MNRL - Brigham Minerals Inc. Reports Record Fourth Quarter and Full Year 2021 Operational and Financial Results Recent Developments and Provides 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 and year-ended December 31, 2021, recent developments and provides 2022 guidance.

FOURTH QUARTER 2021 OPERATIONAL AND FINANCIAL HIGHLIGHTS

• Daily production volumes of 9,170 Boe/d (71% liquids, 51% oil)
  • Production up 1% sequentially from Q3 2021

• Record royalty revenues totaling $47.0 million
  • Up 16% sequentially from Q3 2021 driven by 15% higher realized prices and 1% higher volumes

• Continued cost control efforts drive general and administrative costs (before share based compensation) below revised 2021 guidance
  • Full year 2021 general and administrative costs 5% below revised 2021 guidance and 17% below initial 2021 guidance

• Record net income totaling $21.7 million
  • Record Adjusted EBITDA ⁽¹⁾ totaling $39.6 million up 13% sequentially from Q3 2021

• Declared Q4 2021 dividend of $0.45 per share of Class A common stock ⁽²⁾
  • Base Dividend of $0.14 per share of Class A common stock
  • Variable Dividend increased 19% sequentially to $0.31 per share of Class A common stock
  • Represents 80% payout of Discretionary Cash Flow ex lease bonus ⁽¹⁾

• Record 12.9 net (1,723 gross) activity wells at year-end comprised of 7.4 net (850 gross) DUCs and 5.5 net (873 gross) permits
  • 24% sequential increase in net DUCs to 7.4 net locations and 31% sequential increase in net permits to 5.5 net locations
  • Permian Basin net activity wells increased to a record 7.2 net locations
  • 24.5 net activity wells in inventory at year-end normalized to 5,000’ laterals

• Acquired 8,855 net royalty acres deploying $104 million in mineral acquisition capital
  • Closed DJ Basin acquisition totaling 8,395 net royalty acres that is estimated to add 1,100 to 1,200 Boe/d to 2022 production (50% liquids)
  • Deployed $9.8 million in ground game acquisition capital adding 460 net royalty acres (93% to the Permian Basin)
    • 46% of acquired net locations comprised of PDP, DUCs and permits
    • Ground game acquisitions entirely funded via portfolio rationalization and retained cash

• Undrawn revolver capacity of $137.0 million and $20.8 million cash balance as of December 31, 2021
  • Conservative leverage at 0.5x last quarter annualized Adjusted EBITDA ⁽¹⁾

RECENT DEVELOPMENTS

• Subsequent to year-end, continued portfolio optimization with divestiture of $7.1 million
  • Divested undeveloped Anadarko Basin Merge minerals with estimated 2022 production totaling 40 Boe/d

• Significant 2022 acquisition momentum with entry into $32 million Midland Basin acquisition with Echo Minerals
  • Acquiring approximately 1,800 net royalty acres with 2022 production totaling approximately 225 - 275 Boe/d
  • Anticipated to be developed by Pioneer Natural Resources and Endeavor Energy Resources with 0.4 net activity wells
  • Transaction expected to close in early-to-mid April 2022, subject to continued diligence and satisfaction of customary closing conditions

2022 GUIDANCE

• Anticipate increasing Quarterly Base Dividend 14% to $0.16 per share ($0.64 per share annualized) beginning with Q1 2022 Dividend ⁽²⁾
  • Accretive acquisitions and continued growth in PDP reserves per share underpins strong and sustainable cash flow profile
  • Continue to target 75 - 80% total payout ratio inclusive of Base plus Variable Dividend

• Full Year 2022 production guidance of 11,300 to 12,000 Boe/d driving year-over-year production growth of greater than 25%
  • Anchored by current producing locations, record activity wells and anticipated 2022 ground game acquisitions
  • See additional detail in 2022 Guidance table below

Robert M. (“Rob”) Roosa, Chief Executive Officer, commented, “We are entering 2022 from a position of strength with a record 12.9 net activity wells in inventory, significant accretive ground game acquisition momentum and continued portfolio optimization. Our record activity well inventory is being driven by both organic development on our assets with over 200 gross wells spud on our minerals during the fourth quarter as well as our technical team executing on our accretive acquisition thesis, which added 2.8 net activity wells to inventory during the quarter. Importantly, our acquisition momentum has continued to carry over into the first quarter of 2022 with our entry into our largest Midland Basin deal to date. This transaction is anticipated to add approximately 250 Boe/d of production in 2022 as well as to continue to provide organic development from large, highly active operators including Pioneer and Endeavor. In total, our team has executed over $135 million in acquisitions since the beginning of Q4 2021 that, when combined with the steady PDP growth on our assets, is anticipated to allow us to increase our Quarterly Base Dividend in 2022 by 14% to $0.16 per share ⁽²⁾ . Finally, we have continued to execute on our portfolio optimization efforts and subsequent to year-end divested $7.1 million in Anadarko Basin Merge minerals, which will provide us incremental capital to redeploy to the Permian.”

Blake C. Williams, Chief Financial Officer, added, “Through our disciplined underwriting process, we’ve prudently deployed capital to high return assets across our operating areas. As a result of our diligence and patience, we were able to capitalize on recent opportunities and remain well positioned to aggressively consolidate the mineral space in 2022. Further, our active portfolio management resulted in divesting largely undeveloped Oklahoma assets, while acquiring core Midland assets for 6x 2022E EBITDA ⁽¹⁾ , and allows us to continue to manage our net debt levels. We will continue to high grade our portfolio and will do so whenever we find opportunities to generate proceeds in excess of our internal view of value in order to redeploy the capital into higher return assets. Lastly, our significant improvements in cost structure have generated an anticipated year over year reduction in G&A per boe of roughly 17%, which underscores our ability to further leverage the platform we have built to optimize consolidation of the broader minerals space.”

OPERATIONAL UPDATE

Mineral and Royalty Interest Ownership Update

During the three months ended December 31, 2021, the Company executed 15 ground game acquisition transactions acquiring approximately 460 net royalty acres (standardized to a 1/8th royalty interest) and deployed $9.8 million in capital. The Company focused approximately 93% of its ground game mineral acquisition capital in the fourth quarter on the Permian Basin. In addition, we closed the previously announced DJ Basin asset acquisition for $43.1 million in cash and 2.2 million shares of our Class A common stock. Together, these recent acquisitions are expected to deliver near-term production and cash flow growth with the addition of 138 gross DUCs (1.6 net DUCs) and 134 gross permits (1.2 net permits) to inventory counts.

As of December 31, 2021, the Company had acquired roughly 92,375 net royalty acres, encompassing 13,093 gross (109.4 net) undeveloped horizontal locations, across 36 counties in what the Company views as the core of the Permian Basin in West Texas and New Mexico, the SCOOP/STACK plays in the Anadarko Basin of Oklahoma, the DJ Basin in Colorado and Wyoming and the Williston Basin in North Dakota.

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

DUC Conversions Updates

During the fourth quarter 2021, the Company identified approximately 178 gross (1.0 net) horizontal wells converted to production, which represented 24% of its gross DUC inventory as of the third quarter 2021 (18% of net DUCs). Well conversions to proved developed producing during the fourth quarter are summarized in the table below:

Drilling Activity Update

During the fourth quarter 2021, 202 gross (1.0 net) wells were spud on the Company's mineral position, which represents a 20% sequential increase in gross wells spud from the third quarter 2021. Brigham’s quarterly gross and net wells spud since 2019 are summarized in the table below:

DUC and Permit Inventory Update

The Company expects 2022 production growth to be driven by the continued conversion of its record DUC and permit inventory. Brigham’s gross and net DUC and permit inventory as of December 31, 2021 by basin is outlined in the table below:

FINANCIAL UPDATE

Fourth Quarter 2021 Financial Update

For the three months ended December 31, 2021, crude oil, natural gas and NGL production volumes increased 1% to 9,170 Boe/d (71% liquids) as compared to third quarter 2021. Our volumes are 2% lower than the same prior year period, largely due to divestitures in the Anadarko and Extended Woodford Basins, which were partially offset by a 2% increase in Permian Basin volumes and a 21% increase in DJ Basin volumes.

Fourth quarter 2021 average realized prices were $75.87 per barrel of oil, $5.28 per Mcf of natural gas, and $38.92 per barrel of NGL, for a total equivalent price of $55.76 per Boe. This represents a 15% increase relative to third quarter 2021 and is 102% higher than the same prior year period level of $27.59 per Boe.

The Company’s net income was $21.7 million for the three months ended December 31, 2021. Adjusted EBITDA was $39.6 million for the three months ended December 31, 2021, up 13% from the third quarter 2021 and up 130% from the same prior-year period. Adjusted EBITDA ex lease bonus was $38.9 million for the three months ended December 31, 2021, up 17% from the third quarter 2021 and up 126% from the prior year. 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.

Full Year 2021 Financial Update

For the year ended December 31, 2021, crude oil, natural gas and NGL production volumes decreased 5% to 9,040 Boe/d (70% liquids) as compared to the prior year, due to a 15% decrease in non-Permian Basin volumes which was partially offset by a 3% increase in Permian Basin volumes.

Full year 2021 average realized prices were $66.08 per barrel of oil, $4.60 per Mcf of natural gas, and $29.35 per barrel of NGL, for a total equivalent price of $47.49 per Boe. This represents a 91% increase relative to 2020 realized prices of $24.85 per Boe.

The Company’s net income was $68.0 million for the year ended December 31, 2021. Adjusted EBITDA was $132.3 million for the year ended December 31, 2021, up 103% from the prior year. Adjusted EBITDA ex lease bonus was $127.8 million for the year ended December 31, 2021, up 115% from the prior year. 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 December 31, 2021, the Company had a cash balance of $20.8 million and $137 million of capacity on its revolving credit facility, providing the Company with total liquidity of $157.8 million.

Fourth Quarter and Full Year 2021 Financial and Operational Results

QUARTERLY CASH DIVIDEND

The Company’s Board of Directors (the “Board”) has declared a quarterly cash dividend for the fourth quarter 2021 of $0.45 per share of Class A common stock, to be paid on March 25, 2022 to holders of record as of March 18, 2022. This brings total capital returned through dividends to shareholders of $1.52 per share based on financial results for the full year 2021.

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 stockholders. Future dividends may be adjusted at the Board’s discretion based on market conditions and capital availability.

2022 OPERATIONAL AND FINANCIAL GUIDANCE

BRIGHAM MINERALS FOURTH QUARTER 2021 EARNINGS CONFERENCE CALL

• Thursday, February 24, 2022 at 10:00 a.m. Eastern Time (9:00 a.m. Central Time)
• Pre-register by visiting https://event.on24.com/wcc/r/3575898/534D3989CED563DBCBC52CBB08EDC36E
• 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

Additionally, Brigham Minerals plans to participate in the following events and conferences

• February 28-March 2, 2022: Credit Suisse Energy Summit
• March 21-23, 2022: Simmons Energy Conference

NON-GAAP FINANCIAL MEASURES

Adjusted Net Income, Adjusted EBITDA, Adjusted EBITDA ex lease bonus, Discretionary Cash Flow and Discretionary Cash Flow ex lease bonus 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 Net Income as net income (loss) before impairment of oil and gas properties, after tax, and loss on extinguishment of debt, after tax. We define Adjusted EBITDA as Adjusted Net Income before depreciation, depletion and amortization, share based compensation expense, interest expense, gain or loss on derivative instruments 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 and magnitude of the 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.

Adjusted Net Income, Adjusted EBITDA, Adjusted EBITDA ex lease bonus, Discretionary Cash Flow, and Discretionary Cash Flow ex lease bonus do not represent and should not be considered alternatives to, or more meaningful than, net income, income from operations, cash flows from operating activities or any other measure of financial performance presented in accordance with GAAP as measures of our financial performance. Adjusted Net Income, Adjusted EBITDA, Adjusted EBITDA ex lease bonus, 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. Our computation of Adjusted Net Income, Adjusted EBITDA, Adjusted EBITDA ex lease bonus, Discretionary Cash Flow, and Discretionary Cash Flow ex lease bonus may differ from computations of similarly titled measures of other companies.

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

SUPPLEMENTAL SCHEDULES

Reconciliation of Adjusted Net Income, Adjusted EBITDA and Adjusted EBITDA ex lease bonus

Reconciliation of Discretionary Cash Flow and Discretionary Cash Flow ex lease bonus

Common Stock Outstanding as of December 31, 2021:

CONSOLIDATED BALANCE SHEETS

CONSOLIDATED AND COMBINED STATEMENT OF OPERATIONS