# Granite Ridge Resources, Inc. (GRNT) Informational only - not investment advice. CIK: 0001928446 SIC: 1311 Crude Petroleum & Natural Gas SIC breadcrumb: [Mining](/division/B/) > [SIC Major Group 13](/major-group/13/) > [SIC 1311 Crude Petroleum & Natural Gas](/industry/1311/) Latest 10-K filed: 2026-03-06 SEC page: https://www.sec.gov/edgar/browse/?CIK=1928446 Filing source: https://www.sec.gov/Archives/edgar/data/1928446/000192844626000007/grnt-20251231.htm ## At a glance FY2025 · period end 2025-12-31 · filed 2026-03-06 · accession 0001928446-26-000007 · source: https://data.sec.gov/api/xbrl/companyfacts/CIK0001928446.json | Metric | Value | FY | Provenance | | --- | ---: | ---: | --- | | Revenue | 450,306,000 USD | 2025 | verified | | Net income | 24,353,000 USD | 2025 | verified | | Assets | 1,168,071,000 USD | 2025 | verified | | Net margin | 5.41% | 2025 | computed | | Operating margin | 10.31% | 2025 | computed | | Revenue YoY | +18.49% | 2025 | computed | | ROE | 4.02% | 2025 | computed | Computed values are grepcent-computed from the verified facts above and may differ from ratios the company itself reports. Net margin = net income ÷ revenue. Operating margin = operating income ÷ revenue. Revenue YoY = FY2025 revenue ÷ FY2024 revenue − 1 (consecutive fiscal years only). ROE = net income ÷ period-end stockholders' equity. No market price, no rating, no forecast on this site. Not investment advice. ### Peer percentile fingerprint | Ratio | GRNT | Peer median | Percentile | N | | --- | ---: | ---: | ---: | ---: | | Net margin | 5.4% | 11.9% | 39 | 42 | | Operating margin | 10.3% | 11.9% | 46 | 36 | | Revenue growth | 18.5% | 12.2% | 59 | 42 | | ROE | 4.0% | 8.9% | 36 | 43 | | ROA | 2.1% | 4.9% | 37 | 44 | | Liabilities / equity | 0.93 | 0.90 | 55 | 43 | | Current ratio | 1.25 | 0.86 | 72 | 44 | Percentile = share of the N covered peers reporting that ratio whose value is lower (ties counted half); computed among grepcent-covered companies in SIC industry 1311 Crude Petroleum & Natural Gas, not the whole market. A higher percentile means a higher value of the ratio, not a better company. Ratios with fewer than 8 reporting peers are omitted. Latest reported values per company; fiscal periods may differ. Descriptive arithmetic - not a score, rating, or ranking. ## Selected Fundamentals | Metric | Value | Unit | FY | Filed | | --- | ---: | --- | ---: | --- | | Revenue | 450306000 | USD | 2025 | 2026-03-06 | | Net income | 24353000 | USD | 2025 | 2026-03-06 | | Assets | 1168071000 | USD | 2025 | 2026-03-06 | ## Financials Annual standardized facts from SEC companyfacts as of latest extracted filing date 2026-03-06. Source: https://data.sec.gov/api/xbrl/companyfacts/CIK0001928446.json. Derived margins, ratios, and free cash flow are computed from the extracted annual SEC facts. | Metric | 2019 | 2020 | 2021 | 2022 | 2023 | 2024 | 2025 | | --- | ---: | ---: | ---: | ---: | ---: | ---: | ---: | | Revenue | | 87,098,000 | 290,193,000 | 497,417,000 | 394,069,000 | 380,030,000 | 450,306,000 | | Net income | | -23,930,000 | 108,459,000 | 262,344,000 | 81,099,000 | 18,759,000 | 24,353,000 | | Operating income | | -35,095,000 | 143,233,000 | 302,145,000 | 90,587,000 | 59,256,000 | 46,420,000 | | Diluted EPS | | -0.18 | 0.82 | 1.97 | 0.61 | 0.14 | 0.18 | | Operating cash flow | | 66,806,000 | 181,181,000 | 346,389,000 | 302,867,000 | 275,733,000 | 296,414,000 | | Dividends paid | | | | 10,664,000 | 58,587,000 | 57,494,000 | 57,686,000 | | Share buybacks | | | 0.00 | 216,000 | 35,353,000 | 442,000 | 16,000 | | Assets | | | 547,246,000 | 794,777,000 | 927,104,000 | 1,036,479,000 | 1,168,071,000 | | Liabilities | | | 72,316,000 | 130,530,000 | 255,459,000 | 401,126,000 | 562,311,000 | | Stockholders' equity | 324,369,000 | 370,556,000 | 474,930,000 | 664,247,000 | 671,645,000 | 635,353,000 | 605,760,000 | ### Ratios ROE and ROA use period-end equity/assets. Liabilities / equity uses total liabilities divided by stockholders' equity. Current ratio uses current assets divided by current liabilities when both are reported. | Metric | 2019 | 2020 | 2021 | 2022 | 2023 | 2024 | 2025 | | --- | ---: | ---: | ---: | ---: | ---: | ---: | ---: | | Net margin | | -27.47% | 37.37% | 52.74% | 20.58% | 4.94% | 5.41% | | Operating margin | | -40.29% | 49.36% | 60.74% | 22.99% | 15.59% | 10.31% | | Return on equity | | -6.46% | 22.84% | 39.49% | 12.07% | 2.95% | 4.02% | | Return on assets | | | 19.82% | 33.01% | 8.75% | 1.81% | 2.08% | | Liabilities / equity | | | 0.15 | 0.20 | 0.38 | 0.63 | 0.93 | | Current ratio | | | 1.45 | 2.28 | 2.44 | 1.33 | 1.25 | ## As-reported value updates 2 tracked differences above grepcent's stated thresholds were found between the earliest XBRL-filed value and the value currently on file for the same fiscal period. Ledger: /company/GRNT/revisions/ ## Quarterly Quarterly standardized facts from SEC companyfacts as of latest extracted filing date 2026-08-06. Source: https://data.sec.gov/api/xbrl/companyfacts/CIK0001928446.json. Flow metrics use discrete quarter-length periods from 10-Q/10-Q/A filings. Q4 revenue and net income are derived only when annual FY and nine-month YTD facts exist for the same fiscal year; derived Q4 values are labeled. EPS Q4 is not derived. | Quarter | End date | Revenue | Net income | Diluted EPS | Method | | --- | --- | ---: | ---: | ---: | --- | | 2023-Q1 | 2023-03-31 | | | 0.28 | reported discrete quarter | | 2023-Q2 | 2023-06-30 | | | 0.07 | reported discrete quarter | | 2023-Q3 | 2023-09-30 | 108,404,000 | 17,957,000 | 0.13 | reported discrete quarter | | 2023-Q4 | 2023-12-31 | 106,798,000 | 17,539,000 | | derived Q4 = FY annual - nine-month YTD | | 2024-Q1 | 2024-03-31 | 88,996,000 | 16,227,000 | 0.12 | reported discrete quarter | | 2024-Q2 | 2024-06-30 | 90,652,000 | 5,101,000 | 0.04 | reported discrete quarter | | 2024-Q3 | 2024-09-30 | 94,075,000 | 9,054,000 | 0.07 | reported discrete quarter | | 2024-Q4 | 2024-12-31 | 106,307,000 | -11,622,000 | | derived Q4 = FY annual - nine-month YTD | | 2025-Q1 | 2025-03-31 | 122,931,000 | 9,812,000 | 0.07 | reported discrete quarter | | 2025-Q2 | 2025-03-31 | | 9,812,000 | | reported discrete quarter | | 2025-Q2 | 2025-06-30 | 109,219,000 | | 0.19 | reported discrete quarter | | 2025-Q3 | 2025-06-30 | | 25,081,000 | | reported discrete quarter | | 2025-Q3 | 2025-09-30 | 112,671,000 | | 0.11 | reported discrete quarter | | 2025-Q4 | 2025-12-31 | 105,485,000 | -25,063,000 | | derived Q4 = FY annual - nine-month YTD | | 2026-Q1 | 2026-03-31 | 128,264,000 | -47,031,000 | -0.36 | reported discrete quarter | | 2026-Q2 | 2026-03-31 | | -47,031,000 | | reported discrete quarter | | 2026-Q2 | 2026-06-30 | 149,273,000 | | 0.23 | reported discrete quarter | ## Filed narrative (10-K & 10-Q) ## Business Verbatim Item 1 Business section from GRNT's latest 10-K: [/company/GRNT/business/](/company/GRNT/business/). ## Risk Factors Verbatim Item 1A Risk Factors from GRNT's latest 10-K: [/company/GRNT/risk-factors/](/company/GRNT/risk-factors/). ## Latest quarter (10-Q) Latest 10-Q source: https://www.sec.gov/Archives/edgar/data/1928446/000192844626000051/grnt-20260630.htm Extracted structurally from real Item 2 body heading to real Item 3/4 boundary. Confidence: high Filing date: 2026-08-06 Report date: 2026-06-30 Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations The following discussion and analysis of our financial condition and results of operations should be read in conjunction with our unaudited condensed consolidated financial statements and related notes included elsewhere in this Quarterly Report on Form 10-Q. The following discussion contains “forward‑looking statements” reflecting our current expectations, estimates and assumptions concerning events and financial trends that may affect our future operating results or financial position. Actual results and the timing of events may differ materially from those contained in these forward‑looking statements due to a number of factors. Factors that could cause or contribute to such differences include, but are not limited to, market prices for oil and natural gas, capital expenditures, economic and competitive conditions, regulatory changes and other uncertainties, as well as those factors discussed below and elsewhere in this Report. Please read “Cautionary Note Regarding Forward‑Looking Statements.” Also, please read the risk factors and other cautionary statements described under “Part I, Item 1A. Risk Factors” in our Annual Report on Form 10-K for the year ended December 31, 2025 (the "2025 Form 10-K") and elsewhere in this Report. We assume no obligation to update any of these forward‑looking statements, except as required by applicable law. Overview Granite Ridge is a scaled energy company which aims to provide shareholders with exposure similar to energy private equity through operated partnerships and traditional non-operated assets. We own assets in six prolific unconventional basins across the United States. We aim to deliver a diversified portfolio with best-in-class full cycle returns by investing in a large number of high-graded opportunities developed by proven public and private operators. We focus on success as measured by total shareholder returns, which we seek to balance with a low leverage profile. Selected Factors That Affect Our Operating Results Our revenues, cash flows from operations and future growth depend substantially upon: •the timing and success of drilling and production activities by our operating partners; •the prices and the supply and demand for oil and natural gas; •the quantity of oil and natural gas production from the wells in which we participate; •changes in the fair value of the derivative instruments we use to reduce our exposure to fluctuations in the price of oil and natural gas; •our ability to continue to identify and acquire high-quality acreage and drilling opportunities; and •the level of our operating expenses. In addition to the factors that affect companies in our industry generally, the location of substantially all of our acreage in the Eagle Ford, Permian, Bakken, Haynesville, Denver-Julesburg, and Appalachian Basins subjects our operating results to factors specific to these regions. These factors include the potential adverse impact of weather on drilling, production and transportation activities, particularly during the winter and spring months, as well as infrastructure limitations, transportation capacity, regulatory matters, and other factors that may specifically affect one or more of these regions. The price of oil and natural gas can vary depending on the market in which it is sold and the means of transportation used to transport the oil and natural gas to market. The price at which our oil and natural gas production is sold typically reflects either a premium or discount to the NYMEX benchmark price. Thus, our operating results are also affected by changes in the oil and natural gas price differentials between the applicable benchmark and the sales prices we receive for our oil and natural gas production. Our oil price differential to the NYMEX benchmark price during the three months ended June 30, 2026 and 2025 was a discount of $(1.72) per barrel and $(3.16) per barrel, respectively. For the six months ended June 30, 2026 and 2025, our 27 Table of Contents oil price differential to the NYMEX benchmark price was a discount of $(2.32) per barrel and $(3.01) per barrel, respectively. Our natural gas price differential to the average NYMEX price during the three months ended June 30, 2026 and 2025 was a discount of $(1.83) per Mcf and $(0.87) per Mcf, respectively. For the six months ended June 30, 2026 and 2025, our natural gas price differential to the average NYMEX price was a discount of $(1.93) per Mcf and $(0.55) per Mcf, respectively. Market Conditions The price that we receive for the oil and natural gas our operators produce is largely a function of market supply and demand. Because our oil and natural gas revenues are heavily weighted toward oil, we are more significantly impacted by changes in oil prices than by changes in the price of natural gas. Worldwide supply in terms of output, especially production from properties within the United States, the production quota set by OPEC, and the strength of the U.S. dollar can adversely impact oil prices. Historically, commodity prices have been volatile, and we expect that volatility to continue in the future. Although we cannot predict the occurrence of events that may affect future commodity prices, or the degree to which these prices will be affected, the prices for any commodity that we produce will generally approximate current market prices in the geographic region of the production. From time to time, we expect that we may hedge a portion of our commodity price risk to mitigate the impact of price volatility on our business. Prices for various quantities of oil and natural gas that we produce significantly impact our revenues and cash flows. The following table lists average NYMEX spot prices for oil and natural gas for the three and six months ended June 30, 2026 and 2025. [[GREPCENT_TABLE]] [["","Three Months Ended June 30,","","Six Months Ended June 30,"],["","2026","","2025","","2026","","2025"],["Average NYMEX Prices(1)"],["Oil (per Bbl)","$","95.65","","$","64.57","","$","84.29","","$","68.12"],["Natural gas (per Mcf)","$","2.95","","$","3.19","","$","3.81","","$","3.66"],["(1)Based on average NYMEX spot prices."]] [[/GREPCENT_TABLE]] For the three months ended June 30, 2026, the average NYMEX oil pricing was $95.65 per barrel of oil, or 48% higher than the average NYMEX price per barrel for the three months ended June 30, 2025. Our settled derivatives decreased our realized oil price per barrel by $18.28 for the three months ended June 30, 2026 and increased our realized oil price per barrel by $0.49 for the three months ended June 30, 2025. For the three months ended June 30, 2026, our average realized oil price per barrel after reflecting settled derivatives was $75.65 compared to $61.90 for the three months ended June 30, 2025. For the six months ended June 30, 2026, the average NYMEX oil pricing was $84.29 per barrel of oil, or 24% higher than the average NYMEX price per barrel for the six months ended June 30, 2025. Our settled derivatives decreased our realized oil price per barrel by $11.30 for the six months ended June 30, 2026 and increased our realized oil price per barrel by $0.23 for the six months ended June 30, 2025. For the six months ended June 30, 2026, our average realized oil price per barrel after reflecting settled derivatives was $70.67 compared to $65.34 for the six months ended June 30, 2025. For the three months ended June 30, 2026, the average NYMEX natural gas pricing was $2.95 per Mcf, or 8% lower than the average NYMEX price per Mcf for the three months ended June 30, 2025. Our settled derivatives increased our realized natural gas price per Mcf by $0.52 and $0.03 for the three months ended June 30, 2026 and 2025, respectively. For the three months ended June 30, 2026, our average realized natural gas price per Mcf after reflecting settled derivatives was $1.64 compared to $2.35 for the three months ended June 30, 2025. For the six months ended June 30, 2026, the average NYMEX natural gas pricing was $3.81 per Mcf, or 4% higher than the average NYMEX price per Mcf for the six months ended June 30, 2025. Our settled derivatives decreased our realized natural gas price per Mcf by $0.06 for the six months ended June 30, 2026 and increased our realized natural gas price per Mcf by $0.01 for the six months ended June 30, 2025. For the six months ended June 30, 2026, our average realized natural gas price per Mcf after reflecting settled derivatives was $1.82 compared to $3.12 for the six months ended June 30, 2025. 28 Table of Contents Results of Operations The following table sets forth summary production and operating data for the periods indicated. Because of normal production declines, increased or decreased drilling activities, fluctuations in commodity prices and the effects of 29 Table of Contents acquisitions and divestitures, the historical information presented below should not be interpreted as being indicative of future results. [Excerpt truncated for page length; source filing is linked above.] ## Latest 10-K MD&A (excerpt) Latest 10-K Item 7 source: https://www.sec.gov/Archives/edgar/data/1928446/000192844626000007/grnt-20251231.htm Complete FY 2025 MD&A: /company/GRNT/mda/fy2025/ Extracted structurally from real Item 7 body heading to real Item 7A/8 boundary. Confidence: high Filing date: 2026-03-06 Report date: 2025-12-31 Item 7. Management’s Discussion and Analysis of Financial Conditions and Results of Operations The following discussion and analysis of our financial condition and results of operations should be read in conjunction with our financial statements and related notes included elsewhere in this Annual Report on Form 10-K. The following discussion contains “forward‑looking statements” reflecting our current expectations, estimates and assumptions concerning events and financial trends that may affect our future operating results or financial position. Actual results and the timing of events may differ materially from those contained in these forward‑looking statements due to a number of factors. Factors that could cause or contribute to such differences include, but are not limited to, market prices for oil and natural gas, capital expenditures, economic and competitive conditions, regulatory changes and other uncertainties, as well as those factors discussed below and elsewhere in this report. Please read “Cautionary Note Regarding Forward‑Looking Statements.” Also, please read the risk factors and other cautionary statements described under “Part I, Item 1A. Risk Factors.” We assume no obligation to update any of these forward‑looking statements, except as required by applicable law. Overview Granite Ridge is a scaled energy company which aims to provide shareholders with exposure similar to energy private equity through operated partnerships and traditional non-operated assets. We own assets in six prolific unconventional basins across the United States. We aim to deliver a diversified portfolio with best-in-class full cycle returns by investing in a large number of high-graded opportunities developed by proven public and private operators. We focus on success as measured by total shareholder returns, which we seek to balance with a low leverage profile. As of December 31, 2025, we owned an interest in 3,602 gross (245 net) producing wells, 355,252 gross (47,534 net) developed acres, and 33,399 gross (12,504 net) undeveloped acres, all located in the United States. Our average daily production for the year ended December 31, 2025 was 31,984 Boe per day. 53 Table of Contents Business Combination On October 24, 2022 (the “Closing Date”), Granite Ridge and Executive Network Partnering Corporation ("ENPC") consummated the business combination pursuant to the terms of the Business Combination Agreement, dated as of May 16, 2022 (the “Business Combination Agreement”), by and among ENPC, Granite Ridge, ENPC Merger Sub, Inc., a Delaware corporation and a wholly-owned subsidiary of Granite Ridge (“ENPC Merger Sub”), GREP Merger Sub, LLC, a Delaware limited liability company and a wholly-owned subsidiary of Granite Ridge (“GREP Merger Sub”), and Granite Ridge Holdings, LLC, a Delaware limited liability company formerly known as GREP Holdings, LLC (“GREP”). Pursuant to the Business Combination Agreement, on the Closing Date, (i) ENPC Merger Sub merged with and into ENPC (the “ENPC Merger”), with ENPC surviving the ENPC Merger as a wholly-owned subsidiary of Granite Ridge and (ii) GREP Merger Sub merged with and into GREP (the “GREP Merger,” and together with the ENPC Merger, the “Mergers”), with GREP surviving the GREP Merger as a wholly-owned subsidiary of Granite Ridge (the transactions contemplated by the foregoing clauses (i) and (ii) the “Business Combination,” and together with the other transactions contemplated by the Business Combination Agreement, the “Transactions”). For additional information on the Business Combination See Note 1 in the Notes to the Consolidated Financial Statements. Source of Our Revenues We derive our revenues from our interests in the sale of oil and natural gas production. Revenues are a function of production, the prevailing market price at the time of sale, oil quality, and transportation costs to market. We use derivative instruments to hedge future sales prices on a portion of our oil and natural gas production. We expect our derivative activities will help us achieve more predictable cash flows and reduce our exposure to downward price fluctuations. The use of derivative instruments has in the past, and may in the future, prevent us from realizing the full benefit of upward price movements but also mitigates the effects of declining price movements. Principal Components of Our Cost Structure Lease operating expenses Lease operating expenses are the costs incurred in the operation of producing properties, including workover costs. Expenses for field employees’ salaries, saltwater disposal, repairs and maintenance comprise the most significant portion of our lease operating expenses. Certain items, such as direct labor and materials and supplies, generally remain relatively fixed across broad production volume ranges, but can fluctuate depending on activities performed during a specific period. A portion of our operating cost components are variable and change in correlation to production levels. Production and ad valorem taxes Production taxes are paid on produced oil and natural gas. Ad valorem taxes are paid on the value of our properties in certain states. We seek to take full advantage of all credits and exemptions in our various taxing jurisdictions. In general, the production taxes we pay correlate to the changes in oil and natural gas revenues. Depletion and accretion expense Depletion and accretion include the systematic expensing of the capitalized costs incurred to acquire, explore and develop oil and natural gas. As a “successful efforts” company, we capitalize all costs associated with our acquisition and successful development efforts and allocate these costs to each unit of production using the units of production method. Accretion expense relates to the passage of time of our asset retirement obligations. Impairment expense We evaluate capitalized costs related to proved and unproved oil and natural gas properties, including wells and related oil sales support equipment and facilities, for recoverability when indicators of impairment exist. If undiscounted cash flows are insufficient to recover the net capitalized costs of proved properties, we recognize an impairment charge for the difference between the net capitalized cost of proved properties and their estimated fair values. Unproved oil and natural 54 Table of Contents gas properties are periodically assessed for impairment by considering future drilling and exploration plans, results of exploration activities, commodity price outlooks, planned future sales and expiration of all or a portion of the projects. General and administrative expenses General and administrative expenses include overhead, including payroll and benefits for our corporate staff, management and annual service fees under the MSA, audit and other professional fees and legal compliance. Interest expense We finance a portion of our working capital requirements, capital expenditures and acquisitions with borrowings. As a result, we incur interest expense that is affected by both fluctuations in interest rates and our financing decisions. Gain (loss) on derivative contracts We utilize commodity derivative financial instruments to reduce our exposure to fluctuations in the prices of oil and natural gas. Gain (loss) on derivative contracts is comprised of (i) cash gains and losses we recognize on settled commodity derivatives during the period, and (ii) non-cash mark-to-market gains and losses we incur on commodity derivative instruments outstanding at period-end. Selected Factors That Affect Our Operating Results Our revenues, cash flows from operations and future growth depend substantially upon: •the timing and success of drilling and production activities by our operating partners; •the prices and the supply and demand for oil and natural gas; •the quantity of oil and natural gas production from the wells in which we participate; •changes in the fair value of the derivative instruments we use to reduce our exposure to fluctuations in the price of oil and natural gas; •our ability to continue to identify and acquire high-quality acreage and drilling opportunities; and •the level of our operating expenses. In addition to the factors that affect companies in our industry generally, the location of substantially all of our acreage in the Eagle Ford, Permian, Bakken, Haynesville, Denver-Julesburg and Appalachian Basins subjects our operating results to factors specific to these regions. These factors include the potential adverse impact of weather on drilling, production and transportation activities, particularly during the winter and spring months, as well as infrastructure limitations, transportation capacity, regulatory matters and other factors that may specifically affect one or more of these regions. The price of oil and natural gas can vary depending on the market in which it is sold and the means of transportation used to transport the oil and natural gas to market. The price at which our oil and natural gas production is sold typically reflects either a premium or discount to the NYMEX benchmark price. Thus, our operating results are also affected by changes in the oil and natural gas price differentials between the applicable benchmark and the sales prices we receive for our oil and natural gas production. Our oil price differential to the NYMEX benchmark price during 2025, 2024 and 2023 was $(3.76) per barrel, $(3.57) per barrel and $(1.40) per barrel, respectively. Our natural gas price differential during 2025, 2024 and 2023 was $(0.96) per Mcf, $(0.31) per Mcf and $0.19 per Mcf, respectively. Market Conditions The price that we receive for the oil and natural gas our operators produce is largely a function of market supply and demand. Because our oil and natural gas revenues are heavily weighted toward oil, we are more significantly impacted by 55 Table of Contents changes in oil prices than by changes in the price of natural gas. Worldwide supply in terms of output, especially production from properties within the United States, the production quota set by OPEC, and the strength of the U.S. dollar can adversely impact oil prices. Historically, commodity prices have been volatile, and we expect the volatility to continue in the future. Although we cannot predict the occurrence of events that may affect future commodity prices, or the degree to which these prices will be affected, the prices for any commodity that we produce will generally approximate current market prices in the geographic region of the production. From time to time, we expect that we may hedge a portion of our commodity price risk to mitigate the impact of price volatility on our business. Prices for various quantities of natural gas and oil that we produce significantly impact our revenues and cash flows. The following table lists average NYMEX prices for oil and natural gas for the years ended December 31, 2025, 2024 and 2023. [[GREPCENT_TABLE]] [["","December 31,"],["","2025","","2024","","2023"],["Average NYMEX Prices(1)"],["Oil (per Bbl)","$","65.39","","$","76.63","","$","77.58"],["Natural gas (per Mcf)","$","3.52","","$","2.19","","$","2.53"]] [[/GREPCENT_TABLE]] __________________________________________ (1)Based on average NYMEX closing prices. Results of Operations The following tables and related discussion set forth key operating and financial data as of and for the years ended December 31, 2025 and 2024. For similar operating and financial data and discussion of our 2024 results compared to our 2023 results, refer to “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations” under Part II of our annual report on Form 10-K for the year ended December 31, 2024, which was filed with the SEC on March 6, 2025. Because of normal production declines, increased or decreased drilling activities, fluctuations in 56 Table of Contents [Excerpt truncated for page length; the complete text is on the linked full-MD&A page.] Read the full FY 2025 MD&A: /company/GRNT/mda/fy2025/ All MD&A years: /company/GRNT/mda/ ## MD&A history Prior-year 10-K MD&A spans are extracted from SEC filings with the same bounded parser used for the latest filing. Each year's full verbatim text is on its own sub-page. - [FY 2024 MD&A](/company/GRNT/mda/fy2024/): filed 2025-03-06; accession 0001928446-25-000010 (https://www.sec.gov/Archives/edgar/data/1928446/000192844625000010/grnt-20241231.htm) - [FY 2023 MD&A](/company/GRNT/mda/fy2023/): filed 2024-03-08; accession 0001928446-24-000009 (https://www.sec.gov/Archives/edgar/data/1928446/000192844624000009/grnt-20231231.htm) - [FY 2022 MD&A](/company/GRNT/mda/fy2022/): filed 2023-03-27; accession 0001558370-23-004735 (https://www.sec.gov/Archives/edgar/data/1928446/000155837023004735/grnt-20221231x10k.htm) ## Macro cross-references Indicators mapped to this company's SIC classification (industry 1311 Crude Petroleum & Natural Gas) by grepcent's deterministic macro-sector crosswalk. A navigational mapping, not a statistical or causal claim. - [INDPRO](/indicator/INDPRO/): Industrial Production: Total Index - [TCU](/indicator/TCU/): Capacity Utilization: Total Index - [PPIACO](/indicator/PPIACO/): Producer Price Index by Commodity: All Commodities - [DGS10](/indicator/DGS10/): Market Yield on U.S. Treasury Securities at 10-Year Constant Maturity - [FEDFUNDS](/indicator/FEDFUNDS/): Federal Funds Effective Rate Macro-to-micro threads including this sector: [Inflation (CPI / PCE / PPI)](/thread/inflation-cpi-pce-ppi/). All macro indicators: /indicators/ ## For LLMs & downloads Markdown twin: /company/GRNT.md · JSON record: /company/GRNT.json · verified financials: /company/GRNT/financials.json / /company/GRNT/financials.csv · machine TOC for the whole site: /llms.txt