non-GAAP financial measure. See "Non-GAAP and Other Financial Measures" section in this news release.

(2)

Non‑cash amounts have been excluded.

(3)

Represents net production volumes. See "Presentation of Production and Reserves Information" section in this news release.

(4)

Before transportation costs and commodity derivative instruments.

Condensed Consolidated Balance Sheets

(US$ thousands)

December 31, 2023

December 31, 2022

Assets






Current assets






Cash and cash equivalents

$

66,731

$

38,000

Accounts receivable, net of allowance for doubtful accounts


268,433

276,590

Other current assets


44,959

56,552

Derivative financial assets


3,161

36,542




383,284

407,684

Property, plant and equipment:






Crude oil and natural gas properties (full cost method)


1,511,682

1,322,904

Other capital assets


9,546

10,685

Property, plant and equipment


1,521,228

1,333,589

Other long-term assets


5,945

21,154

Right-of-use assets


24,996

20,556

Deferred income tax asset


133,023

154,998

Total Assets

$

2,068,476

$

1,937,981








Liabilities






Current liabilities






Accounts payable

$

385,670

$

398,482

Current portion of long-term debt


80,600

80,600

Derivative financial liabilities


—

10,421

Current portion of lease liabilities


12,087

13,664




478,357

503,167

Long-term debt


105,429

178,916

Asset retirement obligation


125,452

114,662

Lease liabilities


14,333

9,262

Deferred income tax liability


117,556

55,361

Total Liabilities


841,127

861,368








Shareholders' Equity






Share capital – authorized unlimited common shares, no par value








Issued and outstanding: December 31, 2023 – 202 million shares






   December 31, 2022 – 217 million shares


2,692,053

2,837,329

Paid-in capital


44,499

50,457

Accumulated deficit


(1,207,862)

(1,509,832)

Accumulated other comprehensive loss


(301,341)

(301,341)




1,227,349

1,076,613

Total Liabilities & Shareholders' Equity

$

2,068,476

$

1,937,981

Condensed Consolidated Statements of Income/(Loss) and Comprehensive Income/(Loss)

For the year ended December 31 (US$ thousands)

2023

2022

2021

Revenues









Crude oil and natural gas sales

$

1,663,016

$

2,353,374

$

1,482,575

Commodity derivative instruments gain/(loss)


31,317

(197,686)

(274,432)




1,694,333

2,155,688

1,208,143

Expenses









Operating


389,677

365,701

292,433

Transportation


145,576

154,658

128,309

Production taxes


135,131

166,995

101,953

General and administrative


65,664

69,954

56,807

Depletion, depreciation, accretion and impairment


377,495

309,367

274,756

Interest


17,597

24,553

27,395

Foreign exchange (gain)/loss


60

10,159

(6,908)

Gain on divestment of assets




—

(151,937)

—

Transaction costs and other expense/(income)


(4,297)

(1,360)

(2,487)




1,126,903

948,090

872,258

Income/(Loss) Before Taxes


567,430

1,207,598

335,885

Current income tax expense/(recovery)


27,183

28,063

2,689

Deferred income tax expense/(recovery)


84,171

265,233

98,755

Net Income/(Loss)

$

456,076

$

914,302

$

234,441











Other Comprehensive Income/(Loss)









Unrealized gain/(loss) on foreign currency translation


—

22,507

(6,893)

Foreign exchange gain/(loss) on net investment hedge, net of tax


—

(26,541)

4,097

Total Comprehensive Income/(Loss)

$

456,076

$

910,268

$

231,645











Net Income/(Loss) per Share









Basic

$

2.16

$

3.91

$

0.93

Diluted

$

2.09

$

3.77

$

0.90

Condensed Consolidated Statements of Cash Flows









For the year ended December 31 (US$ thousands)

2023

2022

2021

Operating Activities









Net income/(loss)

$

456,076

$

914,302

$

234,441

Non-cash items add/(deduct):









Depletion, depreciation, accretion and impairment


377,495

309,367

274,756

Unrealized (gain)/loss on derivative instruments


25,621

(150,526)

109,536

Deferred income tax expense/(recovery)


84,171

265,233

98,755

Unrealized foreign exchange (gain)/loss on working capital


363

11,217

(8,055)

Share-based compensation and general and administrative


17,320

22,529

13,424

Other expense/(income)


2,125

(4,137)

(4,594)

Amortization of debt issuance costs


1,556

1,476

1,093

Translation of U.S. dollar cash held in parent company


—

(937)

(2,330)

Gain on divestment of assets




—

(151,937)

—

Investing activities in Other income


(3,484)

13,702

(4,593)

Asset retirement obligation settlements


(14,999)

(17,401)

(12,951)

Changes in non-cash operating working capital


(8,054)

(39,506)

(94,643)

Cash flow from/(used in) operating activities


938,190

1,173,382

604,839











Financing Activities









Drawings from/(repayment of) bank credit facilities


5,900

(341,655)

395,379

Repayment of senior notes


(80,600)

(100,600)

(81,600)

Purchase of common shares under Normal Course Issuer Bid


(258,276)

(410,906)

(123,182)

Proceeds from the issuance of shares


—

—

98,339

Share-based compensation – tax withholdings settled in cash


(16,720)

(13,386)

(3,551)

Dividends




(48,603)

(41,597)

(32,284)

Cash flow from/(used in) financing activities


(398,299)

(908,144)

253,101











Investing Activities









Capital and office expenditures


(544,771)

(429,873)

(271,131)

Bruin acquisition


—

—

(420,249)

Dunn County acquisition


—

—

(305,076)

Canadian divestments


35,847

158,033

—

Property and land acquisitions


(7,342)

(22,515)

(9,846)

Property and land divestments


5,469

18,385

108,193

Other (expense)/income


—

(13,702)

4,593

Cash flow from/(used in) investing activities


(510,797)

(289,672)

(893,516)

Effect of exchange rate changes on cash and cash equivalents


(363)

1,086

6,979

Change in cash and cash equivalents


28,731

(23,348)

(28,597)

Cash and cash equivalents, beginning of year


38,000

61,348

89,945

Cash and cash equivalents, end of year

$

66,731

$

38,000

$

61,348

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.

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.

Presentation of Production and Reserves Information

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.

All reserves information presented herein are reported in accordance with Canadian reserve evaluation standards under National Instrument 51-101 – Standards of Disclosure for Oil and Gas Activities ("Canadian NI 51-101 Standards"), except certain reserves information effective December 31, 2023 in accordance with the provisions of the Financial Accounting Standards Board's ASC Topic 932 Extractive Activities – Oil and Gas, which generally utilize definitions and estimations of proved reserves that are consistent with Rule 4-10 of Regulation S-X promulgated by the U.S. Securities and Exchange Commission (collectively, the "U.S. Rules"), but does not necessarily include all of the disclosure required by the SEC disclosure standards set forth in Subpart 1200 of Regulation S-K (the "U.S. Standards"). The practice of preparing production and reserves data under the Canadian NI 51-101 Standards differs from the U.S. Rules and the presentation of production and reserves data under the Canadian Standards differs from presentation under the U.S. Standards. Please refer to our reserves news release dated as of the date hereof for further information.

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.

Enerplus' oil and gas reserves statement for the year ended December 31, 2023, which will include complete disclosure of our oil and gas reserves and other oil and gas information prepared under the Canadian NI 51-101 Standards and also certain information about our oil and gas reserves prepared in accordance with the U.S. Rules, is contained within our Annual Information Form (AIF) for the year ended December 31, 2023 which is available on our website at www.enerplus.com and under our SEDAR+ profile at www.sedarplus.ca. Additionally, our AIF forms part of our Form 40-F that is filed with the U.S. Securities and Exchange Commission and is available on EDGAR at www.sec.gov. Readers are also urged to review the 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", "intend", "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: expected transaction with Chord, including timing for completion thereof and its effect on Enerplus; expected 2024 capital spending and average production volumes, the proportion of our anticipated oil and gas production that is hedged and the effectiveness of such hedges in protecting our cash flow from operating activities and adjusted funds flow; the results from our drilling program and the timing of related production and ultimate well recoveries; our ESG initiatives, including Scope 1 and Scope 2 GHG emissions and methane emissions intensity, gas flare reduction targets and health and safety targets; our anticipated progress towards our ESG initiatives, including timing and expected capital expenditures needed to achieve such targets; future environmental expenses; future debt and working capital levels and net debt to adjusted funds flow ratio and adjusted payout ratio, financial capacity, liquidity and capital resources to fund capital spending and working capital requirements; and our future acquisitions and dispositions.

The forward-looking information contained in this news release reflects several material factors and expectations and assumptions of Enerplus including, without limitation: the ability to fund our return of capital plans, including dividends at the current level, from free cash flow as expected; changes in strategies regarding our return of capital plans; that we will conduct our operations and achieve results of operations as anticipated; 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; expectations regarding inflation; 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 the continued conflicts in Ukraine and the Middle East; the continuation of assumed tax, royalty and regulatory regimes; the accuracy of the estimates of our reserve and contingent resource volumes; expectations regarding our share price; 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 continued availability and sufficiency of our adjusted funds flow and availability under our bank credit facility to fund our non-cash working capital deficit; our ability to comply with our debt covenants; our ability to meet the targets associated with our bank credit facilities; the availability of third party services; the extent of our liabilities; estimates relating to our methane and GHG emissions intensity; and the availability of technology and process to achieve environmental targets; In addition, our 2024 outlook contained in this news release is based on the following: a WTI price of $75.00/bbl, a NYMEX price of $2.50/Mcf and a CDN/US exchange rate of 0.75.  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.

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: failure to complete the proposed transaction with Chord; continued instability, or further deterioration, in global economic and market conditions, including from inflation and/or Ukraine/Russia conflict, the Middle East conflict and heightened geopolitical risk; 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, including global energy demand and including as a result of ongoing disruptions to global supply chains; volatility in our share trading price and free cash flow that could impact our planned dividend levels; unanticipated operating results, results from our capital spending activities or production declines; 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 and increased capital and operating costs resulting therefrom; inability to comply with applicable environmental government regulations or regulatory approvals and resulting compliance and enforcement actions; 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 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; failure to realize the anticipated benefits of the divestment of the Canadian assets; 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 Management's Discussion & Analysis and Annual Information Form and Form 40-F as at December 31, 2023).

The forward-looking information contained in this news release speaks only as of the date of this news release, and we do not assume any obligation to publicly update or revise such forward-looking information to reflect new events or circumstances, except as may be required pursuant to 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: (a) indicated the composition of the measure; (b) identified the most directly comparable GAAP financial measure and provided comparative detail where appropriate; (c) indicated the reconciliation of the measure to the most directly comparable GAAP financial measure to the extent one exists; and (d) 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 Enerplus' ability to generate funds to repay debt, pay dividends, and fund future capital investment. 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.

Year ended December 31, 

($ millions)

2023

2022

2021

Cash flow from/(used in) operating activities

$

938.2

$

1,173.4

$

604.8

Asset retirement obligation settlements

15.0

17.4

13.0

Changes in non-cash operating working capital

8.0

39.5

94.6

Adjusted funds flow

$

961.2

$

1,230.3

$

712.4

"Adjusted funds flow before tax" is used by Enerplus and is useful to investors and securities analysts in analyzing Enerplus' current income tax expense as a percentage of adjusted funds flow before tax. The most directly comparable GAAP measure is cash flow from operating activities. Adjusted funds flow before tax is calculated as adjusted funds flow plus current income tax expense.

Year ended December 31, 

($ millions)

2023

2022

2021

Adjusted funds flow(1)

$

961.2

$

1,230.3

$

712.4

Current income tax expense

27.2

28.1

2.7

Adjusted funds flow before tax

$

988.4

$

1,258.4

$

715.1

(1)

See adjusted funds flow reconciliation above for a breakdown of the adjustments made to cash flow from/(used in) operating activities.

"Adjusted net income/(loss)" 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).

Year ended December 31, 

($ millions)

2023

2022

2021

Net income/(loss)

$

456.1

$

914.3

$

234.4

Unrealized derivative instrument, foreign exchange and marketable securities (gain)/loss

29.7

(141.7)

101.4

Gain on divestment of assets



—

(151.9)

—

Other expense/(income) related to investing activities

(2.2)

13.6

(4.6)

Income tax rate adjustment on deferred taxes

—

8.8

6.0

Asset impairment

—

—

3.4

Tax effect on above items

(6.0)

64.0

(24.9)

Adjusted net income/(loss)

$

477.6

$

707.1

$

315.7

"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. The most directly comparable GAAP measure is cash flow from operating activities.









Year ended December 31, 

($ millions)

2023

2022

2021

Adjusted funds flow(1)

$

961.2

$

1,230.3

$

712.4

Capital spending

(532.5)

(432.0)

(302.3)

Free cash flow

$

428.7

$

798.3

$

410.1

(1)

See adjusted funds flow reconciliation above for a breakdown of the adjustments made to cash flow from/(used in) operating activities.

"Net debt" is used by Enerplus and is useful to investors and securities analysts in analyzing overall leverage and financial position at the end of the period. 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. There is no directly comparable GAAP equivalent.

Year ended December 31, 

($ millions)

2023

2022

Current portion of long-term debt

$

80.6

$

80.6

Long-term debt

105.4

178.9

Less: Cash and cash equivalents

(66.7)

(38.0)

Net debt

$

119.3

$

221.5

"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.

Year ended December 31, 

($ millions)

2023

2022

Net debt(1)

$

119.3

$

221.5

Trailing adjusted funds flow

961.2

1,230.3

Net debt to adjusted funds flow ratio

0.1x

0.2x

(1)

See net debt reconciliation above.

Other Financial Measures

SUPPLEMENTARY FINANCIAL MEASURES

Supplementary financial measures are financial measures disclosed by a company that (a) are, or are intended to be, disclosed on a periodic basis to depict the historical or expected future financial performance, financial position or cash flow of a company, (b) are not disclosed in the financial statements of the company, (c) are not non-GAAP financial measures, and (d) are not non-GAAP ratios. The following section provides an explanation of the composition of those supplementary financial measures if not previously provided:

"Capital spending" Capital and office expenditures, excluding other capital assets/office capital and property and land acquisitions and divestments and non-cash investing working capital.

"Cash general and administrative expenses" or "Cash G&A expenses" General and administrative expenses that are settled through cash payout, as opposed to expenses that relate to accretion or other non-cash allocations that are recorded as part of general and administrative expenses.

"Cash share-based compensation" or "Cash SBC expenses" Share-based compensation that is settled by way of cash payout, as opposed to equity settled.

Electronic copies of Enerplus' 2023 MD&A and Financial Statements, along with other public information including investor presentations, are available on the Company's website at www.enerplus.com.  For further information, please contact Investor Relations at 1-800-319-6462 or email [email protected].

SOURCE Enerplus Corporation

Investor Contacts, Drew Mair, 403-298-1707, Krista Norlin, 403-298-4304

Organization Profile

Enerplus Corporation

Enerplus Corporation is a responsible developer of high quality crude oil and natural gas assets in Canada and the United States committed to creating value for its shareholders through a disciplined capital investment strategy....