0000351817true8-K/A00003518172023-12-052023-12-05
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 8-K/A
CURRENT REPORT
Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934
Date of Report (or Date of Earliest Event Reported): November 30, 2023
SilverBow Resources, Inc.
(Exact name of Registrant as specified in its charter)
| | | | | | | | |
| Delaware | 001-8754 | 20-3940661 |
(State or other jurisdiction
of incorporation) | (Commission File Number) | (IRS Employer
Identification No.) |
920 Memorial City Way, Suite 850
Houston, Texas 77024
(Address of principal executive offices)
(281) 874-2700
(Registrant’s telephone number)
Not Applicable
(Former Name or former address, if changed since last report)
Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions (see General Instruction A.2. below):
¨ Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425)
¨ Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12)
¨ Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b))
¨ Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c))
Securities registered pursuant to Section 12(b) of the Act:
| | | | | | | | |
| Title of each class | Trading Symbol(s) | Name of each exchange on which registered |
| Common Stock, par value $0.01 per share | SBOW | New York Stock Exchange |
| Preferred Stock Purchase Rights | None | New York Stock Exchange |
Indicate by check mark whether the registrant is an emerging growth company as defined in Rule 405 of the Securities Act of 1933 (§230.405 of this chapter) or Rule 12b-2 of the Securities Exchange Act of 1934 (§240.12b-2 of this chapter).
Emerging growth company ¨
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ¨
EXPLANATORY NOTE
This Current Report on Form 8-K/A of SilverBow Resources, Inc. (the “Company”), amends and supplements the Current Report on Form 8-K of the Company, dated November 30, 2023 and filed with the Securities and Exchange Commission on December 1, 2023 (the “Initial Form 8-K”), which reported under Item 2.01 that on November 30, 2023, the Company and its operating subsidiary, SilverBow Resources Operating, LLC, closed the previously announced acquisition of Chesapeake Energy Corporation's oil and gas assets in South Texas (the “South Texas Rich Properties”), pursuant to that certain Purchase and Sale Agreement, dated August 11, 2023 with Chesapeake Exploration, L.L.C., Chesapeake Operating, L.L.C., Chesapeake Energy Marketing, L.L.C. and Chesapeake Royalty, L.L.C (the “Transaction”). This amendment is filed to provide the financial statements of a business acquired by the Company and the pro forma financial information of the Company for the Transaction as required by Item 9.01 of Form 8-K. Except as set forth below, the Initial Form 8-K is unchanged.
Item 9.01 Financial Statements and Exhibits.
(a) Financial statements of business acquired.
The unaudited statements of revenues and direct operating expenses of the Chesapeake South Texas Rich Properties for the nine months ended September 30, 2023 and 2022, including the related notes thereto, are filed herewith as Exhibit 99.1.
The audited statements of revenues and direct operating expenses of the Chesapeake South Texas Rich Properties for the years ended December 31, 2022 and 2021, including the related notes
thereto, are filed herewith as Exhibit 99.2.
(b) Pro forma financial information.
The unaudited pro forma condensed combined balance sheet of the Company as of September 30, 2023, and the unaudited pro forma condensed combined statements of operations of the Company for the nine months ended September 30, 2023 and the year ended December 31, 2022, including the related notes thereto, giving effect to the Transaction are filed herewith as Exhibit 99.3. The unaudited pro forma financial information gives effect to the Transaction on the basis, and subject to the assumptions, set forth in accordance with Article 11 of Regulation S-X.
(d) Exhibits.
| | | | | | | | |
Exhibit
Number | | Description |
| | |
| 23.1 | | |
| 99.1 | | |
| 99.2 | | |
| 99.3 | | |
| 104 | | Cover Page Interactive Data File (formatted as Inline XBRL) |
| | |
SIGNATURE
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned hereunto duly authorized.
Date: December 5, 2023
| | | | | | | | | | | | | | | | | |
| | | SilverBow Resources, Inc. |
| | | | By: | /s/ Christopher M. Abundis |
| | | | | Christopher M. Abundis
Executive Vice President, Chief Financial Officer and General Counsel |
EXHIBIT 23.1
CONSENT OF INDEPENDENT AUDITORS
We hereby consent to the incorporation by reference in the Registration Statements on Form S-3 (Nos. 333-259122, 333- 260142, 333-261346, 333-264936, 333-266032 and 333-271821 ) and Form S-8 (Nos. 333-210936, 333- 215235, 333-218246, 333-233163 and 333-266584) of SilverBow Resources, Inc. of our report dated September 10, 2023 relating to the statements of revenues and direct operating expenses of the South Texas Rich Properties of Chesapeake Energy Corporation, which appears in this Current Report on Form 8-K/A.
/s/ PricewaterhouseCoopers LLP
Oklahoma City, Oklahoma
December 4, 2023
EXHIBIT 99.1
SOUTH TEXAS RICH PROPERTIES
STATEMENTS OF REVENUES AND DIRECT OPERATING EXPENSES and
NOTES TO STATEMENTS OF REVENUES AND DIRECT OPERATING EXPENSES
(UNAUDITED)
Nine Months Ended September 30, 2023 and 2022
SOUTH TEXAS RICH PROPERTIES
STATEMENTS OF REVENUES AND DIRECT OPERATING EXPENSES
(UNAUDITED)
Nine Months Ended September 30, 2023 and 2022
Table of Contents
| | | | | |
| | Page |
| Statements of Revenues and Direct Operating Expenses | |
| Notes to the Statements of Revenues and Direct Operating Expenses | |
SOUTH TEXAS RICH PROPERTIES
STATEMENTS OF REVENUES AND DIRECT OPERATING EXPENSES (UNAUDITED)
| | | | | | | | | | | |
| | Nine Months Ended |
| $ in thousands | September 30, 2023 | | September 30, 2022 |
| Revenues | $ | 291,807 | | | $ | 380,916 | |
| Direct operating expenses | 122,371 | | | 138,510 | |
| Excess of revenues over direct operating expenses | $ | 169,436 | | | $ | 242,406 | |
See accompanying Notes to the Statements of Revenues and Direct Operating Expenses
SOUTH TEXAS RICH PROPERTIES
NOTES TO THE STATEMENTS OF REVENUES AND DIRECT OPERATING EXPENSES (UNAUDITED)
1. Basis of Presentation
On August 11, 2023, Chesapeake Energy Corporation (“Chesapeake”), through its wholly owned subsidiaries Chesapeake Exploration, L.L.C., Chesapeake Operating, L.L.C., Chesapeake Energy Marketing, L.L.C. and Chesapeake Royalty, L.L.C., entered into a Purchase and Sale Agreement (the “Purchase Agreement”) with SilverBow Resources Operating, LLC, a subsidiary of SilverBow Resources, Inc. (“Buyer”), to sell a portion of its Eagle Ford assets (the “Transaction”). Under the terms of the Purchase Agreement, Chesapeake has agreed to sell approximately 42,000 net acres and approximately 540 wells, along with related property, plant and equipment (collectively, the “South Texas Rich Properties” or the “Properties”).
Under the terms and conditions of the Purchase Agreement, which has an economic effective date of February 1, 2023, the aggregate consideration to be paid to Chesapeake in the Transaction will consist of $700,000,000, comprised of (i) cash in the amount of $650,000,000, due at the closing of the Transaction, subject to certain purchase price adjustments and (ii) cash in the amount of $50,000,000 due on the first anniversary of the closing of the Transaction. Subject to satisfaction of certain commodity price triggers, Chesapeake may also receive additional cash consideration in an amount up to $50,000,000 shortly following the first anniversary of closing of the Transaction. Pursuant to the Purchase Agreement, upon the execution of the Purchase Agreement, the Buyer deposited $50,000,000 into escrow, which will be credited toward the cash consideration payable at the closing of the Transaction.
The accompanying Statements of Revenues and Direct Operating Expenses (the “Statements”) represent the direct undivided interests in the revenues and direct operating expenses associated with the producing wells in the Properties. The Statements of Revenues and Direct Operating Expenses have been derived from the historical financial records of Chesapeake. For purposes of these statements, all properties identified in the purchase and sale agreement are included herein. During the periods presented, the Properties were not accounted for or operated as a separate entity, subsidiary, segment or division by Chesapeake. Accordingly, a complete set of financial statements required by the Securities and Exchange Commission’s Regulation S-X, including a balance sheet and statement of cash flows, prepared in accordance with accounting principles generally accepted in the United States of America (“U.S. GAAP”) is not available or practicable to prepare for the Properties. The accompanying Statements of Revenues and Direct Operating Expenses vary from a complete income statement in accordance with U.S. GAAP in that they do not reflect certain expenses incurred in connection with the ownership and operation of the Properties, including but not limited to depreciation, depletion and amortization, impairments, accretion of asset retirement obligations, general and administrative expenses, interest expense and federal and state income taxes. These costs were not separately allocated to the working interests of the Properties in Chesapeake’s accounting records. In addition, these Statements of Revenues and Direct Operating Expenses are not indicative of the results of operations for the Properties on a go forward basis.
The accompanying Statements for the nine months ended September 30, 2023 and 2022 are unaudited. The unaudited interim Statements have been prepared on the same basis as the annual Statements. In the opinion of management, such unaudited interim Statements reflect all normal recurring adjustments necessary for a fair statement of the revenues and direct operating expenses of the Properties.
2. Summary of Significant Accounting Policies
Revenue Recognition
Revenue from the sale of oil, natural gas and NGL is recognized upon the transfer of control of the products, which is typically when the products are delivered to customers. Revenue is recognized net of royalties due to third parties in an amount that reflects the consideration Chesapeake expects to receive in exchange for those products.
Payment terms and conditions vary by contract type, although terms generally include a requirement of payment within 30 days. There are no significant judgments that significantly affect the amount or timing of revenue from contracts with customers.
Direct Operating Expenses
Direct operating expenses are recognized when incurred and consist of the direct expenses of operating the Properties. Direct operating expenses include lease operating expenses, production taxes and gathering, processing and transportation costs. Lease operating expenses include well repair expenses, saltwater disposal costs, facility maintenance expenses, and other field-related expenses. Lease operating expenses also include expenses directly associated with support personnel, support services, equipment and facilities directly related to oil and natural gas production activities.
Use of Estimates
The Statements of Revenues and Direct Operating Expenses are derived from the historical operating statements of Chesapeake. Accounting principles generally accepted in the United States of America require management to make estimates and assumptions that affect the amounts reported in the Statements of Revenues and Direct Operating Expenses. Actual results could differ from those estimates. Revenues and direct operating expenses relate to the historical net revenue interest and net working interest, respectively, in the Properties.
3. Subsequent Events
The Transaction closed on November 30, 2023, pursuant to the terms of the Purchase Agreement.
Chesapeake has evaluated subsequent events through December 4, 2023, the date the Statements of Revenues and Direct Operating Expenses were available to be issued, and has concluded that no other events need to be reported.
EXHIBIT 99.2
SOUTH TEXAS RICH PROPERTIES
STATEMENTS OF REVENUES AND DIRECT OPERATING EXPENSES
Years Ended December 31, 2022 and 2021
with Report of Independent Auditors
Table of Contents
| | | | | |
| | Page |
| Report of Independent Auditors | |
| Statements of Revenues and Direct Operating Expenses | |
| Notes to Statements of Revenues and Direct Operating Expenses | |
| Supplemental Oil and Gas Reserve Information (unaudited) | |
Report of Independent Auditors
To the Management of Chesapeake Energy Corporation
Opinion
We have audited the accompanying statements of revenues and direct operating expenses of the South Texas Rich Properties (the “South Texas Rich Properties”) of Chesapeake Energy Corporation (the “Company”), for the years ended December 31, 2022 and 2021, including the related notes (collectively referred to as the “statements of revenues and direct operating expenses”).
In our opinion, the accompanying statements of revenues and direct operating expenses present fairly, in all material respects, the revenues and direct operating expenses described in Note 1 of the South Texas Rich Properties for the years ended December 31, 2022 and 2021, in accordance with accounting principles generally accepted in the United States of America.
Basis for Opinion
We conducted our audit in accordance with auditing standards generally accepted in the United States of America (US GAAS). Our responsibilities under those standards are further described in the Auditors’ Responsibilities for the Audit of the Statements of Revenues and Direct Operating Expenses section of our report. We are required to be independent of the Company and to meet our other ethical responsibilities, in accordance with the relevant ethical requirements relating to our audit. We believe that the audit evidence we have obtained is sufficient and appropriate to provide a basis for our audit opinion.
Emphasis of Matter
The accompanying statements of revenues and direct operating expenses were prepared in connection with the Company’s divestiture of the South Texas Rich Properties and, as described in Note 1, were prepared for the purpose of complying with the rules and regulations of the Securities and Exchange Commission. The statements of revenues and direct operating expenses are not intended to be a complete presentation of the financial position, results of operations or cash flows of the South Texas Rich Properties. Our opinion is not modified with respect to this matter.
Responsibilities of Management for the Statements of Revenues and Direct Operating Expenses
Management is responsible for the preparation and fair presentation of the statements of revenues and direct operating expenses in accordance with accounting principles generally accepted in the United States of America, and for the design, implementation, and maintenance of internal control relevant to the preparation and fair presentation of the statements of revenues and direct operating expenses that are free from material misstatement, whether due to fraud or error.
In preparing the statements of revenues and direct operating expenses, management is responsible for the evaluation of whether there are conditions or events, considered in the aggregate, that raise substantial doubt about the South Texas Rich Properties’ ability to continue as a going concern for one year after the date the statements of revenues and direct operating expenses are available to be issued.
Auditors’ Responsibilities for the Audit of the Statements of Revenues and Direct Operating Expenses
Our objectives are to obtain reasonable assurance about whether the statements of revenues and direct operating expenses as a whole are free from material misstatement, whether due to fraud or error, and to issue an auditors’ report that includes our opinion. Reasonable assurance is a high level of assurance but is not absolute assurance and therefore is not a guarantee that an audit conducted in accordance with US GAAS will always detect a material misstatement when it exists. The risk of not detecting a material misstatement resulting from fraud is higher than for
one resulting from error, as fraud may involve collusion, forgery, intentional omissions, misrepresentations, or the override of internal control. Misstatements are considered material if there is a substantial likelihood that, individually or in the aggregate, they would influence the judgment made by a reasonable user based on the statements of revenues and direct operating expenses.
In performing an audit in accordance with US GAAS, we:
•Exercise professional judgment and maintain professional skepticism throughout the audit.
•Identify and assess the risks of material misstatement of the statements of revenues and direct operating expenses, whether due to fraud or error, and design and perform audit procedures responsive to those risks. Such procedures include examining, on a test basis, evidence regarding the amounts and disclosures in the statements of revenues and direct operating expenses.
•Obtain an understanding of internal control relevant to the audit in order to design audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the South Texas Rich Properties' internal control. Accordingly, no such opinion is expressed.
•Evaluate the appropriateness of accounting policies used and the reasonableness of significant accounting estimates made by management, as well as evaluate the overall presentation of the statements of revenues and direct operating expenses.
•Conclude whether, in our judgment, there are conditions or events, considered in the aggregate, that raise substantial doubt about the South Texas Rich Properties’ ability to continue as a going concern for a reasonable period of time.
We are required to communicate with those charged with governance regarding, among other matters, the planned scope and timing of the audit, significant audit findings, and certain internal control-related matters that we identified during the audit.
/s/PricewaterhouseCoopers LLP
Oklahoma City, Oklahoma
September 10, 2023
SOUTH TEXAS RICH PROPERTIES
STATEMENTS OF REVENUES AND DIRECT OPERATING EXPENSES
| | | | | | | | | | | |
| | Year Ended |
| $ in thousands | December 31, 2022 | | December 31, 2021 |
| Revenues | $ | 483,383 | | | $ | 347,489 | |
| Direct operating expenses | 189,018 | | | 146,379 | |
| Excess of revenues over direct operating expenses | $ | 294,365 | | | $ | 201,110 | |
See accompanying Notes to the Statements of Revenues and Direct Operating Expenses
SOUTH TEXAS RICH PROPERTIES
NOTES TO THE STATEMENTS OF REVENUES AND DIRECT OPERATING EXPENSES
1. Basis of Presentation
On August 11, 2023, Chesapeake Energy Corporation (“Chesapeake”), through its wholly owned subsidiaries Chesapeake Exploration, L.L.C., Chesapeake Operating, L.L.C., Chesapeake Energy Marketing, L.L.C. and Chesapeake Royalty, L.L.C., entered into a Purchase and Sale Agreement (the “Purchase Agreement”) with SilverBow Resources Operating, LLC, a subsidiary of SilverBow Resources, Inc. (“Buyer”) to sell a portion of its Eagle Ford assets (the “Transaction”). Under the terms of the Purchase Agreement, Chesapeake has agreed to sell approximately 42,000 net acres and approximately 540 wells, along with related property, plant and equipment (collectively, the “South Texas Rich Properties” or “the Properties”).
Under the terms and conditions of the Purchase Agreement, which has an economic effective date of February 1, 2023, the aggregate consideration to be paid to Chesapeake in the Transaction will consist of $700,000,000, comprised of (i) cash in the amount of $650,000,000, due at the closing of the Transaction, subject to certain purchase price adjustments and (ii) cash in the amount of $50,000,000 due on the first anniversary of the closing of the Transaction. Subject to satisfaction of certain commodity price triggers, Chesapeake may also receive additional cash consideration in an amount up to $50,000,000 shortly following the first anniversary of closing of the Transaction. Pursuant to the Purchase Agreement, upon the execution of the Purchase Agreement, the Buyer deposited $50,000,000 into escrow, which will be credited toward the cash consideration payable at the closing of the Transaction.
The accompanying Statements of Revenues and Direct Operating Expenses represent the direct undivided interests in the revenues and direct operating expenses associated with the producing wells in the Properties. The Statements of Revenues and Direct Operating Expenses have been derived from the historical financial records of Chesapeake. For purposes of these statements, all properties identified in the purchase and sale agreement are included herein. During the periods presented, the Properties were not accounted for or operated as a separate entity, subsidiary, segment or division by Chesapeake. Accordingly, a complete set of financial statements required by the Securities and Exchange Commission’s Regulation S-X, including a balance sheet and statement of cash flows, prepared in accordance with accounting principles generally accepted in the United States of America (“U.S. GAAP”) is not available or practicable to prepare for the Properties. The accompanying Statements of Revenues and Direct Operating Expenses vary from a complete income statement in accordance with U.S. GAAP in that they do not reflect certain expenses incurred in connection with the ownership and operation of the Properties, including but not limited to depreciation, depletion and amortization, impairments, accretion of asset retirement obligations, general and administrative expenses, interest expense and federal and state income taxes. These costs were not separately allocated to the working interests of the Properties in Chesapeake’s accounting records. In addition, these Statements of Revenues and Direct Operating Expenses are not indicative of the results of operations for the Properties on a go forward basis.
2. Summary of Significant Accounting Policies
Revenue Recognition
Revenue from the sale of natural gas, oil and NGL is recognized upon the transfer of control of the products, which is typically when the products are delivered to customers. Revenue is recognized net of royalties due to third parties in an amount that reflects the consideration Chesapeake expects to receive in exchange for those products.
Payment terms and conditions vary by contract type, although terms generally include a requirement of payment within 30 days. There are no significant judgments that significantly affect the amount or timing of revenue from contracts with customers.
Direct Operating Expenses
Direct operating expenses are recognized when incurred and consist of the direct expenses of operating the Properties. Direct operating expenses include lease operating expenses, production taxes and gathering, processing and transportation costs. Lease operating expenses include well repair expenses, saltwater disposal costs, facility maintenance expenses, and other field-related expenses. Lease operating expenses also include expenses directly associated with support personnel, support services, equipment and facilities directly related to natural gas and oil production activities.
Use of Estimates
The Statements of Revenues and Direct Operating Expenses are derived from the historical operating statements of Chesapeake. Accounting principles generally accepted in the United States of America require management to make estimates and assumptions that affect the amounts reported in the Statements of Revenues and Direct Operating Expenses. Actual results could differ from those estimates. Revenues and direct operating expenses relate to the historical net revenue interest and net working interest, respectively, in the Properties.
3. Subsequent Events
Chesapeake has evaluated subsequent events through September 10, 2023, the date the Statements of Revenues and Direct Operating Expenses were available to be issued, and has concluded that no events, except as described in Note 1, need to be reported.
SOUTH TEXAS RICH PROPERTIES
Supplementary Oil and Gas Information (Unaudited)
Natural Gas, Oil and NGL Reserve Quantities
Chesapeake’s petroleum engineers and independent petroleum engineering firms estimated all of Chesapeake's proved reserves as of December 31, 2022.
Proved natural gas, oil, and NGL reserves are those quantities of natural gas, oil, and NGL which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible – from a given date forward, from known reservoirs, and under existing economic conditions, operating methods, and government regulations – prior to the time at which contracts providing the right to operate expire, unless evidence indicates that renewal is reasonably certain, regardless of whether deterministic or probabilistic methods are used for the estimation. Existing economic conditions include prices and costs at which economic producibility from a reservoir is to be determined. Based on reserve reporting rules, the price is calculated using the average price during the 12-month period prior to the ending date of the period covered by the report, determined as an unweighted arithmetic average of the first-day-of-the-month price for each month within the period, unless prices are defined by contractual arrangements, excluding escalations based upon future conditions. A project to extract hydrocarbons must have commenced or the operator must be reasonably certain that it will commence the project within a reasonable time. The area of the reservoir considered as proved includes: (i) the area identified by drilling and limited by fluid contacts, if any, and (ii) adjacent undrilled portions of the reservoir that can, with reasonable certainty, be judged to be continuous with it and to contain economically producible natural gas or oil on the basis of available geoscience and engineering data. In the absence of data on fluid contacts, proved quantities in a reservoir are limited by the lowest known hydrocarbons as seen in a well penetration unless geoscience, engineering, or performance data and reliable technology establish a lower contact with reasonable certainty. Where direct observation from well penetrations has defined a highest known oil elevation and the potential exists for an associated natural gas cap, proved oil reserves may be assigned in the structurally higher portions of the reservoir only if geoscience, engineering, or performance data and reliable technology establish the higher contact with reasonable certainty. Reserves which can be produced economically through application of improved recovery techniques (including, but not limited to, fluid injection) are included in the proved classification when: (i) successful testing by a pilot project in an area of the reservoir with properties no more favorable than in the reservoir as a whole, the operation of an installed program in the reservoir or an analogous reservoir, or other evidence using reliable technology establishes the reasonable certainty of the engineering analysis on which the project or program was based; and (ii) the project has been approved for development by all necessary parties and entities, including governmental entities.
Developed natural gas, oil, and NGL reserves are reserves of any category that can be expected to be recovered through existing wells with existing equipment and operating methods where production can be initiated or restored with relatively low expenditure compared to the cost of drilling a new well.
SOUTH TEXAS RICH PROPERTIES
Supplementary Oil and Gas Information (Unaudited) – continued
Natural Gas, Oil and NGL Reserve Quantities - continued
The information provided below on the Properties' natural gas, oil, and NGL reserves is presented in accordance with regulations prescribed by the Securities and Exchange Commission. These reserve estimates are generally based upon extrapolation of historical production trends, analogy to similar properties, and volumetric calculations. Accordingly, these estimates will change as future information becomes available and as commodity prices change. These changes could be material and could occur in the near term.
Presented below is a summary of change in estimated reserves for the periods presented:
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| | Natural Gas | | Oil | | NGL | | Total |
| | (mcf) | | (Bbl) | | (Bbl) | | (mcfe) |
| December 31, 2022 | | | | | | | | |
| Proved reserves, beginning of period | | 285,251,264 | | | 28,654,405 | | | 38,955,911 | | | 690,913,165 | |
| Extensions, discoveries and other additions | | 11,755,384 | | | 1,984,143 | | | 1,509,852 | | | 32,719,354 | |
| Revisions of previous estimates | | 38,966,441 | | | 2,505,226 | | | 3,523,627 | | | 75,139,561 | |
| Production | | (20,909,750) | | | (2,637,577) | | | (2,645,702) | | | (52,609,426) | |
| Proved reserves, end of period | | 315,063,339 | | | 30,506,197 | | | 41,343,688 | | | 746,162,654 | |
| Proved developed reserves: | | | | | | | | |
| Beginning of period | | 183,596,848 | | | 20,348,596 | | | 25,086,112 | | | 456,205,097 | |
| End of period | | 229,553,642 | | | 22,276,526 | | | 30,178,639 | | | 544,284,628 | |
| Proved undeveloped reserves: | | | | | | | | |
| Beginning of period | | 101,654,416 | | | 8,305,809 | | | 13,869,799 | | | 234,708,068 | |
| End of period | | 85,509,697 | | | 8,229,671 | | | 11,165,049 | | | 201,878,026 | |
| December 31, 2021 | | | | | | | | |
| Proved reserves, beginning of period | | 148,585,717 | | | 18,022,345 | | | 20,648,406 | | | 380,610,225 | |
| Extensions, discoveries and other additions | | 82,671,630 | | | 6,466,685 | | | 10,681,462 | | | 185,560,515 | |
| Revisions of previous estimates | | 74,107,492 | | | 6,720,786 | | | 10,479,354 | | | 177,308,332 | |
| Production | | (20,113,575) | | | (2,555,411) | | | (2,853,311) | | | (52,565,907) | |
| Proved reserves, end of period | | 285,251,264 | | | 28,654,405 | | | 38,955,911 | | | 690,913,165 | |
| Proved developed reserves: | | | | | | | | |
| Beginning of period | | 148,585,717 | | | 18,022,345 | | | 20,648,406 | | | 380,610,225 | |
| End of period | | 183,596,848 | | | 20,348,596 | | | 25,086,112 | | | 456,205,097 | |
| Proved undeveloped reserves: | | | | | | | | |
| Beginning of period | | — | | | — | | | — | | | — | |
End of period(a) | | 101,654,416 | | | 8,305,809 | | | 13,869,799 | | | 234,708,068 | |
(a) As of December 31, 2022 and December 31, 2021, there were no PUDs that had remained undeveloped for five years or more.
The natural gas, oil and NGL prices used in computing the reserves as of December 31, 2022 were $6.36 per mcf, $93.67 per bbl and $43.58 per bbl, respectively, before basis differential adjustments. The natural gas, oil and NGL prices used in computing the reserves as of December 31, 2021 were $3.60 per mcf, $66.56 per bbl and $35.81 per bbl, respectively, before basis differential adjustments.
SOUTH TEXAS RICH PROPERTIES
Supplementary Oil and Gas Information (Unaudited) – continued
Standardized Measure of Discounted Cash Flows
The following summary sets forth the Properties' future net cash flows relating to proved natural gas, oil, and NGL reserves based on the standardized measure as of and for the years ended December 31, 2022 and 2021:
| | | | | | | | | | | | | | |
| $ in thousands | | 2022 | | 2021 |
Future cash inflows(a) | | $ | 5,120,415 | | | $ | 3,321,630 | |
| Future production costs | | (1,153,162) | | | (805,328) | |
Future development costs(b) | | (282,790) | | | (184,595) | |
| Future income tax provisions | | (743,654) | | | (473,873) | |
| Future net cash flows | | 2,940,809 | | | 1,857,834 | |
| Less effect of a 10% discount factor | | (1,462,980) | | | (899,630) | |
| Standardized Measure of discounted future net cash flows | | $ | 1,477,829 | | | $ | 958,204 | |
(a) Calculated using $6.36 per mcf, $93.67 per bbl of oil and $43.58 per bbl of NGL, respectively, before basis differential adjustments in 2022. Calculated using $3.60 per mcf, $66.56 per bbl of oil and $35.81 per bbl of NGL, respectively, before basis differential adjustments in 2021.
(b) Includes future plugging and abandonment costs.
| | | | | | | | | | | | | | |
| $ in thousands | | 2022 | | 2021 |
| Standardized measure, beginning of period | | $ | 958,204 | | | $ | 192,122 | |
Sales of natural gas and oil produced, net of production costs and gathering processing and transportation(a) | | (294,365) | | | (201,110) | |
| Net changes in prices and production costs | | 663,937 | | | 577,781 | |
| Extensions and discoveries, net of production and development costs | | 138,778 | | | 365,709 | |
| Changes in estimated future development costs | | (86,658) | | | (34,445) | |
| Previously estimated development costs incurred during the period | | 32,972 | | | 1,969 | |
| Revisions of previous quantity estimates | | 202,136 | | | 416,962 | |
| Accretion of discount | | 119,239 | | | 19,212 | |
| Net change in income taxes | | (148,648) | | | (236,188) | |
| Changes in production rates and other | | (107,766) | | | (143,808) | |
| Standardized Measure, end of period | | $ | 1,477,829 | | | $ | 958,204 | |
(a) Production costs includes severance and ad valorem taxes.
EXHIBIT 99.3
UNAUDITED PRO FORMA CONDENSED COMBINED FINANCIAL INFORMATION
Acquisition of Chesapeake's South Texas Assets
On November 30, 2023, SilverBow Resources, Inc. and its operating subsidiary, SilverBow Resources Operating, LLC (“SilverBow” or the “Company”), closed the previously announced Purchase and Sale Agreement (the “Purchase Agreement”) with Chesapeake Energy Corporation, through its wholly owned subsidiaries Chesapeake Exploration, L.L.C., Chesapeake Operating, L.L.C., Chesapeake Energy Marketing, L.L.C. and Chesapeake Royalty, L.L.C. (collectively “Chesapeake”), to buy Chesapeake's South Texas assets (the “South Texas Rich Properties”, the transaction collectively, the “ Chesapeake Transaction”). Under the terms and conditions of the Purchase Agreement, which has an economic effective date of February 1, 2023, the aggregate consideration for the Chesapeake Transaction consists of $700,000,000, comprised of cash in the amount of $650,000,000, paid at the closing of the Chesapeake Transaction, subject to certain purchase price adjustments and cash in the amount of $50,000,000 due on the first anniversary of the closing of the Chesapeake Transaction. The Chesapeake Transaction also includes a contingent earn-out payment contingent upon the average monthly settlement price of NYMEX West Texas Intermediate (“WTI”) crude oil for the 12 month period beginning on the first trading day of the next full calendar month following the closing date of the Chesapeake Transaction. If the average monthly settlement price of WTI during the 12 month period (a) exceeds $80 per barrel, SilverBow shall pay Chesapeake an amount equal to $50 million or (b) is between $75 per barrel and $80 per barrel, SilverBow shall pay Chesapeake an amount equal to $25 million. If the average monthly settlement price of WTI during the 12 month period is below $75 per barrel, SilverBow shall not owe Chesapeake a contingent earn-out payment.
The Chesapeake Transaction was funded with borrowings under the Company's First Amended and Restated Senior Secured Revolving Credit Agreement, dated as of April 19, 2017, and amended as of November 30, 2023 (the “Credit Facility”), among the Company, the lenders party thereto and JPMorgan Chase Bank, N.A., as administrative agent for the lenders, and proceeds from the issuance of additional second lien notes (“Second Lien Notes”) pursuant to the Company's Note Purchase Agreement, dated as of December 15, 2017 and amended as of November 30, 2023, among the Company, as issuer, U.S. Bank Trust Company, National Association (as successor-in-interest to U.S. Bank National Association), as agent and collateral agent, and the other parties thereto, and cash on hand. In conjunction with the Chesapeake Transaction, the Company has secured $425 million of incremental commitments under its Credit Facility from existing and new lenders, which increased lender commitments under the Credit Facility to $1.2 billion, and the Company’s Second Lien Notes were upsized by $350 million, which increased lender commitments under the Company’s Second Lien Notes to $500 million and extend the maturity date for the Second Lien Notes to December 15, 2028 (together, the “Related Financing”).
Acquisition of Sundance Assets
On June 30, 2022, SilverBow and its operating subsidiary, SilverBow Operating, closed the previously announced purchase and sale agreement dated April 13, 2022 with Sundance Energy, Inc. and certain affiliated entities (collectively, “Sundance”), thereby acquiring oil and gas assets in the Eagle Ford (the “Sundance Transaction” and together with the Chesapeake Transaction, the “Transactions”). After consideration of closing adjustments, total aggregate consideration was approximately $344.9 million, consisting primarily of $220.9 million in cash, 4,148,472 shares of our common stock valued at approximately $117.7 million based on the Company's share price on the closing date and contingent consideration with an estimated fair value of $7.4 million. The contingent consideration consisted of up to two earn-out payments of $7.5 million each, contingent upon the average monthly settlement price of NYMEX West Texas Intermediate crude oil exceeding $95 per barrel for the period from April 13, 2022 through December 31, 2022 which would trigger a payment of $7.5 million in 2023 and $85 per barrel for 2023 which would trigger a payment of $7.5 million in 2024 (the “2022 WTI Contingency Payout”). The contingent payout for the period of April 13, 2022 through December 31, 2022 did not materialize. As part of our post-close settlement, we settled the 2022 WTI Contingency during the second quarter of 2023. As such, we are no longer required to make a contingency payment related to the 2022 WTI Contingency Payout. We incurred approximately $6.8 million in transaction costs during the year ended December 31, 2022 related to the Sundance Transaction.
Unaudited Pro Forma Condensed Combined Financial Statements
The following unaudited pro forma condensed combined financial statements are derived from the historical consolidated financial statements of SilverBow, historical South Texas Rich Properties Statements of Revenues and Direct Operating Expenses related to the Chesapeake Transaction and from the historical financial activity of Sundance through June 30, 2022, the closing date of the Sundance Transaction.
The Company expects to account for the Chesapeake Transaction as an asset acquisition under accounting principles generally accepted in the United States of America, as the assets and operations acquired in the Chesapeake Transaction do not meet the definition of a business under the Financial Accounting Standards Board Accounting Standards Codification Topic 805, Business Combinations (referred to as “ASC 805”), since substantially all of the fair value of the assets acquired are concentrated in a single asset group.
Certain historical amounts of Sundance and Chesapeake's South Texas Rich Properties have been reclassified to conform to SilverBow’s financial statement presentation. The unaudited pro forma condensed combined balance sheet as of September 30, 2023 presented below was prepared as if the Chesapeake Transaction and related financing had occurred on September 30, 2023. The Sundance Transaction closed on June 30, 2022. Therefore, the Sundance Transaction is already included in SilverBow's condensed consolidated balance sheet as of September 30, 2023. The unaudited pro forma condensed combined statements of operations for the nine-month period ended September 30, 2023 and the year ended December 31, 2022 presented below were prepared as if the Transactions and Related Financing had occurred on January 1, 2022.
The unaudited pro forma condensed combined financial statements reflect the following pro forma adjustments related to the Transactions, based on available information and certain assumptions that SilverBow believes are reasonable:
•the Transactions, accounted for as asset acquisitions and the Related Financing;
•SilverBow’s related borrowing on its Credit Facility and issuance of Second Lien Notes, as applicable, to fund the cash portion of the Transactions;
•adjustments to conform the classification of expenses in Chesapeake’s South Texas Rich Properties historical statement of Revenues and Direct Operating Expenses to SilverBow’s classification for similar expenses;
•adjustments to conform the classification of revenues and expenses in Sundance’s historical statements of operations to SilverBow’s classification for similar revenues and expenses; and
•the recognition of estimated tax impacts of the pro forma adjustments.
Assumptions and estimates underlying the pro forma adjustments are described in the accompanying notes, which should be read in conjunction with the unaudited pro forma condensed combined financial statement. In SilverBow’s opinion, all adjustments that are necessary to present fairly the pro forma information have been made. The historical consolidated financial statements have been adjusted in the unaudited pro forma condensed combined financial statements to give effect to the Transactions and the Related Financing.
The Company expects to account for the Chesapeake Transaction as an asset acquisition under accounting principles generally accepted in the United States of America. The acquisition method of accounting as it relates to the Chesapeake Transaction is dependent upon certain valuations and other studies that, as of the date hereof, have yet to commence or progress to a stage where there is sufficient information for a definitive measure. SilverBow has performed a preliminary valuation analysis of the relative fair value of Chesapeake’s assets to be acquired and liabilities to be assumed and has made certain adjustments to the historical book values of the assets and liabilities of Chesapeake to reflect preliminary estimates of the relative fair value necessary to prepare the unaudited pro forma condensed combined financial statements. A final determination of the relative fair value of Chesapeake’s assets and liabilities will be based on the actual net tangible and intangible assets and liabilities of Chesapeake that exist as of the closing date of the Chesapeake Transaction and, therefore, could not be made prior to the completion of the Chesapeake Transaction. As a result of the foregoing, the pro forma adjustments are preliminary and are subject to change as additional information becomes available and as additional analysis is performed. The preliminary pro forma adjustments have been made solely for the purpose of providing the unaudited pro forma condensed combined financial statements presented below. SilverBow estimated the fair value of Chesapeake’s assets and liabilities based on discussions with Chesapeake’s management, preliminary valuation studies, due diligence, and information presented in Chesapeake’s historical financial statements. Any increases or decreases in the relative fair value of assets acquired and liabilities assumed upon completion of the final valuations will result in adjustments to the unaudited pro forma condensed combined balance sheet and/or statement of operations. The final purchase price allocation may be materially different than that reflected in the pro forma purchase price allocation presented herein.
The unaudited pro forma condensed combined financial information is not intended to represent what SilverBow’s financial position or results of operations would have been had the Transactions and Related Financing actually been consummated on the assumed dates nor does it purport to project the future operating results of the combined company following the Chesapeake Transaction. The unaudited pro forma condensed combined financial information does not reflect future events that may occur after the Chesapeake Transaction, including, but not limited to, the anticipated realization of ongoing savings from potential operating efficiencies, asset dispositions, cost savings, or economies of scale that the combined company may achieve with respect to the combined operations. Specifically, the unaudited pro forma condensed combined statement of operations does not include projected synergies expected to be achieved as a result of the Transactions and any associated costs that may be required to be incurred to
achieve the identified synergies. The unaudited pro forma condensed combined statements of operations also exclude the effects of costs of integration activities and asset dispositions that may result from the Transactions.
The unaudited pro forma condensed combined financial statement should be read in conjunction with the historical consolidated financial statements and accompanying notes contained in SilverBow’s Annual Report on Form 10-K for the year ended December 31, 2022, the historical consolidated financial statements and accompanying notes thereto of Sundance filed as Exhibit 99.1 to the Current Report on Form 8-K filed with the SEC on June 6, 2022, and Quarterly Report on Form 10-Q for the nine months ended September 30, 2023 and historical South Texas Rich Properties Statement of Revenues and Direct Operating Expenses and accompanying notes thereto filed as Exhibits 99.1 and 99.2 to this Current Report on Form 8-K/A of which this Exhibit 99.3 is a part.
| | | | | | | | | | | | | | | | | |
SilverBow Resources, Inc. and Subsidiary Pro Forma Condensed Combined Balance Sheet
As of September 30, 2023 (Unaudited) |
| (in thousands, except per share amounts) | SilverBow Historical | | Chesapeake Transaction Adjustments (Note 2) | | Pro Forma Combined |
| | | | | |
| ASSETS | | | | | |
| Current Assets: | | | | | |
| Cash and cash equivalents | $ | 1,697 | | | $ | — | | | $ | 1,697 | |
| Accounts receivable, net | 80,202 | | | — | | | 80,202 | |
| Fair value of commodity derivatives | 50,189 | | | — | | | 50,189 | |
| | | | | |
| Other current assets | 3,825 | | | — | | | 3,825 | |
| Total Current Assets | 135,913 | | | — | | | 135,913 | |
| Property and Equipment: | | | | | |
| Property and equipment, full cost method, including $27,821 of unproved property costs not being amortized at the end of the period | 2,861,267 | | | 673,018 | | (a) | 3,534,285 | |
| Less – Accumulated depreciation, depletion, amortization & impairment | (1,151,141) | | | — | | | (1,151,141) | |
| Property and Equipment, Net | 1,710,126 | | | 673,018 | | | 2,383,144 | |
| Right of Use Assets | 10,085 | | | 200 | | (a) | 10,285 | |
| Deposit and Other Fees for Oil and Gas Properties | 52,564 | | | (52,564) | | (b) | — | |
| Fair Value of Long-Term Commodity Derivatives | 14,180 | | | — | | | 14,180 | |
| | | | | |
| Other Long-Term Assets | 7,581 | | | — | | | 7,581 | |
| Total Assets | $ | 1,930,449 | | | $ | 620,654 | | | $ | 2,551,103 | |
| LIABILITIES AND STOCKHOLDERS’ EQUITY | | | | | |
| Current Liabilities: | | | | | |
| Accounts payable and accrued liabilities | $ | 74,731 | | | $ | — | | | $ | 74,731 | |
| Fair value of commodity derivatives | 32,752 | | | — | | | 32,752 | |
| Accrued capital costs | 56,424 | | | — | | | 56,424 | |
| Accrued interest | 2,976 | | | — | | | 2,976 | |
| Current lease liability | 5,507 | | | 59 | | (a) | 5,566 | |
| Undistributed oil and gas revenues | 22,462 | | | — | | | 22,462 | |
| Deferred acquisition payment | — | | | 50,000 | | (a) | 50,000 | |
| | | | | |
| Total Current Liabilities | 194,852 | | | 50,059 | | | 244,911 | |
| Long-Term Debt, Net | 645,096 | | | 547,241 | | (c) | 1,192,337 | |
| Non-Current Lease Liability | 4,604 | | | 141 | | (a) | 4,745 | |
| Deferred Tax Liabilities | 49,033 | | | — | | | 49,033 | |
| Asset Retirement Obligations | 9,840 | | | 634 | | (a) | 10,474 | |
| Fair Value of Long-Term Commodity Derivatives | 21,560 | | | 22,579 | | (a) | 44,139 | |
| Other Long-Term Liabilities | 922 | | | — | | | 922 | |
| | | | | |
| Stockholders' Equity: | | | | | |
| Preferred stock | — | | | — | | | — | |
| Common stock | 259 | | | — | | | 259 | |
| Additional paid-in capital | 677,473 | | | — | | | 677,473 | |
| Treasury stock, held at cost | (10,616) | | | — | | | (10,616) | |
| Retained earnings | 337,426 | | | — | | | 337,426 | |
| Total Stockholders’ Equity | 1,004,542 | | | — | | | 1,004,542 | |
| Total Liabilities and Stockholders’ Equity | $ | 1,930,449 | | | $ | 620,654 | | | $ | 2,551,103 | |
See accompanying notes to unaudited pro forma condensed combined financial information. |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| SilverBow Resources, Inc. and Subsidiary Pro Forma Condensed Combined Statement of Operations For Nine Months Ended September 30, 2023 (Unaudited) |
| (in thousands, except per share amounts) | SilverBow Historical | | Chesapeake Historical | | Chesapeake Reclassification Adjustments (Note 2) | | Transaction Accounting Adjustments (Note 2) | | Pro Forma Combined |
| Revenues: | | | | | | | | | |
| Oil and gas sales | $ | 440,317 | | | $ | 291,807 | | | $ | — | | | $ | — | | | $ | 732,124 | |
| | | | | | | | | |
| Operating Expenses: | | | | | | | | | |
| Direct Operating Expenses | — | | | 122,371 | | | (122,371) | | (d) | — | | | — | |
| General and administrative, net | 17,421 | | | — | | | — | | | — | | | 17,421 | |
| Depreciation, depletion, and amortization | 147,037 | | | — | | | — | | | 64,548 | | (f) | 211,585 | |
| Accretion of asset retirement obligations | 718 | | | — | | | — | | | — | | | 718 | |
| Lease operating expenses | 62,417 | | | — | | | 26,537 | | (d) | — | | | 88,954 | |
| Workovers | 2,263 | | | — | | | 908 | | (d) | — | | | 3,171 | |
| Transportation and gas processing | 37,001 | | | — | | | 76,151 | | (d) | — | | | 113,152 | |
| Severance and other taxes | 28,563 | | | — | | | 18,775 | | (d) | — | | | 47,338 | |
| Total Operating Expenses | 295,420 | | | 122,371 | | | — | | | 64,548 | | | 482,339 | |
| | | | | | | | | |
| Operating Income (Loss) | 144,897 | | | 169,436 | | | — | | | (64,548) | | | 249,785 | |
| | | | | | | | | |
| Non-Operating Income (Expense) | | | | | | | | | |
| Gain (loss) on commodity derivatives, net | 57,604 | | | — | | | — | | | — | | | 57,604 | |
| Interest expense, net | (54,746) | | | — | | | — | | | (47,369) | | (g) | (102,115) | |
| Other income (expense), net | 117 | | | — | | | — | | | — | | | 117 | |
| | | | | | | | | |
| Income (Loss) Before Income Taxes | 147,872 | | | 169,436 | | | — | | | (111,917) | | | 205,391 | |
| | | | | | | | | |
| Provision (Benefit) for Income Taxes | 33,214 | | | — | | | — | | | 12,798 | | (h) | 46,012 | |
| | | | | | | | | |
| Net Income (Loss) | $ | 114,658 | | | $ | 169,436 | | | $ | — | | | $ | (124,715) | | | $ | 159,379 | |
| | | | | | | | | |
| Per Share Amounts: | | | | | | | | | |
| | | | | | | | | |
| Basic: Loss Per Share | $ | 5.06 | | | $ | — | | | $ | — | | | $ | — | | | $ | 7.03 | |
| Diluted: Loss Per Share | $ | 5.02 | | | $ | — | | | $ | — | | | $ | — | | | $ | 6.97 | |
| | | | | | | | | |
| Weighted-Average Shares Outstanding - Basic | 22,677 | | | — | | | — | | | — | | | 22,677 | |
| | | | | | | | | |
| Weighted-Average Shares Outstanding - Diluted | 22,852 | | | — | | | — | | | — | | | 22,852 | |
See accompanying notes to unaudited pro forma condensed combined financial information. |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| SilverBow Resources, Inc. and Subsidiary Pro Forma Condensed Combined Statement of Operations For the Year Ended December 31, 2022 (Unaudited) |
| | | Sundance Historical | | | | | |
| | | | | | | | |
| (in thousands, except per share amounts) | SilverBow Historical | | January 1, 2022 Through March 31, 2022 | | Sundance Historical April 1, 2022 through June 30, 2022 | | Chesapeake Historical | | Sundance Reclassification Adjustments (Note 2) | | Chesapeake Reclassification Adjustments (Note 2) | | Sundance Transaction Adjustments (Note 2) | | Chesapeake Transaction Adjustments (Note 2) | | Pro Forma Combined |
| Revenues: | | | | | | | | | | | | | | | | | |
| Oil and gas sales | $ | 753,420 | | | $ | — | | | $ | — | | | $ | 483,383 | | | $ | 102,282 | | (e) | $ | — | | | $ | — | | | $ | — | | | $ | 1,339,085 | |
| Oil sales | | | 45,023 | | | 38,499 | | | — | | | (83,522) | | (e) | — | | | — | | | — | | | — | |
| Natural gas sales | | | 3,298 | | | 4,249 | | | — | | | (7,547) | | (e) | — | | | — | | | — | | | — | |
| Natural gas liquid sales | | | 6,384 | | | 4,829 | | | — | | | (11,213) | | (e) | — | | | — | | | — | | | — | |
| | | | | | | | | | | | | | | | | |
| Operating Expenses: | | | | | | | | | | | | | | | | | |
| Direct Operating Expenses | — | | | — | | | — | | | 189,018 | | | — | | | (189,018) | | (d) | — | | | — | | | — | |
| General and administrative, net | 21,395 | | | 1,727 | | | — | | | — | | | — | | | — | | | — | | | — | | | 23,122 | |
| Depreciation, depletion, and amortization | 133,982 | | | 273 | | | — | | | — | | | (137) | | (e) | — | | | 26,016 | | (f) | 65,756 | | (f) | 225,890 | |
| Accretion of asset retirement obligations | 534 | | | — | | | — | | | — | | | 137 | | (e) | — | | | — | | | — | | | 671 | |
| Lease operating expense | 55,329 | | | 9,510 | | | 8,746 | | | | | (2,016) | | (e) | 27,318 | | (d) | — | | | — | | | 98,887 | |
| Workovers | 1,655 | | | — | | | — | | | | | 2,016 | | (e) | 2,050 | | (d) | — | | | — | | | 5,721 | |
| Transportation and gas processing | 32,989 | | | 3,624 | | | 3,621 | | | | | — | | | 133,376 | | (d) | — | | | — | | | 173,610 | |
| Severance and other taxes | 41,761 | | | 3,807 | | | 3,856 | | | | | — | | | 26,274 | | (d) | — | | | — | | | 75,698 | |
| Exploration expense | — | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | | — | |
| Loss (gain) on commodity derivative financial instruments | — | | | 29,818 | | | — | | | — | | | (29,818) | | (e) | — | | | — | | | — | | | — | |
| Other expense, net | — | | | 208 | | | — | | | — | | | — | | | — | | | — | | | — | | | 208 | |
| Total Operating Expenses | 287,645 | | | 48,967 | | | 16,223 | | | 189,018 | | | (29,818) | | | — | | | 26,016 | | | 65,756 | | | 603,807 | |
| | | | | | | | | | | | | | | | | |
| Operating Income (Loss) | 465,775 | | | 5,738 | | | 31,354 | | | 294,365 | | | 29,818 | | | — | | | (26,016) | | | (65,756) | | | 735,278 | |
| | | | | | | | | | | | | | | | | |
| Non-Operating Income (Expense) | | | | | | | | | | | | | | | | | |
| Net gain (loss) on commodity derivatives | (73,885) | | | — | | | — | | | — | | | (29,818) | | (e) | — | | | — | | | — | | | (103,703) | |
| Interest expense, net | (41,948) | | | (2,289) | | | — | | | — | | | — | | | — | | | (2,720) | | (g) | (67,982) | | (g) | (114,939) | |
| Other income (expense), net | 95 | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | | 95 | |
| | | | | | | | | | | | | | | | | |
| Income (Loss) Before Income Taxes | 350,037 | | | 3,449 | | | 31,354 | | | 294,365 | | | — | | | — | | | (28,736) | | | (133,738) | | | 516,731 | |
| | | | | | | | | | | | | | | | | |
| Provision (Benefit) for Income Taxes | 9,600 | | | — | | | — | | | — | | | — | | | — | | | 1,350 | | (h) | 35,739 | | (h) | 46,689 | |
| | | | | | | | | | | | | | | | | |
| Net Income (Loss) | $ | 340,437 | | | $ | 3,449 | | | $ | 31,354 | | | $ | 294,365 | | | $ | — | | | $ | — | | | $ | (30,086) | | | $ | (169,477) | | | $ | 470,042 | |
| | | | | | | | | | | | | | | | | |
| Per Share Amounts: | | | | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | | | |
| Basic: Net Loss | $ | 17.24 | | | $ | — | | | $ | — | | | $ | — | | | $ | — | | | $ | — | | | $ | — | | | $ | — | | | $ | 23.80 | |
| | | | | | | | | | | | | | | | | |
| Diluted: Net Income Loss | $ | 16.94 | | | $ | — | | | $ | — | | | $ | — | | | $ | — | | | $ | — | | | $ | — | | | $ | — | | | $ | 23.39 | |
| | | | | | | | | | | | | | | | | |
| Weighted Average Shares Outstanding - Basic | 19,748 | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | | 19,748 | |
| | | | | | | | | | | | | | | | | |
| Weighted Average Shares Outstanding - Diluted | 20,097 | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | | 20,097 | |
See accompanying notes to unaudited pro forma condensed combined financial information. |
Notes to Unaudited Pro Forma Condensed Combined Financial Information
(1) Basis of Pro Forma Presentation
The accompanying unaudited pro forma condensed combined financial information was prepared based on the historical consolidated financial statements of the Company, the historical South Texas Rich Properties Statement of Revenues and Direct Operating Expenses related to the Chesapeake Transaction, and from the historical financial activity of Sundance through June 30, 2022, the closing date of the Sundance Transaction. The Unaudited Pro Forma Condensed Combined Statement of Operations for the nine months ended September 30, 2023 and the year ended December 31, 2022 were prepared assuming the Transactions and Related Financing occurred on January 1, 2022. The Unaudited Pro Forma Condensed Combined Balance Sheet at September 30, 2023 was prepared as if the Chesapeake Transaction and related financing had occurred on September 30, 2023. The Sundance Transaction closed on June 30, 2022. Therefore, the Sundance Transaction is already included in SilverBow's condensed consolidated balance sheet as of September 30, 2023.
The unaudited pro forma condensed combined financial statement reflects pro forma adjustments that are described in the accompanying notes and are based on available information and certain assumptions that SilverBow believes are reasonable, however, actual results may differ from those reflected in this statement. In SilverBow’s opinion, all adjustments that are necessary to present fairly the pro forma information have been made. The unaudited pro forma condensed combined financial statement does not purport to represent what SilverBow’s financial position or results of operations would have been if the Transactions had actually occurred on the dates indicated above, nor is it indicative of SilverBow’s future financial position or results of operations. The unaudited pro forma condensed combined financial statement should be read in conjunction with the historical consolidated financial statements and related notes of SilverBow and Chesapeake, as applicable, for the period presented.
(2) Pro Forma Adjustments
The Company expects to account for the Chesapeake Transaction as an asset acquisition under accounting principles generally accepted in the United States of America, as the assets and operations acquired in the Chesapeake Transaction do not meet the definition of a business under the Financial Accounting Standards Board Accounting Standards Codification Topic 805, Business Combinations (referred to as “ASC 805”), since substantially all of the fair value of the assets acquired are concentrated in a single asset group. The allocation of the preliminary estimated purchase price is based upon management’s estimates of and assumptions related to the relative fair value of assets to be acquired and liabilities to be assumed as of September 30, 2023 using currently available information. Due to the fact that the unaudited pro forma condensed combined financial information has been prepared based on these preliminary estimates, the final purchase price allocation and the resulting effect on financial position and results of operations may differ significantly from the pro forma amounts included herein. SilverBow expects to finalize its allocation of the purchase consideration as soon as practicable after completion of the Chesapeake Transaction.
The preliminary purchase price allocation is subject to change due to several factors, including but not limited to:
•changes in the estimated fair value of Chesapeake’s assets acquired and liabilities assumed as of the date of the closing of the Chesapeake Transaction, resulting from the finalization of SilverBow’s detailed valuation analysis, including changes in future oil and gas commodity prices, reserve estimates, interest rates and other factors;
•valuation of ASC 842 Leases as it relates to Chesapeake’s lease obligations and right of use assets expected to be recorded as part of purchase accounting upon the closing of the Chesapeake Transaction; and
•changes in the estimated fair value of the Contingent Consideration as of the date of the closing of the Chesapeake Transaction.
The following adjustments have been made to the accompanying unaudited pro forma condensed combined financial statements:
(a) Consideration for the Chesapeake Transaction was approximately $700.0 million, (i) cash in the amount of $650.0 million due at the closing of the transaction, subject to certain purchase price adjustments (estimated $58.0 million reduction in cash consideration below) and (ii) cash in the amount of $50.0 million due on the first anniversary of the closing of the transaction. The table below represents the preliminary allocation of the total cost of the Chesapeake Transaction to the assets acquired and liabilities assumed, as follows:
| | | | | | | | |
| | (in thousands) |
| Total Cost | | |
| Cash consideration | | $ | 592,000 | |
| Deferred acquisition payment | | 50,000 | |
| Fair value of contingent consideration | | 22,579 | |
| Total Consideration | | $ | 664,579 | |
| | |
| Transaction costs | | 7,805 | |
| | |
| Total Cost of Transaction | | $ | 672,384 | |
| | |
| Allocation of Total Cost of Transaction | | |
| Assets | | |
| Oil and gas properties | | $ | 673,018 | |
| Right of use assets | | 200 | |
| Total Assets | | 673,218 | |
| | |
| Liabilities | | |
| Asset retirement obligations | | 634 | |
| Current lease liability | | 59 | |
| Non-current lease liability | | 141 | |
| Total liabilities assumed | | $ | 834 | |
| Net Assets Acquired and Liabilities Assumed | | $ | 672,384 | |
(b) Reflects reclassification of the deposit and other acquisition related fees associated with the Chesapeake Transaction.
(c) Reflects incremental long-term debt calculated as the aggregate of the cash consideration and transaction costs less the deposit and other acquisition related fees (noted above).
(d) Chesapeake Reclassification and Conforming Adjustments:
•Reflects reclassification of approximately $122.4 million from Direct Operating Expenses to the respective operating expenses by category ($26.5 million to Lease operating expenses, $0.9 million to Workovers, $76.2 million to Transportation and gas processing and $18.8 million to Severance and other taxes) on the Pro Forma Condensed Combined Statement of Operations for the nine months ended September 30, 2023.
•Reflects reclassification of approximately $189.0 million from Direct Operating Expenses to the respective operating expenses by category ($27.3 million to Lease operating expenses, $2.1 million to Workovers, $133.4 million to Transportation and gas processing and $26.3 million to Severance and other taxes) on the Pro Forma Condensed Combined Statement of Operations for the year ended December 31, 2022.
(e) Sundance Reclassification and Conforming Adjustments:
•Reflects reclassification of approximately $102.3 million to oil and gas sales from the respective sales revenues by product ($83.6 million for oil sales, $7.5 million for gas sales and $11.2 million for NGL sales);
•Reflects reclassification of approximately $0.1 million from depreciation, depletion and amortization to accretion of asset retirement obligation;
•Reflects reclassification of approximately $2.0 million from lease operating expenses to workovers; and
•Reflects the reclassification of approximately $29.8 million of loss on commodity derivatives financial instruments from Operating Expenses to Non-Operating Income (Expense).
(f) Depreciation, depletion and amortization (“DD&A”) related to the Chesapeake Transaction for the nine months ended September 30, 2023 and for the year ended December 31, 2022 and Sundance Transaction for the year ended December 31, 2022 was calculated using the unit-of-production method under the full cost method of accounting, and adjusts DD&A for (i) the increase in DD&A reflecting the relative fair values and production volumes attributable to the Transactions and (ii) the revision to the Company’s DD&A rate reflecting the reserve volumes acquired in the Transactions.
(g) Interest expense associated with borrowings under the Company's Second Lien Notes and Credit Facility utilizing current interest rates, as applicable, for each Transaction.
(h) Adjustments to Income tax provision reflects the historical and adjusted Income (Loss) Before Income Taxes for each Transaction, as applicable, multiplied by 22.25% effective tax rate for the periods presented.
(3) Supplemental Oil and Gas Reserve Information
Estimated Quantities of Proved Oil and Natural Gas Reserves
The following tables present information regarding net proved oil and natural gas reserves attributable to the Company's interests in proved properties as of December 31, 2022 and 2021. The information set forth in the tables regarding historical reserves of the Company is based on proved reserves reports prepared in accordance with Securities and Exchange Commission’s (“SEC”) rules. H.J. Gruy and Associates, Inc. (“Gruy”), independent petroleum engineers, prepared the Company's proved reserves reports as of December 31, 2022 and 2021.
In addition, the following tables also set forth information as of December 31, 2022 and 2021 about the estimated net proved oil and natural gas reserves attributable to the Chesapeake Transaction, and the pro forma estimated net proved oil and natural gas reserves as if the Chesapeake Transaction had occurred on January 1, 2021. The reserve estimates attributable to the Chesapeake Transaction at December 31, 2022 and 2021 presented in the table below were prepared based upon information provided by Chesapeake and was prepared in accordance with the authoritative guidance of the FASB and the SEC on oil and natural gas reserve estimation and disclosures.
In addition, the following tables also set forth information as of December 31, 2021 about the estimated net proved oil and natural gas reserves attributable to the Sundance Transaction, and the pro forma estimated net proved oil and natural gas reserves as if the Sundance Transaction had occurred on January 1, 2021. The Sundance Transaction closed on June 30, 2022. Therefore, the net proved oil and natural gas reserves attributable to the Sundance Transaction are reflected in SilverBow's historical reserves as of December 31, 2022. The reserve estimates attributable to the Sundance Transaction at December 31, 2021 presented in the table below were prepared based upon information provided by Sundance and was prepared in accordance with the authoritative guidance of the FASB and the SEC on oil and natural gas reserve estimation and disclosures.
Reserve estimates are inherently imprecise and are generally based upon extrapolation of historical production trends, analogy to similar properties and volumetric calculations. Accordingly, reserve estimates are expected to change, and such changes could be material and occur in the near term as future information becomes available.
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | | Natural Gas (Mcf) |
| | | SilverBow Historical | | Chesapeake Transaction | | Sundance Transaction | | Sundance Transaction Adjustments | | Pro Forma Combined |
| Estimates of Proved Reserves | | | | | | | | | | |
| December 31, 2020 | | 948,094,943 | | | 148,585,717 | | | 50,144,876 | | | — | | | 1,146,825,536 | |
| Revisions | | (199,625,710) | | | 74,107,492 | | | (7,691,299) | | | — | | | (133,209,517) | |
| Extensions, discoveries and other additions | | 324,625,474 | | | 82,671,630 | | | 19,805,640 | | | — | | | 427,102,744 | |
| Purchases of minerals in place | | 142,794,045 | | | — | | | — | | | — | | | 142,794,045 | |
| Production | | (60,509,606) | | | (20,113,575) | | | (2,463,333) | | | — | | | (83,086,514) | |
| December 31, 2021 | | 1,155,379,146 | | | 285,251,264 | | | 59,795,884 | | | — | | | 1,500,426,294 | |
| Revisions | | 561,425 | | | 38,966,441 | | | — | | | — | | | 39,527,866 | |
| Extensions, discoveries and other additions | | 514,492,260 | | | 11,755,384 | | | — | | | — | | | 526,247,644 | |
| Purchases of minerals in place | | 126,849,989 | | | — | | | — | | | (59,795,884) | | (a) | 67,054,105 | |
| Sales of minerals in place | | (772,177) | | | — | | | (59,795,884) | | (a) | 59,795,884 | | (a) | (772,177) | |
| Production | | (70,958,470) | | | (20,909,750) | | | — | | | — | | | (91,868,220) | |
| December 31, 2022 | | 1,725,552,173 | | | 315,063,339 | | | — | | | — | | | 2,040,615,512 | |
| | | | | | | | | | |
| Proved Developed Reserves | | | | | | | | | | |
| December 31, 2020 | | 415,390,459 | | | 148,585,717 | | | 22,666,672 | | | — | | | 586,642,848 | |
| December 31, 2021 | | 525,736,580 | | | 183,596,848 | | | 15,499,234 | | | — | | | 724,832,662 | |
| December 31, 2022 | | 695,481,580 | | | 229,553,642 | | | — | | | — | | | 925,035,222 | |
| | | | | | | | | | |
| Proved Undeveloped Reserves | | | | | | | | | | |
| December 31, 2020 | | 532,704,484 | | | — | | | 27,478,205 | | | — | | | 560,182,689 | |
| December 31, 2021 | | 629,642,566 | | | 101,654,416 | | | 44,296,646 | | | — | | | 775,593,628 | |
| December 31, 2022 | | 1,030,070,593 | | | 85,509,697 | | | — | | | — | | | 1,115,580,290 | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | | Oil (Bbl) |
| | | SilverBow Historical | | Chesapeake Transaction | | Sundance Transaction | | Sundance Transaction Adjustments | | Pro Forma Combined |
| Estimates of Proved Reserves | | | | | | | | | | |
| December 31, 2020 | | 12,531,501 | | | 18,022,345 | | | 28,897,502 | | | — | | | 59,451,348 | |
| Revisions | | (1,644,367) | | | 6,720,786 | | | (5,250,851) | | | — | | | (174,432) | |
| Extensions, discoveries and other additions | | 3,930,631 | | | 6,466,685 | | | 5,501,816 | | | — | | | 15,899,132 | |
| Purchases of minerals in place | | 10,942,051 | | | — | | | — | | | — | | | 10,942,051 | |
| Production | | (1,461,657) | | | (2,555,411) | | | (1,554,079) | | | — | | | (5,571,147) | |
| December 31, 2021 | | 24,298,159 | | | 28,654,405 | | | 27,594,388 | | | — | | | 80,546,952 | |
| Revisions | | (1,097,823) | | | 2,505,226 | | | — | | | — | | | 1,407,403 | |
| Extensions, discoveries and other additions | | 5,423,639 | | | 1,984,143 | | | — | | | — | | | 7,407,782 | |
| Purchases of minerals in place | | 26,393,737 | | | — | | | — | | | (27,594,388) | | (a) | (1,200,651) | |
| Sales of minerals in place | | (194,839) | | | — | | | (27,594,388) | | (a) | 27,594,388 | | (a) | (194,839) | |
| Production | | (2,633,679) | | | (2,637,577) | | | — | | | | | (5,271,256) | |
| December 31, 2022 | | 52,189,194 | | | 30,506,197 | | | — | | | — | | | 82,695,391 | |
| | | | | | | | | | |
| Proved Developed Reserves | | | | | | | | | | |
| December 31, 2020 | | 6,962,826 | | | 18,022,345 | | | 12,156,565 | | | — | | | 37,141,736 | |
| December 31, 2021 | | 9,692,076 | | | 20,348,596 | | | 9,676,355 | | | — | | | 39,717,027 | |
| December 31, 2022 | | 23,360,025 | | | 22,276,526 | | | — | | | — | | | 45,636,551 | |
| | | | | | | | | | |
| Proved Undeveloped Reserves | | | | | | | | | | |
| December 31, 2020 | | 5,568,676 | | | — | | | 16,740,936 | | | — | | | 22,309,612 | |
| December 31, 2021 | | 14,606,082 | | | 8,305,809 | | | 17,918,029 | | | — | | | 40,829,920 | |
| December 31, 2022 | | 28,829,169 | | | 8,229,671 | | | — | | | — | | | 37,058,840 | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | | Natural Gas Liquids (Bbl) |
| | | SilverBow Historical | | Chesapeake Transaction | | Sundance Transaction | | Sundance Transaction Adjustments | | Pro Forma Combined |
| Estimates of Proved Reserves | | | | | | | | | | |
| December 31, 2020 | | 13,855,188 | | | 20,648,406 | | | 8,171,134 | | | — | | | 42,674,728 | |
| Revisions | | 1,836,746 | | | 10,479,354 | | | (855,428) | | | — | | | 11,460,672 | |
| Extensions, discoveries and other additions | | 1,860,900 | | | 10,681,462 | | | 2,940,777 | | | — | | | 15,483,139 | |
| Purchases of minerals in place | | 3,019,773 | | | — | | | — | | | — | | | 3,019,773 | |
| Production | | (1,472,222) | | | (2,853,311) | | | (424,929) | | | — | | | (4,750,462) | |
| December 31, 2021 | | 19,100,385 | | | 38,955,911 | | | 9,831,554 | | | — | | | 67,887,850 | |
| Revisions | | 548,238 | | | 3,523,627 | | | — | | | | | 4,071,865 | |
| Extensions, discoveries and other additions | | 3,366,839 | | | 1,509,852 | | | — | | | | | 4,876,691 | |
| Purchases of minerals in place | | 11,709,713 | | | — | | | — | | | (9,831,554) | | (a) | 1,878,159 | |
| Sales of minerals in place | | (119,211) | | | — | | | (9,831,554) | | (a) | 9,831,554 | | (a) | (119,211) | |
| Production | | (1,949,894) | | | (2,645,702) | | | — | | | | | (4,595,596) | |
| December 31, 2022 | | 32,656,070 | | | 41,343,688 | | | — | | | — | | | 73,999,758 | |
| | | | | | | | | | |
| Proved Developed Reserves | | | | | | | | | | |
| December 31, 2020 | | 8,163,666 | | | 20,648,406 | | | 3,401,266 | | | — | | | 32,213,338 | |
| December 31, 2021 | | 12,390,263 | | | 25,086,112 | | | 2,525,000 | | | — | | | 40,001,375 | |
| December 31, 2022 | | 19,522,859 | | | 30,178,639 | | | — | | | — | | | 49,701,498 | |
| | | | | | | | | | |
| Proved Undeveloped Reserves | | | | | | | | | | |
| December 31, 2020 | | 5,691,522 | | | — | | | 4,769,867 | | | — | | | 10,461,389 | |
| December 31, 2021 | | 6,710,122 | | | 13,869,799 | | | 7,306,553 | | | — | | | 27,886,474 | |
| December 31, 2022 | | 13,133,211 | | | 11,165,049 | | | — | | | — | | | 24,298,260 | |
(a) Amounts and adjustments reflect the purchase and sale of minerals in place associated with the Sundance Transaction, which closed on June 30, 2022.
Changes in commodity prices may significantly impact the Company’s estimates of oil and natural gas reserves. Sustained lower commodity prices can reduce the quantity of the Company’s reserves by causing the economic limit of the proved developed and proved undeveloped wells (the point at which the costs to operate exceed the value of estimated future production, assuming constant prices and costs under SEC rules) to occur earlier in their productive lives than would be the case with higher prices. The undeveloped reserves may also be reduced by the elimination of wells because they would not meet the investment criteria to be economically producible at such prices and costs. The proved undeveloped reserves may also be eliminated by the deferral of drilling of otherwise economic wells beyond the five year proved reserve development horizon as a result of revisions to the Company’s development plan adopted in response to lower prices or otherwise.
Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves
The following table presents the Standardized Measure of Discounted Future Net Cash Flows relating to the proved oil and natural gas reserves of the Company, Chesapeake and Sundance on a pro forma combined basis as of December 31, 2022 and 2021. The Standardized Measure shown below represents estimates only and should not be construed as the current market value of the Company’s estimated oil and natural gas reserves or those acquired estimated oil and natural gas reserves attributable to the Chesapeake Transaction.
| | | | | | | | | | | | | | | | | | | | | |
| | | December 31, 2022 | |
| | | SilverBow Historical | | Chesapeake Transaction | | Pro Forma Combined | |
| | (In thousands) | |
| Future gross revenues | | $ | 16,660,470 | | | $ | 5,120,415 | | | $ | 21,780,885 | | |
| Future production costs | | (4,039,248) | | | (1,153,162) | | | (5,192,410) | | |
| Future development costs | | (2,063,508) | | | (282,790) | | | (2,346,298) | | |
| Future income taxes | | (1,953,345) | | | (743,654) | | | (2,696,999) | | |
| Future net cash flows | | 8,604,369 | | | 2,940,809 | | | 11,545,178 | | |
| Discount at 10% per annum | | (4,564,123) | | | (1,462,980) | | | (6,027,103) | | |
| Standardized Measure of discounted future net cash flows | | $ | 4,040,246 | | | $ | 1,477,829 | | | $ | 5,518,075 | | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | | December 31, 2021 | |
| | | SilverBow Historical | | Chesapeake Transaction | | Sundance Transaction | | Pro Forma Combined | |
| | (In thousands) | |
| Future gross revenues | | $ | 6,370,628 | | | $ | 3,321,630 | | | $ | 2,188,156 | | | $ | 11,880,414 | | |
| Future production costs | | (1,853,856) | | | (805,328) | | | (858,212) | | | (3,517,396) | | |
| Future development costs | | (753,046) | | | (184,595) | | | (533,540) | | | (1,471,181) | | |
| Future income taxes | | (584,613) | | | (473,873) | | | (47,186) | | | (1,105,672) | | |
| Future net cash flows | | 3,179,113 | | | 1,857,834 | | | 749,218 | | | 5,786,165 | | |
| Discount at 10% per annum | | (1,620,651) | | | (899,630) | | | (336,350) | | | (2,856,631) | | |
| Standardized Measure of discounted future net cash flows | | $ | 1,558,462 | | | $ | 958,204 | | | $ | 412,868 | | | $ | 2,929,534 | | |
The following table sets forth the principal changes in the Standardized Measure of discounted future net cash flows applicable to estimated net proved oil and natural gas reserves of the Company, the Chesapeake Transaction and of the Sundance Transaction on a pro forma combined basis as of December 31, 2022 and 2021:
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | SilverBow Historical | | Chesapeake Transaction | | Sundance Transaction | | Sundance Transaction Adjustments | | Pro Forma Combined |
| | (In thousands) |
| January 1, 2022 balance | | $ | 1,558,462 | | | $ | 958,204 | | | $ | 412,868 | | | $ | — | | | $ | 2,929,534 | |
| Net changes in prices, net of production costs | | 1,852,439 | | | 663,937 | | | — | | | — | | | 2,516,376 | |
| Net changes in future development costs | | (208,188) | | | (86,658) | | | — | | | — | | | (294,846) | |
| Net changes due to revisions in quantity estimates | | (4,218) | | | 202,136 | | | — | | | — | | | 197,918 | |
| Accretion of discount | | 181,678 | | | 119,239 | | | — | | | — | | | 300,917 | |
| Other | | (176,112) | | | (107,766) | | | — | | | — | | | (283,878) | |
| Total revisions | | 1,645,599 | | | 790,888 | | | — | | | — | | | 2,436,487 | |
| | | | | | | | | | |
| New field discoveries and extensions, net of future production and development costs | | 968,093 | | | 138,778 | | | — | | | — | | | 1,106,871 | |
| Purchase of reserves | | 1,051,869 | | | — | | | — | | | (412,868) | | (a) | 639,001 | |
| Sales of minerals in place | | (5,209) | | | — | | | (412,868) | | (a) | 412,868 | | (a) | (5,209) | |
| Sales of oil and natural gas produced, net of production costs | | (621,686) | | | (294,365) | | | — | | | — | | | (916,051) | |
| Previously estimated development costs | | 108,566 | | | 32,972 | | | — | | | — | | | 141,538 | |
| Net change in income taxes | | (665,448) | | | (148,648) | | | — | | | — | | | (814,096) | |
| Net change in Standardized Measure of discounted future net cash flows | | 2,481,784 | | | 519,625 | | | (412,868) | | | — | | | 2,588,541 | |
| December 31, 2022 balance | | $ | 4,040,246 | | | $ | 1,477,829 | | | $ | — | | | $ | — | | | $ | 5,518,075 | |
(a) Amounts and adjustments reflect the purchase and sale of minerals in place associated with the Sundance Transaction, which closed on June 30, 2022.
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| | SilverBow Historical | | Chesapeake Transaction | | Sundance Transaction | | Pro Forma Combined |
| | (In thousands) |
| January 1, 2021 balance | | $ | 512,952 | | | $ | 192,122 | | | 230,804 | | | $ | 935,878 | |
| Net changes in prices, net of production costs | | 781,786 | | | 577,781 | | | 272,732 | | | 1,632,299 | |
| Net changes in future development costs | | 1,569 | | | (34,445) | | | (42,547) | | | (75,423) | |
| Net changes due to revisions in quantity estimates | | (43,379) | | | 416,962 | | | (19,717) | | | 353,866 | |
| Accretion of discount | | 52,627 | | | 19,212 | | | 23,109 | | | 94,948 | |
| Other | | 29,303 | | | (143,808) | | | (30,765) | | | (145,270) | |
| Total revisions | | 821,906 | | | 835,702 | | | 202,812 | | | 1,860,420 | |
| | | | | | | | |
| New field discoveries and extensions, net of future production and development costs | | 400,008 | | | 365,709 | | | 64,454 | | | 830,171 | |
| Purchase of reserves | | 345,300 | | | — | | | — | | | 345,300 | |
| Sales of minerals in place | | — | | | — | | | — | | | — | |
| Sales of oil and natural gas produced, net of production costs | | (336,028) | | | (201,110) | | | (83,194) | | | (620,332) | |
| Previously estimated development costs | | 59,318 | | | 1,969 | | | 22,035 | | | 83,322 | |
| Net change in income taxes | | (244,994) | | | (236,188) | | | (24,043) | | | (505,225) | |
| Net change in Standardized Measure of discounted future net cash flows | | 1,045,510 | | | 766,082 | | | 182,064 | | | 1,993,656 | |
| December 31, 2021 balance | | $ | 1,558,462 | | | $ | 958,204 | | | $ | 412,868 | | | $ | 2,929,534 | |
Document and Entity Information
|
Dec. 05, 2023 |
| Cover [Abstract] |
|
| Document Period End Date |
Nov. 30, 2023
|
| Document Type |
8-K/A
|
| Entity Registrant Name |
SilverBow Resources, Inc.
|
| Entity Incorporation, State or Country Code |
DE
|
| Entity File Number |
001-8754
|
| Entity Tax Identification Number |
20-3940661
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| Entity Address, Address Line One |
920 Memorial City Way
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Suite
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| Entity Address, City or Town |
Houston
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TX
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77024
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281
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874-2700
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false
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false
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false
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false
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Common Stock, par value $0.01 per share
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SBOW
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NYSE
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| X |
- DefinitionA unique 10-digit SEC-issued value to identify entities that have filed disclosures with the SEC. It is commonly abbreviated as CIK. Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Exchange Act
-Number 240
-Section 12
-Subsection b-2
| Name: |
dei_EntityCentralIndexKey |
| Namespace Prefix: |
dei_ |
| Data Type: |
dei:centralIndexKeyItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionIndicate if registrant meets the emerging growth company criteria. Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Exchange Act
-Number 240
-Section 12
-Subsection b-2
| Name: |
dei_EntityEmergingGrowthCompany |
| Namespace Prefix: |
dei_ |
| Data Type: |
xbrli:booleanItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionCommission file number. The field allows up to 17 characters. The prefix may contain 1-3 digits, the sequence number may contain 1-8 digits, the optional suffix may contain 1-4 characters, and the fields are separated with a hyphen.
| Name: |
dei_EntityFileNumber |
| Namespace Prefix: |
dei_ |
| Data Type: |
dei:fileNumberItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionTwo-character EDGAR code representing the state or country of incorporation.
| Name: |
dei_EntityIncorporationStateCountryCode |
| Namespace Prefix: |
dei_ |
| Data Type: |
dei:edgarStateCountryItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionThe exact name of the entity filing the report as specified in its charter, which is required by forms filed with the SEC. Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Exchange Act
-Number 240
-Section 12
-Subsection b-2
| Name: |
dei_EntityRegistrantName |
| Namespace Prefix: |
dei_ |
| Data Type: |
xbrli:normalizedStringItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionThe Tax Identification Number (TIN), also known as an Employer Identification Number (EIN), is a unique 9-digit value assigned by the IRS. Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Exchange Act
-Number 240
-Section 12
-Subsection b-2
| Name: |
dei_EntityTaxIdentificationNumber |
| Namespace Prefix: |
dei_ |
| Data Type: |
dei:employerIdItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionLocal phone number for entity.
| Name: |
dei_LocalPhoneNumber |
| Namespace Prefix: |
dei_ |
| Data Type: |
xbrli:normalizedStringItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionBoolean flag that is true when the Form 8-K filing is intended to satisfy the filing obligation of the registrant as pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act. Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Exchange Act
-Number 240
-Section 13e
-Subsection 4c
| Name: |
dei_PreCommencementIssuerTenderOffer |
| Namespace Prefix: |
dei_ |
| Data Type: |
xbrli:booleanItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionBoolean flag that is true when the Form 8-K filing is intended to satisfy the filing obligation of the registrant as pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act. Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Exchange Act
-Number 240
-Section 14d
-Subsection 2b
| Name: |
dei_PreCommencementTenderOffer |
| Namespace Prefix: |
dei_ |
| Data Type: |
xbrli:booleanItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionTitle of a 12(b) registered security. Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Exchange Act
-Number 240
-Section 12
-Subsection b
| Name: |
dei_Security12bTitle |
| Namespace Prefix: |
dei_ |
| Data Type: |
dei:securityTitleItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionName of the Exchange on which a security is registered. Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Exchange Act
-Number 240
-Section 12
-Subsection d1-1
| Name: |
dei_SecurityExchangeName |
| Namespace Prefix: |
dei_ |
| Data Type: |
dei:edgarExchangeCodeItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionBoolean flag that is true when the Form 8-K filing is intended to satisfy the filing obligation of the registrant as soliciting material pursuant to Rule 14a-12 under the Exchange Act. Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Exchange Act
-Section 14a
-Number 240
-Subsection 12
| Name: |
dei_SolicitingMaterial |
| Namespace Prefix: |
dei_ |
| Data Type: |
xbrli:booleanItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionTrading symbol of an instrument as listed on an exchange.
| Name: |
dei_TradingSymbol |
| Namespace Prefix: |
dei_ |
| Data Type: |
dei:tradingSymbolItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionBoolean flag that is true when the Form 8-K filing is intended to satisfy the filing obligation of the registrant as written communications pursuant to Rule 425 under the Securities Act. Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Securities Act
-Number 230
-Section 425
| Name: |
dei_WrittenCommunications |
| Namespace Prefix: |
dei_ |
| Data Type: |
xbrli:booleanItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
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