GUIDANCE

Paramount is reaffirming its 2024 guidance for sales volumes.  The Company currently has approximately 4,600 Boe/d of dry gas production shut-in.  The 2024 sales volumes guidance assumes that this production, as well as certain new dry gas production, is brought online in the fourth quarter.  If natural gas prices do not improve later in the year, as anticipated, the Company may choose to defer bringing this production online.  In such a case, Paramount anticipates that 2024 sales volumes would be at the lower end of the forecast range.

The Company is reaffirming its 2024 guidance for capital expenditures and abandonment and reclamation expenditures.

Paramount is updating its forecast of 2024 free cash flow from $205 million to $100 million to reflect first half results and revised natural gas price assumptions for the second half of 2024 of US$2.50/MMBtu NYMEX and $1.50/GJ AECO (previously US$3.50/MMBtu NYMEX and $2.84/GJ AECO).  Assumed WTI pricing for the second half of 2024 remains unchanged at US$80.00/Bbl.

The Company's midpoint 2024 sustaining and maintenance capital program, abandonment and reclamation expenditures and regular monthly dividend would remain fully funded down to an average WTI price for the second half of 2024 of about US$56/Bbl, assuming no changes to the other forecast assumptions.

AUGUST DIVIDEND

Paramount's Board of Directors has declared a cash dividend of $0.15 per class A common share that will be payable on August 30, 2024 to shareholders of record on August 15, 2024.  The dividend will be designated as an "eligible dividend" for Canadian income tax purposes.

REVIEW OF OPERATIONS

GRANDE PRAIRIE REGION

Sales volumes and netbacks in the Grande Prairie Region are summarized below:

Second quarter 2024 sales volumes in the Grande Prairie Region were consistent with Paramount's expectations, averaging 63,480 Boe/d (51% liquids) compared to 67,163 Boe/d (50% liquids) in the first quarter.  Although field deliverability has been enhanced as a result of the previously disclosed well optimization program, second quarter sales volumes were restricted by planned maintenance outages at two third-party natural gas processing facilities.  Sales volumes were further restricted by start-up issues and unplanned downtime at one of these plants, which have since been largely resolved.

The well optimization program that was initiated in the first quarter is ongoing and has resulted in improved deliverability.  There are currently 11 wells that the Company believes could benefit from intervention in the Grande Prairie Region.  The magnitude of incremental contribution from these wells is expected to be less as the Company focused on the highest impact wells first.

Development activities in the Grande Prairie Region in the second quarter included the drilling of eleven (11.0 net) Montney wells, the completion of eleven (11.0 net) Montney wells and the bringing onstream of four (4.0 net) Montney wells.  The construction of a new compressor node in the western portion of the Wapiti field was concluded and commissioned in July, approximately one month ahead of schedule.  This has allowed the Company to bring a new seven (7.0 net) well Montney pad on production earlier than forecast.  The pad has been brought on at restricted rates, initially through temporary equipment and more recently through permanent facilities.

Paramount plans to drill a total of 16 (16.0 net) Montney wells and bring on production a total of 27 (27.0 net) Montney wells in the Grande Prairie Region in the second half of 2024.  As previously disclosed, third quarter sales volumes will be impacted by a planned 21-day full outage at the Wapiti natural gas processing plant.

KAYBOB REGION

Kaybob Region sales volumes averaged 23,946 Boe/d (41% liquids) in the second quarter of 2024 compared to 22,353 Boe/d (42% liquids) in the first quarter.  Sales volumes increased as a result of new well production from a five (5.0 net) well Kaybob North Duvernay pad that came on production part way through the second quarter.  The shut-in of certain dry gas wells due to low natural gas prices partially offset production contributions from this pad.  In light of low natural gas pricing, Paramount shut-in 1,800 Boe/d of Kaybob Region dry gas production in the second quarter and does not expect to bring this production back on until late 2024 when prices are forecast to improve.

Development activities in the second quarter included the drilling of five (5.0 net) Duvernay wells and the completion and bringing on production of a five (5.0 net) well Duvernay pad at Kaybob North.

Initial production from the five well Duvernay pad brought onstream at Kaybob North in the second quarter averaged gross 30-day peak production per well of 1,028 Boe/d (1.1 MMcf/d of shale gas and 853 Bbl/d of NGLs) with an average CGR of 814 Bbl/MMcf. ⁽¹⁾  The wells on this pad have been flowing at restricted rates due to facility constraints.

Paramount plans to drill five (5.0 net) Duvernay wells and bring on production six (6.0 net) Duvernay wells at Kaybob North in the second half of 2024.

CENTRAL ALBERTA AND OTHER REGION

Central Alberta and Other Region sales volumes averaged 8,183 Boe/d (49% liquids) in the second quarter of 2024 compared to 11,461 Boe/d (44% liquids) in the first quarter.  In the second quarter, the Company shut-in approximately 2,800 Boe/d of dry gas production in northeast British Columbia due to low natural gas prices.

Paramount finished the drilling of a new six (6.0 net) well Duvernay pad in Willesden Green in the second quarter.  The Company plans to complete and bring onstream three of these wells in the third quarter and the remaining three wells in 2025 when sufficient processing capacity is expected to be available.

The construction of the Company's second operated natural gas processing plant in the Willesden Green area is ongoing.  Paramount continues to anticipate start-up of the plant in the fourth quarter of 2025.

The Company plans to drill five (5.0 net) Duvernay wells and bring on production three (3.0 net) Duvernay wells at Willesden Green in the second half of 2024.  Third quarter sales volumes will be impacted by the planned shut-in of certain legacy wells on the Willesden Green Duvernay 04-07 pad for two weeks as completion operations are conducted on three new wells on this pad.  The Company capitalized on this planned downtime by taking a 9-day full outage of the Company's Leafland natural gas processing plant to conduct preventative maintenance and minor repair work.

HEDGING

The Company's current commodity and foreign exchange contracts are summarized below:

ABOUT PARAMOUNT

Paramount is an independent, publicly traded, liquids-rich natural gas focused Canadian energy company that explores for and develops both conventional and unconventional petroleum and natural gas, including longer-term strategic exploration and pre-development plays, and holds a portfolio of investments in other entities.  The Company's principal properties are located in Alberta and British Columbia.  Paramount's Common Shares are listed on the Toronto Stock Exchange under the symbol "POU".

Paramount's second quarter 2024 results, including Management's Discussion and Analysis and the Company's Interim Consolidated Financial Statements, can be obtained on SEDAR+ at www.sedarplus.ca or on Paramount's website at www.paramountres.com/investors/financial-shareholder-reports.

A summary of historical financial and operating results is also available on Paramount's website at www.paramountres.com/investors/financial-shareholder-reports.

FINANCIAL AND OPERATING RESULTS ⁽¹⁾

PRODUCT TYPE INFORMATION

This press release includes references to sales volumes of "natural gas", "condensate and oil", "NGLs", "Other NGLs" and "liquids".  "Natural gas" refers to shale gas and conventional natural gas combined.  "Condensate and oil" refers to condensate, light and medium crude oil, tight oil and heavy crude oil combined.  "NGLs" refers to condensate and Other NGLs combined.  "Other NGLs" refers to ethane, propane and butane.  "Liquids" refers to condensate and oil and Other NGLs combined.  Below is a complete breakdown of sales volumes for applicable periods by the specific product types of shale gas, conventional natural gas, NGLs, light and medium crude oil, tight oil and heavy crude oil.  Numbers may not add due to rounding.

The Company forecasts that 2024 annual sales volumes will average between 100,000 Boe/d and 106,000 Boe/d (52% shale gas and conventional natural gas combined, 41% condensate, light and medium crude oil, tight oil and heavy crude oil combined and 7% Other NGLs).  Third quarter 2024 sales volumes are expected to average between 96,000 Boe/d and 104,000 Boe/d (51% shale gas and conventional natural gas combined, 42% condensate, light and medium crude oil, tight oil and heavy crude oil combined and 7% Other NGLs). Fourth quarter 2024 sales volumes are expected to average between 109,000 Boe/d and 121,000 Boe/d (52% shale gas and conventional natural gas combined, 41% condensate, light and medium crude oil, tight oil and heavy crude oil combined and 7% Other NGLs).

SPECIFIED FINANCIAL MEASURES

Non-GAAP Financial Measures

Netback and netback including risk management contract settlements are non-GAAP financial measures.  These measures are not standardized measures under IFRS and might not be comparable to similar financial measures presented by other issuers.  These measures should not be considered in isolation or construed as alternatives to their most directly comparable measure disclosed in the Company's primary financial statements or other measures of financial performance calculated in accordance with IFRS.

Netback equals petroleum and natural gas sales (the most directly comparable measure disclosed in the Company's primary financial statements) plus sales of commodities purchased less royalties, operating expense, transportation and NGLs processing expense and commodities purchased.  Sales of commodities purchased and commodities purchased are treated as corporate items and are not allocated to individual regions or properties.  Netback is used by investors and management to compare the performance of the Company's producing assets between periods.

Netback including risk management contract settlements equals netback after including (or deducting) risk management contract settlements received (paid). Netback including risk management contract settlements is used by investors and management to assess the performance of the producing assets after incorporating management's risk management strategies.

Refer to the table under the heading "Financial and Operating Results" in this press release for the calculation of netback and netback including risk management contract settlements for the three months ended June 30, 2024, March 31, 2024 and June 30, 2023.

Non-GAAP Ratios

Netback and netback including risk management contract settlements presented on a $/Boe basis are non-GAAP ratios as they each have a non-GAAP financial measure as a component.  These measures are not standardized measures under IFRS and might not be comparable to similar financial measures presented by other issuers.  These measures should not be considered in isolation or construed as alternatives to their most directly comparable measure disclosed in the Company's primary financial statements or other measures of financial performance calculated in accordance with IFRS.

Netback on a $/Boe basis is calculated by dividing netback (a non-GAAP financial measure) for the applicable period by the total sales volumes during the period in Boe.  Netback including risk management contract settlements on a $/Boe basis is calculated by dividing netback including risk management contract settlements (a non-GAAP financial measure) for the applicable period by the total sales volumes during the period in Boe.  These measures are used by investors and management to assess netback and netback including risk management contract settlements on a unit of sales volumes basis.

Capital Management Measures

Adjusted funds flow, free cash flow and net (cash) debt are capital management measures that Paramount utilizes in managing its capital structure. These measures are not standardized measures and therefore may not be comparable with the calculation of similar measures by other entities.  Refer to Note 15 in the Interim Consolidated Financial Statements of Paramount as at and for the three and six months ended June 30, 2024 for: (i) a description of the composition and use of these measures, (ii) reconciliations of adjusted funds flow and free cash flow to cash from operating activities, the most directly comparable measure disclosed in the Company's primary financial statements, for the three and six months ended June 30, 2024 and 2023 and (iii) a calculation of net (cash) debt as at June 30, 2024 and December 31, 2023.

Supplementary Financial Measures

This press release contains supplementary financial measures expressed as: (i) cash from operating activities, adjusted funds flow and free cash flow on a per share – basic and per share – diluted basis and (ii) petroleum and natural gas sales, revenue, royalties, operating expenses, transportation and NGLs processing expenses, sales of commodities purchased and commodities purchased on a $/Boe or $/Mcf basis.

Cash from operating activities, adjusted funds flow and free cash flow on a per share – basic basis are calculated by dividing cash from operating activities, adjusted funds flow or free cash flow, as applicable, over the referenced period by the weighted average basic shares outstanding during the period determined under IFRS.  Cash from operating activities, adjusted funds flow and free cash flow on a per share – diluted basis are calculated by dividing cash from operating activities, adjusted funds flow or free cash flow, as applicable, over the referenced period by the weighted average diluted shares outstanding during the period determined under IFRS.

Petroleum and natural gas sales, revenue, royalties, operating expenses, transportation and NGLs processing expenses, sales of commodities purchased and commodities purchased on a $/Boe or $/Mcf basis are calculated by dividing petroleum and natural gas sales, revenue, royalties, operating expenses, transportation and NGLs processing expenses, sales of commodities purchased and commodities purchased, as applicable, over the referenced period by the aggregate units (Boe or Mcf) of sales volumes during such period.

ADVISORIES

Forward-looking Information

Certain statements in this press release constitute forward-looking information under applicable securities legislation.  Forward-looking information typically contains statements with words such as "anticipate", "believe", "estimate", "will", "expect", "plan", "schedule", "intend", "propose", or similar words suggesting future outcomes or an outlook.  Forward-looking information in this press release includes, but is not limited to:

• forecast sales volumes for 2024 and certain periods therein;

• planned capital expenditures in 2024 and the allocation thereof between sustaining and maintenance capital and growth capital;

• planned abandonment and reclamation expenditures in 2024;

• forecast free cash flow in 2024;

• planned exploration, development and production activities, including: (i) the expected timing of drilling, completing and bringing new wells on production; (ii) planned well optimizations and the anticipated impact thereof; (iii) the expected timing of completion of planned facilities, including a new natural gas processing facility at Willesden Green, (iv) a planned outage at the Wapiti natural gas processing plant and (iv) the expected timing of bringing shut-in natural gas production back on; and

• the potential payment of future dividends.

Such forward-looking information is based on a number of assumptions which may prove to be incorrect. Assumptions have been made with respect to the following matters, in addition to any other assumptions identified in this press release:

• future commodity prices;

• the impact of international conflicts, including in Ukraine and the Middle East;

• royalty rates, taxes and capital, operating, general & administrative and other costs;

• foreign currency exchange rates, interest rates and the rate and impacts of inflation;

• general business, economic and market conditions;

• the performance of wells and facilities;

• the availability to Paramount of the funds required for exploration, development and other operations and the meeting of commitments and financial obligations;

• the ability of Paramount to obtain equipment, materials, services and personnel in a timely manner and at expected and acceptable costs to carry out its activities;

• the ability of Paramount to secure adequate processing, transportation, fractionation, disposal and storage capacity on acceptable terms and the capacity and reliability of facilities;

• the ability of Paramount to obtain the volumes of water required for completion activities;

• the ability of Paramount to market its production successfully;

• the ability of Paramount and its industry partners to obtain drilling success (including in respect of anticipated sales volumes, reserves additions, product yields and product recoveries) and operational improvements, efficiencies and results consistent with expectations;

• the timely receipt of required governmental and regulatory approvals;

• the application of regulatory requirements respecting abandonment and reclamation; and

• anticipated timelines and budgets being met in respect of: (i) drilling programs and other operations, including well completions and tie-ins, (ii) the construction, commissioning and start-up of new and expanded third-party and Company facilities, including the new natural gas processing facility at Willesden Green, and (iii) facility turnarounds and maintenance.

Although Paramount believes that the expectations reflected in such forward-looking information are reasonable based on the information available at the time of this press release, undue reliance should not be placed on the forward-looking information as Paramount can give no assurance that such expectations will prove to be correct.  Forward-looking information is based on expectations, estimates and projections that involve a number of risks and uncertainties which could cause actual results to differ materially from those anticipated by Paramount and described in the forward-looking information.  The material risks and uncertainties include, but are not limited to:

• fluctuations in commodity prices;

• changes in capital spending plans and planned exploration and development activities;

• changes in foreign currency exchange rates, interest rates and the rate of inflation;

• the uncertainty of estimates and projections relating to future production, product yields (including condensate to natural gas ratios), revenue, free cash flow, reserves additions, product recoveries, royalty rates, taxes and costs and expenses;

• the ability to secure adequate processing, transportation, fractionation, disposal and storage capacity on acceptable terms;

• operational risks in exploring for, developing, producing and transporting natural gas and liquids, including the risk of spills, leaks or blowouts;

• risks associated with wildfires, including the risk of physical loss or damage to wells, facilities, pipelines and other infrastructure, prolonged disruptions in production, restrictions on the ability to access properties, interruption of electrical and other services and significant delays or changes to planned development activities and facilities maintenance;

• the ability to obtain equipment, materials, services and personnel in a timely manner and at expected and acceptable costs, including the potential effects of inflation and supply chain disruptions;

• potential disruptions, delays or unexpected technical or other difficulties in designing, developing, expanding or operating new, expanded or existing facilities, including third-party facilities and the new natural gas processing facility at Willesden Green;

• processing, transportation, fractionation, disposal and storage outages, disruptions and constraints;

• potential limitations on access to the volumes of water required for completion activities due to drought, conditions of low river flow, government restrictions or other factors;

• risks and uncertainties involving the geology of oil and gas deposits;

• the uncertainty of reserves estimates;

• general business, economic and market conditions;

• the ability to generate sufficient cash from operating activities to fund, or to otherwise finance, planned exploration, development and operational activities and meet current and future commitments and obligations (including asset retirement obligations, processing, transportation, fractionation and similar commitments and obligations);

• changes in, or in the interpretation of, laws, regulations or policies (including environmental laws);

• the ability to obtain required governmental or regulatory approvals in a timely manner, and to obtain and maintain leases and licenses, including those required for the new natural gas processing facility at Willesden Green;

• the effects of weather and other factors including wildlife and environmental restrictions which affect field operations and access;

• uncertainties as to the timing and cost of future abandonment and reclamation obligations and potential liabilities for environmental damage and contamination;

• uncertainties regarding Indigenous claims and in maintaining relationships with local populations and other stakeholders;

• the outcome of existing and potential lawsuits, regulatory actions, audits and assessments; and

• other risks and uncertainties described elsewhere in this document and in Paramount's other filings with Canadian securities authorities.

There are risks that may result in the Company changing, suspending or discontinuing its monthly dividend program, including changes to its free cash flow, operating results, capital requirements, financial position, market conditions or corporate strategy and the need to comply with requirements under debt agreements and applicable laws respecting the declaration and payment of dividends.  There are no assurances as to the continuing declaration and payment of future dividends or the amount or timing of any such dividends.

The foregoing list of risks is not exhaustive. For more information relating to risks, see the section titled "Risk Factors" in Paramount's annual information form for the year ended December 31, 2023, which is available on SEDAR+ at www.sedarplus.ca or on the Company's website at www.paramountres.com.  The forward-looking information contained in this press release is made as of the date hereof and, except as required by applicable securities law, Paramount undertakes no obligation to update publicly or revise any forward-looking statements or information, whether as a result of new information, future events or otherwise.

Certain forward-looking information in this press release, including forecast free cash flow in 2024, may also constitute a "financial outlook" within the meaning of applicable securities laws. A financial outlook involves statements about Paramount's prospective financial performance or position and is based on and subject to the assumptions and risk factors described above in respect of forward-looking information generally as well as any other specific assumptions and risk factors in relation to such financial outlook noted in this press release. Such assumptions are based on management's assessment of the relevant information currently available and any financial outlook included in this press release is provided for the purpose of helping readers understand Paramount's current expectations and plans for the future. Readers are cautioned that reliance on any financial outlook may not be appropriate for other purposes or in other circumstances and that the risk factors described above or other factors may cause actual results to differ materially from any financial outlook.

Oil and Gas Measures and Definitions

This press release contains disclosures expressed as "Boe", "$/Boe" and "Boe/d".  Natural gas equivalency volumes have been derived using the ratio of six thousand cubic feet of natural gas to one barrel of oil when converting natural gas to Boe.  Equivalency measures may be misleading, particularly if used in isolation. A conversion ratio of six thousand cubic feet of natural gas to one barrel of oil is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the well head.  For the six months ended June 30, 2024, the value ratio between crude oil and natural gas was approximately 61:1. This value ratio is significantly different from the energy equivalency ratio of 6:1. Using a 6:1 ratio would be misleading as an indication of value.

This press release refers to "CGR", a metric commonly used in the oil and natural gas industry. "CGR" means condensate to gas ratio and is calculated by dividing wellhead raw liquids volumes by wellhead raw natural gas volumes.   This metric does not have a standardized meaning and may not be comparable to similar measures presented by other companies. As such, it should not be used to make comparisons. Management uses oil and gas metrics for its own performance measurements and to provide shareholders with measures to compare the Company's performance over time; however, such measures are not reliable indicators of the Company's future performance and future performance may not compare to the performance in previous periods and therefore should not be unduly relied upon.

Additional information respecting the Company's oil and gas properties and operations is provided in the Company's annual information form for the year ended December 31, 2023 which is available on SEDAR+ at www.sedarplus.ca or on Paramount's website at www.paramountres.com.

SOURCE Paramount Resources Ltd.

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