Brigham Minerals, Inc. Reports Record Second Quarter 2022 Operational and Financial Results and Provides Updated 2022 Guidance

Brigham Minerals, Inc. (NYSE: MNRL) (“Brigham Minerals,” “Brigham,” or the “Company”), a leading mineral and royalty interest acquisition company, today announced record operational and financial results for the quarter ended June 30, 2022 and updated full year 2022 guidance.

RECORD SECOND QUARTER 2022 OPERATIONAL AND FINANCIAL HIGHLIGHTS

• Record daily production volumes of 13,019 Boe/d (72% liquids, 52% oil)
  • Production up 8% sequentially from Q1 2022 including a 24% increase in Permian Basin volumes

• Record royalty revenues of $90.4 million
  • Up 29% sequentially from Q1 2022 driven by 8% higher volumes and 18% higher realized prices

• Record Net income totaling $50.2 million
  • Record Adjusted EBITDA⁽¹⁾ totaling $79.7 million up 31% sequentially from Q1 2022

• Declared record Q2 2022 dividend of $0.77 per share of Class A common stock⁽²⁾
  • Base Dividend of $0.16 per share of Class A common stock
  • Variable Dividend increased 39% sequentially to $0.61 per share of Class A common stock
  • Represents 75% payout ratio of Discretionary Cash Flow ex lease bonus⁽¹⁾

• 11.0 net (1,792 gross) activity wells comprised of 6.8 net (1,008 gross) DUCs and 4.2 net (784 gross) permits
  • 2.4 net DUCs converted to PDP during Q2 2022
  • Record 253 gross wells spud during Q2 2022 (1.5 net locations)
  • Permian Basin activity wells totaling 6.7 net locations

• Generated divestiture proceeds totaling $67.3 million from the sale of undeveloped Anadarko Basin assets
  • Divested largely undeveloped minerals with anticipated Q3 2022 production of 200 Boe/d
  • Asset monetization proceeds partially utilized to fund accretive Permian Basin acquisitions and reduce Net Debt⁽¹⁾ to approximately $49 million as of June 30, 2022
  • Permian Basin now makes up 48% of net royalty acres and 68% of net locations

• Acquired 885 net royalty acres deploying $33.2 million in mineral acquisition capital
  • 100% of capital deployed to Permian Basin comprised of 95% PDP, DUC and permitted net locations with anticipated Q3 2022 production of 400 Boe/d
  • Locations to be converted by top tier operators including Endeavor Energy Resources, Chevron Corporation and Marathon Oil

• $24.1 million cash balance and undrawn revolver capacity of $217.0 million as of June 30, 2022
  • Conservative leverage at 0.2x last quarter annualized Adjusted EBITDA⁽¹⁾

FULL YEAR 2022 UPDATED GUIDANCE

• Updated full year 2022 production guidance of 12,300 to 13,000 Boe/d
  • Production guidance raised 9% at the midpoint relative to February 2022 guidance
• Mineral acquisition capital raised to $100 to $120 million
  • Includes impact of highly accretive Permian Basin acquisitions entered into during the first half 2022
• See additional detail in Operational and Financial Guidance Update table below

Robert M. (“Rob”) Roosa, Chief Executive Officer, commented, “Our team once again generated record operational and financial results during the quarter including record production, revenue, EBITDA⁽¹⁾ and dividends. Our production volumes increased 8% sequentially to a record 13,019 Boe/d driven by continued strong DUC conversions, particularly conversions in the Permian Basin where production volumes grew by 24% sequentially. We also saw record drilling activity during the quarter with approximately 253 gross wells spud on our assets, and when combined with our acquisition efforts, we were able to maintain an almost constant DUC inventory level even with the aforementioned strong conversions. In total, we ended the second quarter with 11.0 net activity wells in inventory and anticipate our production volumes for the full year 2022 to average between 12,300 and 13,000 Boe/d, which represents a 9% increase relative to our original guidance provided in February.”

Blake C. Williams, Chief Financial Officer, added, “Our results continue to excel and highlight the benefits of our high margin business model especially in the current inflationary environment. Our EBITDA⁽¹⁾ grew 31% sequentially and is up 159% year over year, leading to our $0.77 dividend at a 75% payout ratio. While many companies are seeing higher cost, we instead saw an increased EBITDA margin⁽¹⁾ due to our unhedged price realizations and largely fixed cost structure. Our team also took advantage of the supportive commodity price environment by successfully executing our largest, single asset monetization to date generating proceeds of approximately $67.3 million. The proceeds, along with our retained cash flow, were utilized to fully fund our second quarter ground game acquisitions as well as reduce our Net Debt⁽¹⁾ outstanding at the end of the quarter to approximately $49 million. With over $200 million of available liquidity, we plan to continue creating value for our shareholders through accretive acquisitions and our current and future return of capital program.”

OPERATIONAL UPDATE

Mineral and Royalty Interest Ownership Update

During the second quarter 2022, the Company executed twenty transactions acquiring approximately 885 net royalty acres (standardized to a 1/8th royalty interest) and deployed $33.2 million in capital. The Company deployed all of its mineral acquisition capital in the second quarter to the Permian Basin. Second quarter acquisitions are expected to deliver near-term production and cash flow growth with the addition of 116 gross DUCs (0.8 net) and 27 gross permits (0.2 net) to inventory counts. The Company also divested 12,550 net royalty acres in the Anadarko Basin generating approximately $67.3 million in cash proceeds, net of customary closing adjustments.

The table below summarizes the Company’s approximate mineral and royalty interest ownership as of the dates indicated.

DUC Conversions Updates

During the second quarter 2022, the Company identified approximately 223 gross (2.4 net) horizontal wells converted to production, which represented 33% of its net DUC inventory as of the first quarter 2022 (24% of gross DUCs). Well conversions to proved developed producing during second quarter are summarized in the table below:

Drilling Activity Update

During the second quarter 2022, the Company identified a record 253 gross (1.5 net) wells spud on its mineral position, which represents a 6% sequential increase from the first quarter 2022 on a gross well basis. Brigham’s average quarterly gross and net wells spud over 2019 to 2021 relative to the second quarter 2022 are summarized in the table below:

DUC and Permit Inventory Update

The Company expects 2022 production volumes will be driven by the continued conversion of its DUC and permit inventory. Brigham’s gross and net DUC and permit inventory as of June 30, 2022 by basin is outlined in the table below:

FINANCIAL UPDATE

For the three months ended June 30, 2022, crude oil, natural gas and NGL production volumes increased 8% to 13,019 Boe/d as compared to the three months ended March 31, 2022 and increased 45% as compared to the same prior-year period.

For the three months ended June 30, 2022, average realized prices were $108.37 per barrel of oil, $6.95 per Mcf of natural gas, and $42.31 per barrel of NGL, for a total equivalent price of $76.31 per Boe. This represents a 18% increase relative to the three months ended March 31, 2022 and a 69% increase relative to the same prior-year period.

The Company's net income for the three months ended June 30, 2022 was $50.2 million, up 28% from the three months ended March 31, 2022 and up 227% relative to the same prior-year period.

Adjusted EBITDA was $79.7 million for the three months ended June 30, 2022, up 31% from the three months ended March 31, 2022 and up 159% relative to the same prior-year period. Adjusted EBITDA ex lease bonus was $79.2 million for the three months ended June 30, 2022, up 34% from the three months ended March 31, 2022 and up 164% from the same prior-year period. Adjusted EBITDA and Adjusted EBITDA ex lease bonus are Non-GAAP financial measures. For a definition of Adjusted EBITDA and Adjusted EBITDA ex lease bonus and a reconciliation to our most directly comparable measure calculated and presented in accordance with GAAP, please read "Non-GAAP Financial Measures” below.

As of June 30, 2022, the Company had a cash balance of $24.1 million and $217.0 million of undrawn revolver capacity under its credit facility, providing the Company with total liquidity of $241.1 million.

Quarterly Cash Dividend

The Company’s Board of Directors (the “Board”) has declared a quarterly cash dividend incorporating results for the second quarter 2022 of $0.77 per share of Class A common stock at a 75% payout ratio. This represents a 28% increase in payout compared to the dividend declared for the first quarter of 2022. The second quarter dividend represents a base dividend of $0.16 per share and a variable dividend of $0.61 per share and will be paid on August 26, 2022 to holders of record as of August 19, 2022. An amount equal to the cash dividend per share will also be set aside for each outstanding award granted under the long-term incentive plan for payment upon the vesting of such awards in accordance with their terms.

Future declarations of dividends are subject to approval by the Board and to the Board’s continuing determination that the declarations of dividends are in the best interests of the Company and its shareholders. Future dividends may be adjusted at the Board’s discretion based on market conditions and capital availability.

OPERATIONAL AND FINANCIAL GUIDANCE UPDATE

Below is Brigham's updated guidance for the full year 2022:

Brigham Minerals Second Quarter 2022 Earnings Conference Call

• Friday, August 5, 2022 at 9:00 a.m. Eastern Time (8:00 a.m. Central Time)
• Pre-register by visiting: https://ige.netroadshow.com/registration/q4inc/11359/brigham-minerals-second-quarter-2022-earnings-conference-call/
• Listen to a live audio webcast of the call by visiting the Company’s website
  • https://investors.brighamminerals.com
• A recording of the webcast will be available on the Company’s website after the call

Non-GAAP Financial Measures

Adjusted EBITDA, Adjusted EBITDA ex lease bonus, Adjusted EBITDA Margin, Discretionary Cash Flow, Discretionary Cash Flow ex lease bonus, and Net Debt are non-GAAP supplemental financial measures used by our management and by external users of our financial statements such as investors, research analysts and others to assess the financial performance of our assets and their ability to sustain dividends over the long term without regard to financing methods, capital structure or historical cost basis.

We define Adjusted EBITDA as Net Income before depreciation, depletion and amortization, share-based compensation expense, interest expense, and income tax expense, less other income. We define Adjusted EBITDA ex lease bonus as Adjusted EBITDA further adjusted to eliminate the impacts of lease bonus and other revenues we receive due to the unpredictability of timing of the revenue. We define Adjusted EBITDA Margin as Adjusted EBITDA divided by total revenue. We define Discretionary Cash Flow as Adjusted EBITDA, less cash interest expense and cash taxes. We define Discretionary Cash Flow ex lease bonus as Discretionary Cash Flow further adjusted to eliminate the impacts of lease bonus revenue. We define Net Debt as total debt less cash and cash equivalents.

Adjusted EBITDA, Adjusted EBITDA ex lease bonus, Adjusted EBITDA Margin, Discretionary Cash Flow, Discretionary Cash Flow ex lease bonus, and Net Debt do not represent and should not be considered alternatives to, or more meaningful than, net income or any other measure of financial performance presented in accordance with GAAP as measures of our financial performance. Adjusted EBITDA, Adjusted EBITDA ex lease bonus, Adjusted EBITDA Margin, Discretionary Cash Flow and Discretionary Cash Flow ex lease bonus have important limitations as analytical tools because they exclude some but not all items that affect net income, the most directly comparable GAAP financial measure. Net Debt should not be considered an alternative to, or more meaningful than, total debt, the most directly comparable GAAP measure. Our computation of Adjusted EBITDA, Adjusted EBITDA ex lease bonus, Adjusted EBITDA Margin, Discretionary Cash Flow, Discretionary Cash Flow ex lease bonus, and Net Debt may differ from computations of similarly titled measures of other companies.

The following tables present a reconciliation of Adjusted EBITDA, Adjusted EBITDA ex lease bonus, Adjusted EBITDA Margin, Discretionary Cash Flow, Discretionary Cash Flow ex lease bonus, and Net Debt to the most directly comparable GAAP financial measure for the periods indicated.

ABOUT BRIGHAM MINERALS, INC.

Brigham Minerals is an Austin, Texas, based company that acquires and actively manages a portfolio of mineral and royalty interests in the core of some of the most active, highly economic, liquids-rich resource basins across the continental United States. Brigham Minerals’ assets are located in the Delaware and Midland Basins in West Texas and New Mexico, the Anadarko Basin of Oklahoma, the DJ Basin in Colorado and Wyoming, and the Williston Basin in North Dakota. The Company’s primary business objective is to maximize risk-adjusted total return to its shareholders by both capturing organic growth in its existing assets as well as leveraging its highly experienced technical evaluation team to continue acquiring minerals.

Cautionary Statement Concerning Forward-Looking Statements

This press release contains forward-looking statements. All statements, other than statements of historical facts, included in this press release that address activities, events or developments that the Company expects, believes or anticipates will or may occur in the future are forward-looking statements. Without limiting the generality of the foregoing, forward-looking statements contained in this press release specifically include the expectations of plans, strategies, objectives and anticipated financial and operating results of the Company, including production and other guidance within this press release. These statements are based on certain assumptions made by the Company based on management’s experience and perception of historical trends, current conditions, anticipated future developments and other factors believed to be appropriate. Such statements are subject to a number of assumptions, risks and uncertainties, many of which are beyond the control of the Company, which may cause actual results to differ materially from those implied or expressed by the forward-looking statements. These include, but are not limited to, operator capital discipline and inflation impacts on their cash flows, the Company’s ability to integrate acquisitions into its existing business, changes in oil, natural gas and NGL prices, weather and environmental conditions, the timing of planned capital expenditures, availability of and competition for acquisitions, operational factors affecting the commencement or maintenance of producing wells on the Company’s properties, the condition of the capital markets generally, as well as the Company’s ability to access them, economic and competitive conditions, including those resulting from the current conflict between Russia and Ukraine and elevated inflation levels resulting from global supply and demand imbalances, the proximity to and capacity of transportation, uncertainties regarding environmental regulations or litigation, global or national health events, including the ongoing spread and economic effects of the ongoing COVID-19 pandemic, potential future pandemics, the actions of the Organization of Petroleum Exporting Countries and other significant producers and governments and the ability of such producers to agree to and maintain oil price and production controls and other legal or regulatory developments affecting the Company’s business and other important factors. These and other applicable uncertainties, factors and risks are described more fully in the Company's filings with the Securities and Exchange Commission, including its Annual Report on Form 10-K for the year ended December 31, 2021, and any subsequently filed Quarterly Reports on Form 10-Q and Current Reports on Form 8-K. Should one or more of these risks or uncertainties occur, or should underlying assumptions prove incorrect, the Company’s actual results and plans could differ materially from those expressed in any forward-looking statements.

Any forward-looking statement speaks only as of the date on which such statement is made and the Company undertakes no obligation to correct or update any forward-looking statement, whether as a result of new information, future events or otherwise except as required by applicable law.

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