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Ovintiv Reports Fourth Quarter and Full-Year 2020 Results, Announces Multi-Year Debt Reduction Target, Signs Agreement to Sell Duvernay and Provides Strong 2021 Outlook


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  • Year-end 2020 debt reduced nearly $500 million from mid-year 2020
  • 2021 debt reduction target increased 25% to $1.25 billion including second half 2020
  • Multi-year debt target issued: $4.5 billion of total debt by year-end 2022
  • Company signs agreement to sell its Duvernay asset for $263 million
  • Company generated significant non-GAAP Free Cash Flow for third consecutive year
  • Strong well performance and realized prices combined with lower cash costs drive cash flow beat with lower-than-expected capital investments
  • 2021 capital investment plan of $1.5 billion expected to generate ~$1 billion of non-GAAP Free Cash Flow

DENVER, Feb. 17, 2021 /CNW/ – Ovintiv Inc. (NYSE: OVV) (TSX: OVV) today announced its fourth quarter and full-year 2020 financial and operating results, announced an agreement to sell its Duvernay assets, disclosed its year-end 2020 proved reserves and provided a strong 2021 Outlook. In addition, the Company issued a new target of reducing total debt to $4.5 billion by year-end 2022. A conference call and webcast will be held at 9 a.m. MT, Thursday, February 18, 2021 (details within).

Highlights:

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Ovintiv Reports Fourth Quarter and Full-Year 2020 Results, Announces Multi-Year Debt Reduction Target, Signs Agreement to Sell Duvernay and Provides Strong 2021 Outlook (CNW Group/Ovintiv Inc.)

  • Fourth quarter and full-year financial and operating results exceeded targets and consensus expectations.
  • Full-year cash from operating activities was approximately $1.9 billion, equal to non-GAAP Cash Flow; 2020 non-GAAP Free Cash Flow was $193 million (inclusive of $90 million of one-time restructuring costs), with strong fourth quarter momentum of nearly $350 million in non-GAAP Free Cash Flow.
  • Reduced total long-term debt, including current portion, by $257 million in the fourth quarter, representing a $481 million reduction since mid-year 2020.
  • Delivered strong well performance, driving fourth quarter crude and condensate(1)production of 215 thousand barrels per day (Mbbls/d), above guidance of 200 Mbbls/d; Fourth quarter total production averaged 557 thousand barrels of oil equivalent per day (MBOE/d).
  • Full-year 2020 production averaged 544 MBOE/d.
  • Maintained disciplined capital investments with full year spending of $1.74 billion, well under the $1.8 billion guide.
  • Further capital efficiency gains achieved with fourth quarter average completed well costs at least 25% lower than full-year 2019 averages; new pacesetter well costs attained in each of the three core plays.
  • Achieved seventh consecutive “safest-year-ever”.
  • Flared and vented natural gas volumes in the fourth quarter of 2020 accounted for less than 0.5% of total natural gas production, down significantly from 1.2% in 2019.
  • Reached an agreement to sell its Duvernay assets for $263 million including $12 million of contingent payments.
  • Established total debt target of $4.5 billion by year-end 2022, a 35% reduction when compared to year-end 2020, inclusive of $1 billion in divestment proceeds.

Ovintiv CEO Doug Suttles said, “We achieved outstanding financial, operating and environmental results in 2020. Through this combination, we ‘beat our beat’ in the fourth quarter with lower capital investments and very strong cash flows. The strengths of our company – a high-quality portfolio, industry-leading efficiencies, sophisticated risk management and a culture of innovation – were crucial to our success during a challenging time for the industry. For the third consecutive year, we delivered meaningful free cash flow, and we estimate $1 billion in free cash flow in 2021. We’ve made significant progress on debt reduction and today increased our year-end 2021 debt reduction target by 25% to $1.25 billion and set a year-end 2022 total debt target of $4.5 billion. The critical intersection of financial and operating results with environmental progress was evident through our industry-leading total flare and vent volumes of less than half-of-one percent in the fourth quarter.”

1. Throughout this document, crude and condensate refers to tight oil including medium and light crude oil volumes and plant condensate.

A conference call and webcast to discuss the 2020 fourth quarter and full-year results and the 2021 Outlook will be held at 9 a.m. MT on February 18, 2021. In addition to the release, supplemental slides and financial statements will be available on the Company’s website, located at www.ovintiv.com. The Company also issued a separate release today on its enhanced compensation, governance, and environmental initiatives. To participate in the conference call, please dial 888-664-6383 (toll-free in North America) or 416-764-8650 (international) approximately 15 minutes prior to the call. The live audio webcast of the conference call, including slides, will also be available on Ovintiv’s website, under Investors/Presentations and Events, and will be archived for approximately 90 days.

Multi-Year Debt Reduction Target
Reducing debt is Ovintiv’s number one priority. The Company today set a year-end 2022 goal to reduce absolute debt to $4.5 billion, a 35% reduction from year-end 2020. This target includes $1 billion in divestment proceeds and maintaining crude and condensate production of approximately 200 Mbbls/d. The Company’s previously announced leverage target of 1.5 times net-debt-to adjusted EBITDA and its long-term reinvestment framework of less than 75% of annual non-GAAP Cash Flow were reaffirmed.

Sale of Duvernay Assets
The Company through a wholly owned subsidiary, has agreed to sell its Duvernay assets for approximately $263 million including approximately $12 million in contingency payments based on future commodity prices. The agreement is subject to ordinary closing conditions, regulatory approvals and other adjustments and is expected to close in the second quarter of 2021. Duvernay production averaged approximately 10 MBOE/d (43% liquids) in the fourth quarter of 2020. Ovintiv will update its guidance once the transaction has closed.

“Today’s announcement of the sale of our Duvernay asset combined with our strong fourth quarter and 2021 guide clearly demonstrate our commitment to debt reduction and puts us squarely on track to achieve our $4.5 billion dollar year-end 2022 goal,” said Suttles.

Full Year and Fourth Quarter 2020 Financial and Operating Results
For 2020, the Company recorded a net loss of $6.1 billion, or ($23.47) per share of common stock, driven primarily by a non-cash ceiling test impairment of $5,580 million, before-tax, related to the decline in 12-month average trailing commodity prices which reduced SEC proved reserves (see proved reserves table within this release). Non-GAAP operating earnings were $91 million, or $0.35 per share of common stock.

The Company recorded a net loss in the fourth quarter of $614 million, or ($2.36) per share of common stock. Cash from operating activities for the fourth quarter was $719 million and non-GAAP Cash Flow was $692 million.

Production Summary and Asset Highlights
Ovintiv’s significantly higher than expected fourth quarter production was largely driven by strong well results across the portfolio. The Company’s cube development approach and innovative completion designs continued to deliver industry-leading capital efficiencies. Fourth quarter crude oil and condensate volumes were 215 Mbbls/d. Fourth quarter liquids production averaged 297 Mbbls/d and total Company production was 557 MBOE/d.

For the year, total production averaged 544 MBOE/d including liquids production of 289 Mbbls/d. See the “Capital Investment and Production” table below.

In the fourth quarter, Ovintiv set new, record-low well costs in each of its Core 3 assets. The Company exceeded its stated goal of reducing 2020 well costs by 20% when compared to 2019 averages by delivering cost reductions of 25% or greater during the quarter.

“Ovintiv has demonstrated industry-leading capital efficiencies across our portfolio,” said Suttles. “The efforts of our teams to consistently find innovative ways to reduce costs have led to sustainable capital savings that will be durable even as commodity prices improve. More importantly, they never lost their focus on safety and 2020 marks our ‘safest year ever’ for the seventh consecutive year.”

Permian
Permian production averaged 110 MBOE/d (81% liquids) in the fourth quarter. The Company averaged three rigs, drilled 22 net wells, and had 29 net wells turned in line (TIL).

Fourth quarter drilling and completion (D&C) costs per lateral foot was $470, down more than 30% compared to 2019 average D&C cost.

Full year production in the play averaged 109 MBOE/d (81% liquids).

Anadarko
Anadarko production averaged 134 MBOE/d (62% liquids) in the fourth quarter. The Company averaged two rigs, drilled 11 net wells, and had 28 net wells TIL.

Fourth quarter D&C costs per lateral foot was $440, down over 30% compared to 2019 average D&C cost.

Full year production in the play averaged 144 MBOE/d (62% liquids).

Montney
Montney production averaged 222 MBOE/d (26% liquids) in the fourth quarter. The Company averaged four rigs, drilled 22 net wells and had 28 net wells TIL.

Fourth quarter D&C costs per lateral foot was $380, down approximately 25% compared to 2019 average D&C cost.

Full year production in the play averaged 204 MBOE/d (25% liquids).

Base Assets
There were 23 net wells TIL in the base assets during the fourth quarter. All fourth quarter TILs were drilled in the first half of the year.

Year-End 2020 Reserves
Under Canadian reserves protocol, proved and probable reserves were 4.2 billion BOE before royalties and 3.5 billion BOE after royalties. SEC proved reserves at year-end 2020 were 2.0 billion BOE, of which approximately 60% were liquids and 56% were proved developed. The significant gains in capital efficiency that the Company realized through the year resulted in an SEC total proved reserve replacement of 90% of 2020 production excluding price and net of acquisitions and divestitures.

Balance Sheet and Liquidity
Ovintiv’s total liquidity at year end was approximately $3.3 billion, which represents the Company’s $4 billion committed, unsecured credit facilities, available capacity on uncommitted demand lines and cash-on-hand, net of the amount drawn on the credit facilities and commercial paper outstanding.

Throughout 2020 Ovintiv took steps to capitalize on market dislocations, purchasing its notes at a discount in the open market, resulting in a $30 million gain as well as go-forward interest savings. During 2020, Ovintiv repurchased approximately $302 million in principal of its senior notes for a cash payment of approximately $272 million, plus accrued interest. The Company expects to incur lower interest expense of approximately $10 million on an annualized basis on the reduced fixed long-term debt balances. The Company has significant flexibility to manage its late 2021 and early 2022 maturities, including available cash on hand or the use of its credit facilities.

More than 80% of the Company’s total fixed-rate long-term debt is due in 2024 or later and has an aggregate weighted average bond maturity of approximately nine years.

Refer to Note 1 Non-GAAP measures and the tables in this release for reconciliation to comparable GAAP financial measures.

2021 Outlook
Regarding the Company’s 2021 Outlook, Suttles said, “Our strong performance in 2020 sets us up well to deliver once again in 2021. We expect this will be our fourth consecutive year of generating significant free cash flow and we are confident in our ability to meaningfully reduce our debt over the next two years. Longer-term, our ongoing capital discipline and reinvestment rate commitment ensure that we will be able to return cash to shareholders – all critical components of the ‘new E&P’ company.”

Ovintiv’s 2021 planned capital investments are approximately $1.5 billion and are expected to generate non-GAAP Free Cash Flow of approximately $1 billion, assuming commodity prices of $50 WTI and $2.75 NYMEX. The capital program represents a cash flow reinvestment rate of about 60%, significantly lower than the Company’s framework of less than 75%.

Over 90% of total capital investment is earmarked for Ovintiv’s Core 3 assets—Permian, Anadarko and Montney. The Company plans to execute a load-levelled program with consistent quarterly levels of activity and capital spending.

Crude oil and condensate volumes are expected to be relatively flat through the year, averaging approximately 200 Mbbls/d. Full-year NGL (C2 – C4) production is expected to be approximately 80 Mbbls/d and natural gas is expected to average approximately 1.55 billion cubic feet per day (Bcf/d). Total costs in 2021 are expected to average approximately $12.25 to $12.50 per barrel of oil equivalent (BOE).

Ovintiv has strong risk management positions in place with about 65% of 2021 crude oil and condensate and natural gas production hedged. The majority of the hedges are in three-way structures that provide exposure to higher oil prices. Hedge tables can be found below.

2021 Guidance

Capital Expenditures ($ million) $1,500
Oil & Condensate (Mbbls/d) (1) 200
Other NGLs (Mbbls/d) 80
Natural Gas (MMcf/d) (2) 1,550
Total Costs per BOE (3)
(Upstream Transportation and Processing, Operating, Production, Mineral and Other Taxes, plus Corp G&A)
$12.25 – $12.50
(1) Primarily tight oil, including minimal medium and light crude oil volumes, and approximately 25% plant condensate.
(2) Primarily shale gas, including minimal conventional natural gas.
(3) Operating and G&A costs exclude long-term incentive costs and CECL.

Dividend declared
On February 17, 2021, Ovintiv’s Board declared a dividend of $0.09375 per share of common stock payable on March 31, 2021 to common stockholders of record as of March 15, 2021.

Capital Investment and Production

(for the period ended December 31) Q4 2020 Q4 2019 2020 2019
Capital Expenditures (1) ($ millions) 343 574 1,736 2,626
Oil (Mbbls/d) (2) 158.0 172.9 151.5 164.4
NGLs – Plant Condensate (Mbbls/d) 56.8 52.9 52.1 52.9
NGLs – Other (Mbbls/d) 82.6 96.2 85.3 84.6
Total NGLs (Mbbls/d) 139.4 149.1 137.4 137.5
Total Liquids (Mbbls/d) 297.4 322.0 288.9 301.9
Natural gas (MMcf/d) (3) 1,559 1,624 1,529 1,577
Total production (MBOE/d) 557.2 592.6 543.8 564.9
(1) Including capitalized overhead costs.
(2) Primarily tight oil, including minimal medium and light crude oil volumes.
(3) Primarily shale gas, including minimal conventional natural gas.

Fourth Quarter and Year-End Summary

Non-GAAP Cash Flow Reconciliation
 (for the period ended December 31)

($ millions, except as indicated)

Q4

 2020

Q4

2019

 

2020

 

2019

Cash from (used in) operating activities 719 730 1,895 2,921
Deduct (add back):
Net change in other assets and liabilities (6) (42) (173) (97)
Net change in non-cash working capital 33 (43) 139 87
Non-GAAP cash flow(1) 692 815 1,929 2,931
Non-GAAP cash flow margin(1) ($/BOE) 13.50 14.95 9.69 14.21
Non-GAAP Free Cash Flow Reconciliation 
Non-GAAP cash flow(1) 692 815 1,929 2,931
Less: capital expenditures 343 574 1,736 2,626
Non-GAAP free cash flow(1) 349 241 193 305
Non-GAAP Operating Earnings Reconciliation
Net earnings (loss) before income tax (642) (68) (5,730) 315
Before-tax (addition) deduction:
Unrealized gain (loss) on risk management (186) (345) (204) (730)
Impairments (717) (5,580)
Restructuring charges (2) (4) (90) (138)
Non-operating foreign exchange gain (loss) 17 52 (16) 94
Gain (loss) on divestitures (1) 3
Gain on debt retirement 2 30
Income tax expense (recovery) 61 20 39 226
Non-GAAP operating earnings (loss)(1) 183 210 91 860
(1) Non-GAAP cash flow, non-GAAP cash flow margin, non-GAAP free cash flow, and non-GAAP operating earnings are non-GAAP measures as defined in Note 1.

Realized Pricing Summary

Q4 2020 Q4 2019 2020 2019
Liquids ($/bbl)
WTI 42.66 56.96 39.40 57.03
Realized liquids prices (1)
Oil 47.75 56.17 44.68 57.40
NGLs – Plant Condensate 44.81 52.03 40.89 51.95
NGLs – Other 10.94 12.90 9.41 14.04
Total NGLs 24.73 26.80 21.35 28.63
Natural gas
NYMEX ($/MMBtu) 2.66 2.50 2.08 2.63
Realized natural gas price (1) ($/Mcf) 2.33 2.25 2.13 2.28
(1) Prices include the impact of realized gains (losses) on risk management.

Total Costs Summary

(for the year ended December 31)
($ millions, except as indicated)
2020 2019
Total Operating Expenses 11,484 6,128
Deduct (add back):
Market optimization operating expenses 1,608 1,304
Corporate & other operating expenses (2) (3)
Depreciation, depletion and amortization 1,834 2,015
Impairments 5,580
Accretion of asset retirement obligation 29 37
Long-term incentive costs 31 35
Restructuring costs 90 138
Current expected credit losses 1
Total Costs (1) 2,313 2,602
Divided by:
Production Volumes (MMBOE) 199.0 206.2
Total Costs (1) ($/BOE) 11.60 12.59
Drivers Included in Total Costs (1) ($/BOE)
Production, mineral and other taxes 0.87 1.23
Upstream transportation and processing 6.44 6.42
Upstream operating, excluding long-term incentive costs 2.88 3.35
Administrative, excluding long-term incentive costs,  restructuring costs and current expected credit losses 1.41 1.59
Total Costs (1) ($/BOE) 11.60 12.59
(1) Calculated using whole dollars and volumes. Total Costs is a non-GAAP measure as defined in Note 1.

Debt to Adjusted Capitalization

($ millions, except as indicated) December 31, 2020 December 31, 2019
Long-Term Debt, including current portion 6,885 6,974
Total Shareholders’ Equity 3,837 9,930
Equity Adjustment for Impairments at December 31, 2011 7,746 7,746
Adjusted Capitalization 18,468 24,650
Debt to Adjusted Capitalization (1)  37% 28%
(1) Debt to Adjusted Capitalization is a non-GAAP measure as defined in Note 1.

Year-End 2020 Reserves Estimates

2020 Reserves Estimates – Canadian Protocols (Net, After Royalties)(1)
Using forecast prices and costs; simplified table (MMBOE) 1P
Proved
2P
Proved + Probable
Canadian Operations 696.7 1,227.4
USA Operations 1,496.8 2,267.2
Total as of December 31, 2020 2,193.5 3,494.6
2020 Proved Reserves Estimates – Canadian Protocols (Net, After Royalties) (1)
Using forecast prices and costs; simplified table Oil
(MMbbls)
(3)
NGLs
(MMbbls)
Natural
Gas
(Bcf)
(4)
Total
(MMBOE)
December 31, 2019 737.6 596.7 5,793 2,299.8
Technical Revisions (92.0) 43.3 54 (39.8)
Economic Factors (23.1) (9.3) (120) (52.5)
Extensions, improved recovery and discoveries 64.4 50.3 482 195.0
Acquisitions 10.8 19.5 140 53.7
Dispositions (9.4) (20.7) (201) (63.6)
Production (55.4) (50.3) (560) (199.0)
December 31, 2020 632.9 629.5 5,587 2,193.5

 

2020 Proved Plus Probable Reserves Estimates – Canadian Protocols (Net, After Royalties) (1)
Using forecast prices and costs; simplified table  

Oil
(MMbbls)
(3)

 

NGLs
(MMbbls)

Natural
Gas
(Bcf)
(4)
 

Total
(MMBOE)

December 31, 2019 1,369.1 1,029.3 10,746 4,189.5
Technical Revisions (471.7) (164.3) (2,432) (1,041.3)
Economic Factors (27.9) (4.8) (79) (45.9)
Extensions, improved recovery and discoveries 210.3 144.6 1,568 616.3
Acquisitions 18.0 30.3 232 86.9
Dispositions (17.2) (38.2) (339) (111.9)
Production (55.4) (50.3) (560) (199.0)
December 31, 2020 1,025.3 946.6 9,137 3,494.6
2020 Proved Reserves Estimates – U.S. Protocols (Net, After Royalties)(1)
Using constant prices and costs; simplified table Oil
(MMbbls)
(3)
NGLs
(MMbbls)
Natural
Gas
(Bcf)
(4)
Total
(MMBOE)
December 31, 2019 723.7 588.5 5,259 2,188.8
Revisions and improved recovery (2) (222.0) (62.2) (484) (364.9)
Extensions and discoveries 144.4 105.8 764 377.5
Purchase of reserves in place 10.9 20.0 140 54.3
Sale of reserves in place (9.3) (21.4) (201) (64.1)
Production (55.4) (50.3) (560) (199.0)
December 31, 2020 592.3 580.5 4,918 1,992.5

 

1) Numbers may not add due to rounding.
2) Changes in reserve estimates resulting from economic factors, pricing and application of improved recovery techniques are included in revisions of previous estimates.
3) Primarily tight oil, including minimal medium and light crude oil volumes.
4) Primarily shale gas, including minimal conventional natural gas.

Differences between estimates under Canadian and U.S. protocols primarily represent the use of forecast prices and escalating costs in the estimation of reserves under Canadian standards, while U.S. standards require the use of 12-month average historical prices which are held constant along with costs. For information on reserves reporting, see Note 2.

2021 Hedge Positions as of January 31, 2021

Oil & Condensate Hedges 2021 Q1 2021 Q2 2021 Q3 2021 Q4 2021
WTI 3-Way Options Mbbls/d 90 74 69 69 75
Short Call ($/bbl) $50.03 $51.05 $52.65 $52.65 $51.48
Long Put ($/bbl) $40.66 $41.32 $42.53 $42.53 $41.68
Short Put ($/bbl) $32.58 $32.29 $32.82 $32.82 $32.62
WTI Swaps Mbbls/d 50 40 30 30 37
Swap Price ($/bbl) $44.49 $47.54 $46.37 $46.37 $46.06
WTI Costless Collars Mbbls/d 15 15 15 15 15
Short Call ($/bbl) $45.84 $45.84 $45.84 $45.84 $45.84
Long Put ($/bbl) $35.00 $35.00 $35.00 $35.00 $35.00
Natural Gas Hedges 2021 Q1 2021 Q2 2021 Q3 2021 Q4 2021
NYMEX 3-Way Options MMcf/d 880 1,030 1,030 880 955
Short Call ($/Mcf) $3.55 $3.37 $3.37 $3.35 $3.41
Long Put ($/Mcf) $2.90 $2.87 $2.87 $2.88 $2.88
Short Put ($/Mcf) $2.50 $2.50 $2.50 $2.50 $2.50
NYMEX Swaps MMcf/d 165 165 83
Swap Price ($/Mcf) $2.51 $2.51 $2.51

About Ovintiv Inc.
Ovintiv is one of the largest producers of oil, condensate and natural gas in North America. The Company is committed to preserving its financial strength, maximizing profitability through disciplined capital investments and operational efficiencies and returning capital to shareholders. A talented team, in combination with a culture of innovation and efficiency, fuels Ovintiv’s economic performance, increases shareholder value and strengthens its commitment to sustainability in the communities where its employees live and work.

NOTE 1: Non-GAAP measures
Certain measures in this news release do not have any standardized meaning as prescribed by U.S. GAAP and, therefore, are considered non-GAAP measures. These measures may not be comparable to similar measures presented by other companies and should not be viewed as a substitute for measures reported under U.S. GAAP. These measures are commonly used in the oil and gas industry and/or by Ovintiv to provide shareholders and potential investors with additional information regarding the Company’s liquidity and its ability to generate funds to finance its operations. For additional information regarding non-GAAP measures, see the Company’s website. This news release contains references to non-GAAP measures as follows:

  • Non-GAAP Cash Flowis a non-GAAP measure defined as cash from (used in) operating activities excluding net change in other assets and liabilities, net change in non-cash working capital and current tax on sale of assets. Non-GAAP Cash Flow Margin is a non-GAAP measure defined as Non-GAAP Cash Flow per BOE of production. Non-GAAP Free Cash Flow is a non-GAAP measure defined as Non-GAAP Cash Flow in excess of capital expenditures, excluding net acquisitions and divestitures.
  • Non-GAAP Operating Earnings (Loss)is a non-GAAP measure defined as net earnings (loss) excluding non-recurring or non-cash items that Management believes reduces the comparability of the Company’s financial performance between periods. These items may include, but are not limited to, unrealized gains/losses on risk management, impairments, restructuring charges, non-operating foreign exchange gains/losses, gains/losses on divestitures and gains on debt retirement. Income taxes includes adjustments to normalize the effect of income taxes calculated using the estimated annual effective income tax rate.
  • Total Costs is a non-GAAP measure which includes the summation of production, mineral and other taxes, upstream transportation and processing expense, upstream operating expense and administrative expense, excluding the impact of long-term incentive costs, restructuring costs and current expected credit losses. It is calculated as total operating expenses excluding non-upstream operating costs and non-cash items which include operating expenses from the Market Optimization and Corporate and Other segments, depreciation, depletion and amortization, impairments, accretion of asset retirement obligation, long-term incentive costs, restructuring costs and current expected credit losses. When presented on a per BOE basis, Total Costs is divided by production volumes. Management believes this measure is useful to the Company and its investors as a measure of operational efficiency across periods.
  • Debt to Adjusted Capitalization is a non-GAAP measure which adjusts capitalization for historical ceiling test impairments that were recorded as at December 31, 2011. Management monitors Debt to Adjusted Capitalization as a proxy for the Company’s financial covenant under the Credit Facilities which require debt to adjusted capitalization to be less than 60 percent. Adjusted Capitalization incudes debt, total shareholders’ equity and an equity adjustment for cumulative historical ceiling test impairments recorded as at December 31, 2011 in conjunction with the Company’s January 1, 2012 adoption of U.S. GAAP.
  • Net Debt, Adjusted EBITDA and Net Debt to Adjusted EBITDA– Net Debt is defined as long-term debt, including the current portion, less cash and cash equivalents. Management uses this measure as a substitute for total long-term debt in certain internal debt metrics as a measure of the company’s ability to service debt obligations and as an indicator of the company’s overall financial strength. Adjusted EBITDA is defined as trailing 12-month net earnings (loss) before income taxes, DD&A, impairments, accretion of asset retirement obligation, interest, unrealized gains/losses on risk management, foreign exchange gains/losses, gains/losses on divestitures and other gains/losses. Net Debt to Adjusted EBITDA is monitored by management as an indicator of the company’s overall financial strength.

Note 2: INFORMATION ON RESERVES REPORTING – Detailed Canadian protocol disclosure will be contained in the Company’s Form 51-101F1 for the year ended December 31, 2020 (“Form 51-101F1”) and detailed U.S. protocol disclosure will be contained in the Company’s Annual Report on Form 10-K for the year ended December 31, 2020 (“Annual Report on Form 10-K”), each of which the Company anticipates filing with applicable securities regulatory authorities on or about February 18, 2021. A description of the primary differences between the disclosure requirements under Canadian standards and under U.S. standards will be set forth under the heading “Note Regarding Additional Reserves Information” in the Form 51–101F1.

ADVISORY REGARDING FORWARD-LOOKING STATEMENTS – This news release contains certain forward-looking statements or information (collectively, “FLS”) within the meaning of applicable securities legislation, including the United States Private Securities Litigation Reform Act of 1995. FLS include: targeted debt reduction; 2021 outlook, including with respect to expected capital investments, reinvestment rate, free cash flow, production and pricing; estimated hedging revenue and sensitivity to commodity prices; timing and size of expected asset sales; and contingent payments. FLS involve assumptions, risks and uncertainties that may cause such statements not to occur or results to differ materially. These assumptions include expectations and projections made in light of the Company’s historical experience. Risks and uncertainties include: commodity price volatility and impact to the Company’s stock price and cash flows; ability to secure adequate transportation and potential curtailments of refinery operations, including resulting storage constraints or widening price differentials; discretion to declare and pay dividends, if any; business interruption, property and casualty losses or unexpected technical difficulties; impact of COVID-19 to the Company’s operations, including maintaining ordinary staffing levels, securing operational inputs, executing on portions of its business and cyber-security risks associated with remote work; counterparty and credit risk; impact of changes in credit rating and access to liquidity, including costs thereof; risks in marketing operations; risks associated with technology; risks associated with decommissioning activities, including timing and costs thereof; the occurrence of any event, change or other circumstances that could give rise to the inability to complete proposed asset sales; and other risks and uncertainties as described in the Company’s Annual Report on Form 10-K, Quarterly Report on Form 10-Q and as described from time to time in its other periodic filings as filed on EDGAR and SEDAR. Although the Company believes such FLS are reasonable, there can be no assurance they will prove to be correct. The above assumptions, risks and uncertainties are not exhaustive. FLS are made as of the date hereof and, except as required by law, the Company undertakes no obligation to update or revise any FLS.

SOLICITATION OF PROXIES – Ovintiv intends to file a proxy statement and WHITE proxy card with the U.S. Securities and Exchange Commission (the “SEC”) and Canadian securities regulatory authorities in connection with its solicitation of proxies for its 2021 Annual Meeting of Stockholders (the “2021 Annual Meeting”). OVINTIV STOCKHOLDERS ARE STRONGLY ENCOURAGED TO READ THE DEFINITIVE PROXY STATEMENT (AND ANY AMENDMENTS AND SUPPLEMENTS THERETO) AND ACCOMPANYING WHITE PROXY CARD WHEN THEY BECOME AVAILABLE AS THEY WILL CONTAIN IMPORTANT INFORMATION. Stockholders may obtain the proxy statement, any amendments or supplements to the proxy statement and other documents as and when filed by Ovintiv with the SEC without charge from the SEC’s website at www.sec.gov and Canadian securities regulatory authorities at www.sedar.com.

Certain Information Regarding Participants
Ovintiv, its directors and certain of its executive officers may be deemed to be participants in connection with the solicitation of proxies from Ovintiv’s stockholders in connection with the matters to be considered at the 2021 Annual Meeting. Information regarding the ownership of Ovintiv’s directors and executive officers in Ovintiv common stock is included in their SEC filings on Forms 3, 4, and 5, which can be found through the SEC’s website at www.sec.gov. Information can also be found in Ovintiv’s other SEC filings. More detailed and updated information regarding the identity of potential participants, and their direct or indirect interests, by security holdings or otherwise, will be set forth in the proxy statement and other materials to be filed with the SEC. These documents can be obtained free of charge from the sources indicated above.

Further information on Ovintiv Inc. is available on the Company’s website, www.ovintiv.com, or by contacting:

Investor contact: Media contact:
 (888) 525-0304 (281) 210-5253

 



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