PEDEVCO CORP

Previous wording

Certain capitalized terms used below but not otherwise defined, are defined in, and shall be read along with the meanings given to such terms in, the notes to the unaudited financial statements of the Company for the three months ended March 31, 2025, above.

Current wording

Certain capitalized terms used below but not otherwise defined, are defined in, and shall be read along with the meanings given to such terms in, the notes to the unaudited consolidated financial statements of the Company for the three and six months ended June 30, 2025, above.

Previous wording

We are an oil and gas company focused on the acquisition and development of oil and natural gas assets where the latest in modern drilling and completion techniques and technologies have yet to be applied. In particular, we focus on legacy proven properties where there is a long production history, well defined geology and existing infrastructure that can be leveraged when applying modern field management technologies. Our current properties are located in the San Andres formation of the Permian Basin situated in West Texas and eastern New Mexico (the “Permian Basin”) and in the Denver-Julesberg Basin (“D-J Basin”) in Colorado and Wyoming. As of March 31, 2025, we held approximately 14,105 net Permian Basin acres located in Chaves and Roosevelt Counties, New Mexico, through our wholly-owned subsidiary, Pacific Energy Development Corp. (“PEDCO”), and which are operated by our wholly-owned operating subsidiary, Ridgeway Arizona Oil Corp. (“RAZO”), which asset we refer to as our “Permian Basin Asset.” Also as of March 31, 2025, we held approximately 18,572 net D-J Basin acres located in Weld and Morgan Counties, Colorado, and Laramie County, Wyoming, through our wholly-owned subsidiary, PRH Holdings LLC (“PRH”), and which are operated by our wholly-owned operating subsidiary, Red Hawk Petroleum, LLC (“Red Hawk”), which asset we refer to as our “D-J Basin Asset.” As of March 31, 2025, we held interests in 35 gross (33.5 net) wells in our Permian Basin Asset, of which 28 gross (26.5 net) wells were active producers, five gross (five net) wells were inactive, and two gross (two net) wells were active salt water disposal wells (“SWD’s”), all of which were held by PEDCO and operated by RAZO, and interests in 82 gross (21.9 net) wells in our D-J Basin Asset held by PRH, all of which 17 gross (15.4 net) wells were operated by Red Hawk and then-producing, 48 gross (6.5 net) wells were non-operated, and 17 wells had an after-payout interest. On April 3, 2025, and effective January 1, 2025, in order to reduce plugging and abandonment liabilities and recurring operational expenses, the Company sold all of its legacy 17 gross (15.4 net) operated wells in its D-J Basin Asset, with the Company retaining ownership in all its existing leasehold, which legacy wells no longer provided meaningful oil and gas production to the Company.

Current wording

We are an oil and gas company focused on the acquisition and development of oil and natural gas assets where the latest in modern drilling and completion techniques and technologies have yet to be applied. In particular, we focus on legacy proven properties where there is a long production history, well defined geology and existing infrastructure that can be leveraged when applying modern field management technologies. Our current properties are located in the San Andres formation of the Permian Basin situated in West Texas and eastern New Mexico (the “Permian Basin”) and in the Denver-Julesberg Basin (“D-J Basin”) in Colorado and Wyoming. As of June 30, 2025, we held approximately 14,105 net Permian Basin acres located in Chaves and Roosevelt Counties, New Mexico, through our wholly-owned subsidiary, Pacific Energy Development Corp. (“PEDCO”), and which are operated by our wholly-owned operating subsidiary, Ridgeway Arizona Oil Corp. (“RAZO”), which asset we refer to as our “Permian Basin Asset.” Also as of June 30, 2025, we held approximately 17,830 net D-J Basin acres located in Weld and Morgan Counties, Colorado, and Laramie County, Wyoming, through our wholly-owned subsidiary, PRH Holdings LLC (“PRH”), and which are operated by our wholly-owned operating subsidiary, Red Hawk Petroleum, LLC (“Red Hawk”), which asset we refer to as our “D-J Basin Asset.” As of June 30, 2025, we held interests in 39 gross (35.5 net) wells in our Permian Basin Asset, of which 32 gross (28.5 net) wells were active producers, five gross (five net) wells were inactive, and two gross (two net) wells were active salt water disposal wells (“SWD’s”), all of which were held by PEDCO and operated by RAZO, and interests in 71 gross (6.9 net) wells in our D-J Basin Asset held by PRH, which includes 54 gross (6.9 net) non-operated wells, and 17 wells that had an after-payout interest. On April 3, 2025, and effective January 1, 2025, in order to reduce plugging and abandonment liabilities and recurring operational expenses, the Company sold all of its legacy 17 gross (15.4 net) operated wells in its D-J Basin Asset, with the Company retaining ownership in all its existing leasehold, which legacy wells no longer provided meaningful oil and gas production to the Company.

Previous wording

Our strategy is to be the operator and/or a significant working interest owner, directly or through our subsidiaries and joint ventures, in the majority of our Permian Basin acreage so we can dictate the pace of development in order to execute our business plan. Our D-J Basin strategy is to participate in projects we deem highly economic on an operated or non-operated basis as our acreage position does not always allow for us to serve as operator in the D-J Basin. Our net capital expenditures for 2025 are estimated at the time of this filing to range between $27 million to $33 million. This estimate includes a range of $24.5 million to $30.5 million for drilling and completion costs on our Permian Basin and D-J Basin Assets (of which we have incurred approximately $5.7 million through March 31, 2025) and approximately $2.5 million in estimated capital expenditures for electronic submersible pump (ESP) purchases, rod pump conversions, recompletions, well cleanouts, leasing, facilities, remediation and other miscellaneous capital expenses (of which we have incurred approximately $0.3 million through March 31, 2025) . We anticipate that approximately 70% to 75% of our expected capital expenditures for 2025 will be allocated to development in the D-J Basin under our February 2025 joint development agreement entered into with a large private equity-backed D-J Basin operator and our Participation Agreement and Area of Mutual Interest (“AMI”) entered into in August 2024 with a private operator, each discussed below. These estimates do not include expenditures for acquisitions or other projects that may arise but are not currently anticipated. We periodically review our capital expenditures and adjust our capital forecasts and allocations based on liquidity, drilling results, leasehold acquisition opportunities, partner non-consents, proposals from third party operators, and commodity prices, while prioritizing our financial strength and liquidity.

Current wording

Our strategy is to be the operator and/or a significant working interest owner, directly or through our subsidiaries and joint ventures, in the majority of our Permian Basin acreage so we can dictate the pace of development in order to execute our business plan. Our D-J Basin strategy is to participate in projects we deem highly economic on an operated or non-operated basis as our acreage position does not always allow for us to serve as operator in the D-J Basin. Our net capital expenditures for 2025 are estimated at the time of this filing to range between $27 million to $33 million. This estimate includes a range of $24.5 million to $30.5 million for drilling and completion costs on our Permian Basin and D-J Basin Assets (of which we have incurred approximately $7.8 million through June 30, 2025) and approximately $2.5 million in estimated capital expenditures for electronic submersible pump (ESP) purchases, rod pump conversions, recompletions, well cleanouts, leasing, facilities, remediation and other miscellaneous capital expenses (of which we have incurred approximately $0.5 million through June 30, 2025) . We anticipate that approximately 70% to 75% of our expected capital expenditures for 2025 will be allocated to development in the D-J Basin under our February 2025 joint development agreement entered into with a large private equity-backed D-J Basin operator and our Participation Agreement and Area of Mutual Interest (“AMI”) entered into in August 2024 with a private operator, each discussed below. These estimates do not include expenditures for acquisitions or other projects that may arise but are not currently anticipated. We periodically review our capital expenditures and adjust our capital forecasts and allocations based on liquidity, drilling results, leasehold acquisition opportunities, partner non-consents, proposals from third party operators, and commodity prices, while prioritizing our financial strength and liquidity.

Previous wording

We expect that we will have sufficient cash available to meet our needs over the next 12 months after the filing of this report and in the foreseeable future, including to fund the remainder of our 2025 development program, discussed above, which cash we anticipate being available from (i) projected cash flow from our operations, (ii) existing cash on hand, (iii) equity infusions or loans (which may be convertible) made available from Dr. Simon G., Kukes, our former CEO and recently appointed Executive Chairman of the Company's Board of Directors, which funding Dr. Kukes is under no obligation to provide, (iv) public or private debt or equity financings, including up to $8.0 million in securities which we may sell in the future in “at the market offerings”, pursuant to a Sales Agreement entered into on December 20, 2024, with Roth Capital Partners, LLC (the “Lead Agent”), and A.G.P./Alliance Global Partners (“AGP” and, together with the Lead Agent, the “Agents”)(discussed in greater detail below under “Liquidity and Capital Resources—Financing” (under which we have sold no shares to date), and (v) funding through credit or loan facilities, including under the Company’s reserve-based lending facility (“RBL”) with Citibank, N.A., as administrative agent, which provides for an initial borrowing base of $20 million and an aggregate maximum revolving credit amount of $250 million (of which none has been drawn down by the Company to date), as discussed in greater detail below under “Liquidity and Capital Resources”. In addition, we may seek additional funding through asset sales, farm-out arrangements, and credit facilities to fund potential acquisitions during the remainder of 2025.

Current wording

We expect that we will have sufficient cash available to meet our needs over the next 12 months after the filing of this report and in the foreseeable future, including to fund the remainder of our 2025 development program, discussed above, which cash we anticipate being available from (i) projected cash flow from our operations, (ii) existing cash on hand, (iii) equity infusions or loans (which may be convertible) made available from Dr. Simon G., Kukes, our former CEO and recently appointed Executive Chairman of the Company's Board of Directors, which funding Dr. Kukes is under no obligation to provide, (iv) public or private debt or equity financings, including up to $7.6 million in securities which we may sell in the future in “at the market offerings”, pursuant to a Sales Agreement entered into on December 20, 2024, with Roth Capital Partners, LLC (the “Lead Agent”), and A.G.P./Alliance Global Partners (“AGP” and, together with the Lead Agent, the “Agents”)(discussed in greater detail below under “Liquidity and Capital Resources—Financing” (under which we have sold 489,967 shares to date), and (v) funding through credit or loan facilities, including under the Company’s reserve-based lending facility (“RBL”) with Citibank, N.A., as administrative agent, which provides for an initial borrowing base of $20 million and an aggregate maximum revolving credit amount of $250 million (of which none has been drawn down by the Company to date), as discussed in greater detail below under “Liquidity and Capital Resources”. In addition, we may seek additional funding through asset sales, farm-out arrangements, and credit facilities to fund potential acquisitions during the remainder of 2025.

Previous wording

The following discussion and analysis of the results of operations for the three-month periods ended March 31, 2025, and 2024, should be read in conjunction with our consolidated financial statements and notes thereto included in this Quarterly Report on Form 10-Q. The majority of the numbers presented below are rounded numbers and should be considered as approximate.

Current wording

The following discussion and analysis of the results of operations for the three-month and six-month periods ended June 30, 2025, and 2024, should be read in conjunction with our consolidated financial statements and notes thereto included in this Quarterly Report on Form 10-Q. The majority of the numbers presented below are rounded numbers and should be considered as approximate.

Previous wording

We reported net income for the three-month period ended March 31, 2025, of $0.1 million, or $0.00 per common share, compared to net income for the three-month period ended March 31, 2024 of $0.8 million or $0.01 per share. The decrease in net income of $0.7 million, when comparing the current period to the prior year’s period, was primarily due to a $1.1 million increase in total operating expense (which includes an impairment of oil and gas properties of $0.2 million), offset by an increase of revenues of $0.6 million and other income (each discussed in more detail below) combined with income tax expense of $76,000 (seeNote 13 – Income Taxes, in the notes to the consolidated financial statements above under “Part I – Financial Information—Item 1. Financial Statements”).

Current wording

We reported a net loss for the three-month period ended June 30, 2025, of $1.7 million, or ($0.02) per common share, compared to net income for the three-month period ended June 30, 2024 of $2.7 million or $0.03 per share. The decrease in net income of $4.4 million, when comparing the current period to the prior year’s period, was primarily due to the recognition of $1.4 million from a note receivable - credit loss related to the full write-off of the Tilloo Note receivable, corresponding accrued interest and posting closing adjustments owed to the Company related to the sale of our EOR subsidiary and other reductions to operating income of $3.5 million (a $4.8 million reduction in revenue and a $0.5 million impairment to oil and gas properties, offset by a $0.8 million reduction in other operating expenses), offset by a $1.0 million gain on sale on oil and gas properties from the sale of our operated wells in the D-J Basin (each discussed in more detail below) and an income tax benefit of $0.5 million (seeNote 13 – Income Taxes, in the notes to the consolidated financial statements above under “Part I – Financial Information—Item 1. Financial Statements”).

Previous wording

*Includes severance, ad valorem taxes and marketing costs.

Current wording

Includes severance, ad valorem taxes, assessment and gathering, transportation and processing costs.

Previous wording

Impairment of Oil and Gas Properties. The Company recorded an impairment of oil and gas properties of $0.2 million related to undeveloped leases representing 232 net acres in the D-J Basin that it allowed to expire or currently have no plans to drill prior to expiration, in the current period. There was no impairment in the prior period.

Current wording

Impairment of Oil and Gas Properties. The Company recorded an impairment of oil and gas properties of $0.5 million related to undeveloped leases representing 776 net acres in the D-J Basin that it allowed to expire or currently have no plans to drill prior to expiration, in the current period. There was no impairment in the prior period.

Previous wording

*General and Administrative Expenses (excluding share-based compensation).*The $0.1 million increase was primarily the result of additional payroll and professional fees.

Current wording

*General and Administrative Expenses (excluding share-based compensation).*The $0.3 million increase was primarily the result of additional payroll, audit fees and software licensing fees.

Previous wording

*Share-Based Compensation.*Share-based compensation, which is included in general and administrative expenses in the Statements of Operations, remained unchanged when comparing periods. Share-based compensation is utilized for the purpose of conserving cash resources for use in field development activities and operations.

Current wording

*Share-Based Compensation.*Share-based compensation, which is included in general and administrative expenses in the Statements of Operations, increased nominally due to the award of certain employee restricted stock and stock-based options. Share-based compensation is utilized for the purpose of conserving cash resources for use in field development activities and operations.

Previous wording

Interest Income and Other Income. Includes interest earned from our interest-bearing cash accounts and interest on our note receivable, nominally decreased due to additional cash usage for our operations in the current period compared to the prior period. There was a nominal amount and decrease in other income when comparing periods.

Current wording

Interest Income and Other Income (Expense). Includes interest earned from our interest-bearing cash accounts, which nominally decreased due to additional cash usage for our operations and no interest on the note receivable, which has been fully written-off in the current period. Other income in the current period is related to sales tax refunds and other expense in the prior period primarily relates to the subsequent disposition of a cash escrow bank balance related to the sale of our then wholly-owned subsidiary EOR Operating Company.

Previous wording

*Lease Operating Expenses.*The increase of $0.9 million was primarily due to higher direct and variable lease operating expenses associated with the higher oil volume resulting from the increased number of wells and increased oil production during the current year’s period, compared to the prior year’s period, due to our participation in new non-operated wells in the D-J Basin, as well as production from our completed wells in 2024.

Current wording

*Lease Operating Expenses.*The increase of $0.1 million was primarily due to higher direct and variable lease operating expenses associated with the higher oil volume in Q1 2025, which was offset by lower direct and variable lease operating expenses associated with the lower crude oil volumes resulting from the production volume declines in Q2 2025 noted above.

Previous wording

*Depreciation, Depletion, Amortization and Accretion.*The $0.1 million decrease was primarily the result of an increase in our 2025 depletable reserve base relative to the production increase noted above.

Current wording

*Depreciation, Depletion, Amortization and Accretion.*The $0.5 million decrease was primarily the result of lower crude oil volumes resulting from the production volume declines, primarily from Q2 2025, as noted above.

Previous wording

Gain on Sale of Fixed Asset. Relates to the sale of a vehicle and the subsequent purchase of a replacement vehicle in the prior period.

Current wording

Gain on Sale of Fixed Asset. Relates to the sale of a vehicle and the subsequent purchase of another vehicle in the current period.

Previous wording

The primary sources of cash for the Company during the three-month period ended March 31, 2025 were from $8.7 million in sales of crude oil, natural gas and NGLs. The primary uses of cash were funds used for drilling, completion and operating costs.

Current wording

The primary sources of cash for the Company during the three-month period ended June 30, 2025 were from $15.7 million in sales of crude oil, natural gas and NGLs. The primary uses of cash were funds used for drilling, completion and operating costs.

Previous wording

At March 31, 2025, the Company’s total current assets of $23.6 million exceeded its total current liabilities of $16.9 million, resulting in a working capital surplus of $6.7 million, while at December 31, 2024, the Company’s total current assets of $13.2 million exceeded its total current liabilities of $6.9 million, resulting in a working capital surplus of $6.3 million. The $0.4 million increase in our working capital surplus is primarily related to a proportional increase in production and sales, offset by a proportional increase in payables related to our current capital drilling program, when comparing the current period to the prior period (described above).

Current wording

At June 30, 2025, the Company’s total current assets of $17.6 million exceeded its total current liabilities of $10.6 million, resulting in a working capital surplus of $7.0 million, while at December 31, 2024, the Company’s total current assets of $13.2 million exceeded its total current liabilities of $6.9 million, resulting in a working capital surplus of $6.3 million. The $0.7 million increase in our working capital surplus is primarily related to a proportional increase in production and sales, offset by a proportional increase in payables related to our current capital drilling program, when comparing the current period to the prior period (described above).

Previous wording

The Company has $8.0 million of availability under a December 20, 2024, Sales Agreement (the “Sales Agreement”), entered into with Roth Capital Partners, LLC (the “Lead Agent”) and A.G.P./Alliance Global Partners (“AGP”, and collectively with the Lead Agent, the “Agents”), pursuant to which the Company may sell securities from time to time in an “at the market offering” (the “ATM Offering”). The Company will pay the Lead Agent a commission of 3.0% of the gross sales price of any shares sold under the Sales Agreement. The Company also agreed to reimburse the Agents for their reasonable and documented out-of-pocket expenses in an amount not to exceed $75,000, in connection with entering into the Sales Agreement and for the Agents’ reasonable and documented out-of-pocket expenses related to quarterly maintenance of the Sales Agreement on a quarterly basis in an amount not to exceed $5,000. The Company has not sold any securities under the ATM Offering as of the date of this report.

Current wording

The ATM Offering was made pursuant to the terms of that certain December 20, 2024, Sales Agreement (the “Sales Agreement”), entered into with Roth Capital Partners, LLC (the “Lead Agent”) and A.G.P./Alliance Global Partners (“AGP”, and collectively with the Lead Agent, the “Agents”), pursuant to which the Company may sell securities from time to time in an “at the market offering” (the “ATM Offering”). The Company will pay the Lead Agent a commission of 3.0% of the gross sales price of any shares sold under the Sales Agreement. The Company also agreed to reimburse the Agents for their reasonable and documented out-of-pocket expenses in an amount not to exceed $75,000, in connection with entering into the Sales Agreement and for the Agents’ reasonable and documented out-of-pocket expenses related to quarterly maintenance of the Sales Agreement on a quarterly basis in an amount not to exceed $5,000.

Previous wording

**Cash flows provided by operating activities.**Net cash used in operating activities increased by $10.2 million for the current year’s period, when compared to the prior year’s period, primarily due to a decrease in net income of $0.6 million, coupled with a $0.1 million decrease in depreciation, depletion and amortization, offset by a $0.2 million impairment of oil and gas properties, and a $10.7 million net increase to our other components of working capital (predominantly from our drilling and completion activities).

Current wording

**Cash flows provided by operating activities.**Net cash used in operating activities increased by $5.2 million for the current year’s period, when compared to the prior year’s period, primarily due to a decrease in net income of $5.0 million, coupled with a $0.5 million decrease in depreciation, depletion and amortization and a $1.0 million gain on a sale of oil and gas properties, offset by a $0.7 million impairment of oil and gas properties, $0.4 increase in deferred tax asset and $1.4 million from a note receivable - credit loss, and a $9.9 million net decrease to our other components of working capital (predominantly from increased expenses from our drilling and completion activities).

Previous wording

Cash flows provided by (used in) investing activities. Net cash provided by investing activities increased by $1.6 million for the current year’s period, when compared to the prior year’s period, primarily due to cash received from the sale of oil and gas properties, offset by increased cash outlays from our capital spending relating to our drilling and completion activities.

Current wording

Cash flows used in investing activities. Even though total capital costs (accrued and cash) increased to $8.5 million this period from $7.2 million last period (see extract table below from our Consolidated Statements of Cash Flows), net cash used in investing activities actually decreased by $11.3 million year-over-year primarily due to a decrease in cash only outlays from our capital spending relating to our drilling and completion activities offset by cash received from the sale of oil and gas properties.

Previous wording

We have included EBITDA and Adjusted EBITDA in this Report as supplements to generally accepted accounting principles in the United States of America (“GAAP”) measures of performance to provide investors with an additional financial analytical framework which management uses, in addition to historical operating results, as the basis for financial, operational and planning decisions and present measurements that third parties have indicated are useful in assessing the Company and its results of operations. “EBITDA” represents net income before interest, taxes, depreciation and amortization. “Adjusted EBITDA” represents EBITDA, less share-based compensation, impairment of oil and gas properties and gain on sale of fixed assets. Adjusted EBITDA excludes certain items that we believe affect the comparability of operating results and can exclude items that are generally non-recurring in nature or whose timing and/or amount cannot be reasonably estimated. EBITDA and Adjusted EBITDA are presented because we believe they provide additional useful information to investors due to the various noncash items during the period. EBITDA and Adjusted EBITDA are also frequently used by analysts, investors and other interested parties to evaluate companies in our industry. EBITDA and Adjusted EBITDA have limitations as analytical tools, and you should not consider them in isolation, or as a substitute for analysis of our operating results as reported under GAAP. Some of these limitations are: EBITDA and Adjusted EBITDA do not reflect cash expenditures, future requirements for capital expenditures, or contractual commitments; EBITDA and Adjusted EBITDA do not reflect changes in, or cash requirements for, working capital needs; and EBITDA and Adjusted EBITDA do not reflect the significant interest expense, or the cash requirements necessary to service interest or principal payments, on debt or cash income tax payments. For example, although depreciation and amortization are noncash charges, the assets being depreciated and amortized will often have to be replaced in the future, and EBITDA and Adjusted EBITDA do not reflect any cash requirements for such replacements. Additionally, other companies in our industry may calculate EBITDA and Adjusted EBITDA differently than PEDEVCO Corp. does, limiting its usefulness as a comparative measure. You should not consider EBITDA and Adjusted EBITDA in isolation, or as substitutes for analysis of the Company’s results as reported under GAAP. The Company’s presentation of these measures should not be construed as an inference that future results will be unaffected by unusual or nonrecurring items. We compensate for these limitations by providing a reconciliation of each of these non-GAAP measures to the most comparable GAAP measure. We encourage investors and others to review our business, results of operations, and financial information in their entirety, not to rely on any single financial measure, and to view these non-GAAP me…

Excerpt shortened here; the source contains the full paragraph.

Current wording

We have included EBITDA and Adjusted EBITDA in this Report as supplements to generally accepted accounting principles in the United States of America (“GAAP”) measures of performance to provide investors with an additional financial analytical framework which management uses, in addition to historical operating results, as the basis for financial, operational and planning decisions and present measurements that third parties have indicated are useful in assessing the Company and its results of operations. “EBITDA” represents net income before interest, taxes, depreciation and amortization. “Adjusted EBITDA” represents EBITDA, less share-based compensation, impairment of oil and gas properties, gain on sale of oil and gas properties, gain on sale of fixed asset and note receivable - credit loss. Adjusted EBITDA excludes certain items that we believe affect the comparability of operating results and can exclude items that are generally non-recurring in nature or whose timing and/or amount cannot be reasonably estimated. EBITDA and Adjusted EBITDA are presented because we believe they provide additional useful information to investors due to the various noncash items during the period. EBITDA and Adjusted EBITDA are also frequently used by analysts, investors and other interested parties to evaluate companies in our industry. EBITDA and Adjusted EBITDA have limitations as analytical tools, and you should not consider them in isolation, or as a substitute for analysis of our operating results as reported under GAAP. Some of these limitations are: EBITDA and Adjusted EBITDA do not reflect cash expenditures, future requirements for capital expenditures, or contractual commitments; EBITDA and Adjusted EBITDA do not reflect changes in, or cash requirements for, working capital needs; and EBITDA and Adjusted EBITDA do not reflect the significant interest expense, or the cash requirements necessary to service interest or principal payments, on debt or cash income tax payments. For example, although depreciation and amortization are noncash charges, the assets being depreciated and amortized will often have to be replaced in the future, and EBITDA and Adjusted EBITDA do not reflect any cash requirements for such replacements. Additionally, other companies in our industry may calculate EBITDA and Adjusted EBITDA differently than PEDEVCO Corp. does, limiting its usefulness as a comparative measure. You should not consider EBITDA and Adjusted EBITDA in isolation, or as substitutes for analysis of the Company’s results as reported under GAAP. The Company’s presentation of these measures should not be construed as an inference that future results will be unaffected by unusual or nonrecurring items. We compensate for these limitations by providing a reconciliation of each of these non-GAAP measures to the most comparable GAAP measure. We encourage investors and others to review our business, results of operations, and financial information in their entirety, not …

Excerpt shortened here; the source contains the full paragraph.

Previous wording

Our discussion and analysis of our financial condition and results of operations is based on our financial statements, which have been prepared in accordance with accounting principles generally accepted in the United States. The preparation of these financial statements requires us to make estimates and judgments that affect the reported amounts of assets, liabilities, revenues and expenses. We base our estimates on historical experience and on various other assumptions that we believe to be reasonable under the circumstances, the results of which form the basis for making judgments about the carrying values of assets and liabilities that are not readily apparent from other sources. Actual results may differ from these estimates under different assumptions or conditions. We believe the following critical accounting policies affect our most significant judgments and estimates used in preparation of our financial statements.

Current wording

Our discussion and analysis of our financial condition and results of operations is based on our consolidated financial statements, which have been prepared in accordance with accounting principles generally accepted in the United States. The preparation of these consolidated financial statements requires us to make estimates and judgments that affect the reported amounts of assets, liabilities, revenues and expenses. We base our estimates on historical experience and on various other assumptions that we believe to be reasonable under the circumstances, the results of which form the basis for making judgments about the carrying values of assets and liabilities that are not readily apparent from other sources. Actual results may differ from these estimates under different assumptions or conditions. We believe the following critical accounting policies affect our most significant judgments and estimates used in preparation of our consolidated financial statements.

Previous wording

Recently Issued Accounting Pronouncements.

Current wording

Recently Adopted and Recently Issued Accounting Pronouncements.