| Basis of Presentation and Significant Accounting Policies, Voluntary Reorganization under Chapter 11 Cases | Basis of Presentation and Significant Accounting Policies Basis of Presentation and Consolidation Our consolidated financial statements are prepared in accordance with United States generally accepted accounting principles (“U.S. GAAP”) and include the accounts of all consolidated subsidiaries after the elimination of all significant intercompany accounts and transactions. On October 3, 2019, we and certain of our direct and indirect subsidiaries filed voluntary petitions in the United States Bankruptcy Court for the Southern District of Texas seeking relief under chapter 11 of title 11 of the United States Code. The consolidated financial statements included herein have been prepared as if we were a going concern and in accordance with Financial Accounting Standards Board (“FASB”) Accounting Standards Codification (“ASC”) Topic No. 852, Reorganizations . For a further discussion of our Chapter 11 filing, see Note 1A. We consolidate entities when we have the ability to control the operating and financial decisions of the entity or when we have a significant interest in the entity that gives us the ability to direct the activities that are significant to that entity. The determination of our ability to control, direct or exert significant influence over an entity involves the use of judgment. We are engaged in the exploration for and the acquisition, development, and production of oil, natural gas and NGLs in the United States. Our oil and natural gas properties are managed as a single operating segment rather than through discrete operating segments or business units. We track basic operational data by area and allocate capital resources on a project-by-project basis across our entire asset base without regard to individual areas. We assess financial performance as a single enterprise and not on a geographical area basis. New Accounting Pronouncements Issued But Not Yet Adopted Income Taxes. In December 2019, the FASB issued ASU No. 2019-12, Income Taxes (Topic 740): Simplifying the Accounting for Income Taxes , which is intended to simplify various aspects related to accounting for income taxes by eliminating certain exceptions within ASC 740, Income Taxes, and clarifying certain aspects of the current guidance. This standard is effective beginning for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2020, with early adoption permitted. The Company is in the process of assessing the impact the adoption of this guidance may have on our consolidated financial statements. Significant Accounting Policies Use of Estimates The preparation of our financial statements requires the use of estimates and assumptions that affect the amounts we report as assets, liabilities, revenues and expenses and our disclosures in these financial statements. Actual results can, and often do, differ from those estimates. Revenue Recognition Our revenues are generated primarily through the physical sale of oil, natural gas and NGLs to third party customers at spot or market prices under both short and long-term contracts. We recognize revenue upon satisfaction of our contractual performance obligation requiring us to deliver oil, natural gas and NGLs to a delivery point. Our performance obligation is satisfied upon transfer of control of the commodity to the customer. Transfer of control varies depending on the product and delivery method, but typically occurs when delivery and passage of title and risk of loss have occurred at a pipeline or gathering line delivery point interconnect when delivered via pipeline or at the wellhead or tank battery to purchasers who transport the oil via truck. Realized prices for each barrel of oil, MMcf of natural gas or MMBtu of NGLs are based upon index prices (WTI, LLS, Henry Hub and Mt. Belvieu) or refiners' posted prices at various delivery points across our producing basins. Realized transaction prices received (not considering the effects of hedges) are generally less than the stated index price as a result of contractual deductions, differentials from the index to the delivery point, adjustments for time, and/or discounts for quality or grade. Revenue is recorded net of any royalty interests or other profit interests in the produced product. Revenues related to products delivered, but not yet billed, are estimated each month. These estimates are based on contract data, commodity prices and preliminary throughput and allocation measurements. When actual sales volumes exceed our entitled share of sales volumes, an overproduced imbalance occurs. To the extent the overproduced imbalance exceeds our share of the remaining estimated proved natural gas reserves for a given property, we record a liability. Costs associated with the transportation and delivery of production between the wellhead and its intended sale location are generally included in transportation costs. We also purchase and sell oil and natural gas on a monthly basis to manage our overall oil and natural gas production and sales. These transactions are undertaken to optimize prices we receive for our oil and natural gas, to physically move oil and gas to its intended sales point, or to manage firm transportation agreements. Revenue related to these transactions are recorded in oil and natural gas sales in operating revenues and associated purchases reflected in oil and natural gas purchases in operating expenses in our consolidated income statements. For the years ended December 31, 2019 and 2018 , we had two and three customers, respectively, that individually accounted for 10 percent or more of our total revenues. The loss of any one customer would not have an adverse effect on our ability to sell our oil, natural gas and NGLs production. While most of our physical production is priced off of market indices, we actively manage the volatility of market pricing through our risk management program whereby we enter into financial derivatives contracts. All of our derivatives are marked-to-market each period. The change in the fair value of our commodity-based derivatives, as well as any realized amounts, are reflected in operating revenues as financial derivative revenues (see Derivatives below and Note 5). Cash and Cash Equivalents and Restricted Cash We consider short-term investments with an original maturity of less than three months to be cash equivalents. As of December 31, 2019 , we had $1 million in restricted cash. As of December 31, 2018, we had no restricted cash. Allowance for Doubtful Accounts We establish provisions for losses on accounts receivable and for natural gas imbalances with other parties if we determine that we will not collect all or part of the outstanding balance. We regularly review collectability and establish or adjust our allowance as necessary using the specific identification method. Oil and Natural Gas Properties We account for oil and natural gas properties in accordance with the successful efforts method of accounting for oil and natural gas exploration and development activities. Under the successful efforts method, we capitalize (i) lease acquisition costs, all development costs and exploratory drilling costs until results are determined, (ii) certain internal costs directly identified with the acquisition, successful drilling of exploratory wells and development activities, and (iii) interest costs related to financing oil and natural gas projects actively being developed until the projects are evaluated or substantially complete and ready for their intended use if the projects were evaluated as successful. Non-drilling exploratory costs, including certain geological and geophysical costs such as seismic costs and delay rentals, are expensed as incurred. We provide for depreciation, depletion, and amortization on the basis of common geological structure or stratigraphic conditions applied to total capitalized costs, plus future abandonment costs, net of salvage value, using the unit of production method. Lease acquisition costs are amortized over total proved reserves, while other exploratory drilling and all developmental costs are amortized over total proved developed reserves. We evaluate capitalized costs related to proved properties upon a triggering event to determine if impairment of such properties is necessary. Our evaluation of recoverability is made on the basis of common geological structure or stratigraphic conditions and considers estimated future cash flows primarily from all proved developed (producing and non-producing) and proved undeveloped reserves in comparison to the carrying amount of the proved properties. Estimated future cash flows are determined based on estimates of future oil and gas production, estimated or published commodity prices as of the date of the estimate, adjusted for geographical location, contractual and quality price differentials, and estimates of future operating and development costs. If the carrying amount of a property exceeds these estimated undiscounted future cash flows, the carrying amount is reduced to its estimated fair value through a charge to income. Fair value is calculated by discounting the estimated future cash flows using a risk-adjusted discount rate. This discount rate is based on rates utilized by market participants that are commensurate with the risks inherent in the development and production of the underlying crude oil and natural gas. Leasehold acquisition costs associated with non-producing areas are also assessed for impairment based on our estimated drilling plans and anticipated capital expenditures related to potential lease expirations. Property, Plant and Equipment (Other than Oil and Natural Gas Properties) Our property, plant and equipment, other than our assets accounted for under the successful efforts method, are recorded at their original cost of construction or, upon acquisition, at the fair value of the assets acquired. We capitalize the major units of property replacements or improvements and expense minor items. We depreciate our non-oil and natural gas property, plant and equipment using the straight-line method over the useful lives of the assets which range from four to seven years. Accounting for Asset Retirement Obligations We record a liability for legal obligations associated with the replacement, removal or retirement of our long-lived assets in the period the obligation is incurred and is estimable. Our asset retirement liabilities are initially recorded at their estimated fair value with a corresponding increase to property, plant and equipment. This increase in property, plant and equipment is then depreciated over the useful life of the asset to which that liability relates. An ongoing expense is recognized for changes in the value of the liability as a result of the passage of time, which we record as depreciation, depletion and amortization expense in our consolidated income statements. Accounting for Long-Term Incentive Compensation We measure the cost of long-term incentive compensation based on the fair value of the award on the day it is granted. Awards issued under our incentive compensation programs are recognized as either equity awards or liability awards based on their characteristics. Expense is recognized in our consolidated financial statements as general and administrative expense over the period of service required by the award. See Note 9 for further discussion of our long-term incentive compensation. Environmental Costs, Legal and Other Contingencies Environmental Costs. We record environmental liabilities at their undiscounted amounts on our consolidated balance sheet in other current and long-term liabilities when we assess that remediation efforts are probable and the costs can be reasonably estimated. Estimates of our environmental liabilities are based on current available facts, existing technology and presently enacted laws and regulations, taking into consideration the likely effects of other societal and economic factors, and include estimates of associated legal costs. These amounts also consider prior experience in remediating contaminated sites, other companies’ clean-up experience and data released by the Environmental Protection Agency (EPA) or other organizations. Our estimates are subject to revision in future periods based on actual costs or new circumstances. We capitalize costs that benefit future periods and expense costs that do not in general and administrative expense. We evaluate any amounts paid directly or reimbursed by government sponsored programs and potential recoveries or reimbursements of remediation costs from third parties, including insurance coverage, separately from our liability. Recovery is evaluated based on the creditworthiness or solvency of the third party, among other factors. When recovery is assured, we record and report an asset separately from the associated liability on our consolidated balance sheet. Legal and Other Contingencies. We recognize liabilities for legal and other contingencies when we have an exposure that indicates it is both probable that a liability has been incurred and the amount of the loss can be reasonably estimated. Where the most likely outcome of a contingency can be reasonably estimated, we accrue a liability for that amount. Where the most likely outcome cannot be estimated, a range of potential losses is established and if no one amount in that range is more likely than any other to occur, the low end of the range is accrued. Derivatives We enter into derivative contracts on our oil and natural gas products primarily to stabilize cash flows and reduce the risk and financial impact of downward commodity price movements on commodity sales. Derivative instruments are reflected on our consolidated balance sheet at their fair value as assets and liabilities. We classify our derivatives as either current or non-current based on their anticipated settlement date. We net derivative assets and liabilities with counterparties where we have a legal right of offset. All of our derivatives are marked-to-market each period and changes in the fair value of our commodity based derivatives, as well as any realized amounts, are reflected as operating revenues. We classify cash flows related to derivative contracts based on the nature and purpose of the derivative. As the derivative cash flows are considered an integral part of our oil and natural gas operations, they are classified as cash flows from operating activities. In our consolidated balance sheet, receivables and payables resulting from the settlement of our derivative instruments are reported as trade receivables and payables. See Note 5 for a further discussion of our derivatives. Income Taxes Our taxable income or loss is included in our parent's (EP Energy Corporation) U.S. federal and certain state returns. EP Energy Corporation pays all consolidated U.S. federal and state income tax directly to the appropriate taxing jurisdictions. We record income taxes on a separate return basis in our financial statements as if we had filed separate income tax returns under our existing structure. In certain states, we also file and pay directly to the state taxing authorities. Changes in tax laws are recorded in the period they are enacted. We classify all deferred tax assets and liabilities, along with any related valuation allowance, as non-current on the consolidated balance sheet. We account for tax credits under the flow-through method, which reduces the provision for income taxes in the year the tax credits first become available. The realization of our deferred tax assets depends on recognition of sufficient future taxable income during periods in which those temporary differences are deductible. We record a valuation allowance against deferred tax assets when, based on our estimates, it is more likely than not that a portion of those assets will not be realized in a future period. The estimates utilized in recognition of deferred tax assets are subject to revision, either up or down, in future periods based on new facts or circumstances. In evaluating our valuation allowances, we consider cumulative book losses, the reversal of existing temporary differences, the existence of taxable income in carryback years, tax planning strategies and future taxable income for each of our taxable jurisdictions, the latter two of which involve the exercise of significant judgment. Changes to our valuation allowances could materially impact our results of operations. Voluntary Reorganization under Chapter 11 Cases Formation of Special Committee. In the second quarter 2019, our Board of Directors (the “Board”) appointed a special committee (the “Special Committee”) of three independent directors that are not affiliated with the Sponsors (affiliates of Apollo Global Management, Inc. (“Apollo”), Riverstone Holdings LLC, Access Industries, Inc. (“Access”) and Korea National Oil Corporation, collectively, the “Sponsors”), and we engaged financial and legal advisors to consider a number of potential actions and evaluate certain strategic alternatives to address our liquidity and balance sheet issues. Covenant Violations, Forbearance, and Chapter 11 Cases. On August 15, 2019, we did not make the approximately $40 million cash interest payment due and payable with respect to the 8.000% Senior Secured Notes due 2025 (the “2025 1.5 Lien Notes”). On September 3, 2019, we did not make the approximately $7 million cash interest payment due and payable with respect to the 7.750% Senior Notes due 2022 (the “2022 Unsecured Notes”). Our failure to make these interest payments within thirty days after they were due and payable resulted in an event of default under the respective indentures governing the 2025 1.5 Lien Notes and 2022 Unsecured Notes. Each event of default under the indentures noted above also resulted in a cross-default under the Reserve-Based Facility (“RBL Facility”). On September 14, 2019, we entered into forbearance agreements, extending through October 3, 2019, with (i) certain beneficial owners and/or investment advisors or managers of discretionary accounts for the beneficial owners of greater than 70% of the aggregate principal amount of the outstanding 2025 1.5 Lien Notes (collectively, the “Noteholders”) and (ii) certain lenders holding greater than a majority of the revolving commitments under our RBL Facility and the administrative agent and collateral agent under the RBL Facility (collectively, the “RBL Forbearing Parties”) pursuant to which each Noteholder and RBL Forbearing Party temporarily agreed to forbear from exercising any rights or remedies they may have occurred in respect of the failure to make the $40 million cash interest payment. On October 3, 2019, we and certain of our direct and indirect subsidiaries (collectively with the Company, the “Debtors”) filed voluntary petitions (the “Chapter 11 Cases”) in the United States Bankruptcy Court for the Southern District of Texas (the “Bankruptcy Court”) seeking relief under chapter 11 of title 11 of the United States Code (the “Bankruptcy Code”). To ensure ordinary course operations, the Debtors obtained approval from the Bankruptcy Court for a variety of “first day” motions, including motions to obtain customary relief intended to assure our ability to continue our ordinary course operations after the filing date. In addition, the Debtors received authority to use cash collateral of the lenders under the RBL Facility. The commencement of the Chapter 11 Cases constituted an immediate event of default, and caused the automatic and immediate acceleration of all debt outstanding under or in respect of a number of our instruments and agreements relating to our direct financial obligations, including our RBL Facility and indentures governing the 2025 1.5 Lien Notes, 7.750% Senior Secured Notes due 2026, 8.000% Senior Secured Notes due 2024 (the “2024 1.25 Lien Notes”), 9.375% Senior Secured Notes due 2024 (the “2024 1.5 Lien Notes”), 9.375% Senior Notes due 2020, 2022 Unsecured Notes and 6.375% Senior Notes due 2023 (collectively, the “Senior Notes”). Any efforts to enforce such payment obligations were automatically stayed as a result of the filing of the Chapter 11 Cases and the creditors’ rights of enforcement in respect of the Senior Notes and the RBL Facility are subject to the applicable provisions of the Bankruptcy Code. Plan Support Agreement and Backstop Commitment Agreement . On October 18, 2019, the Debtors entered into a plan support agreement (the “PSA”) to support a restructuring on the terms of a chapter 11 plan of reorganization (as defined below, the “Plan”) with holders of approximately 52.0% of the 2024 1.25 Lien Notes and approximately 79.3% of the 2024 1.5 Lien Notes and the 2025 1.5 Lien Notes issued, in each case, by EP Energy LLC and Everest Acquisition Finance Inc. The holders of these notes include affiliates of, or funds managed by, Elliott Management Corporation (“Elliott”), Apollo (together with Elliott, the “Initial Supporting Noteholders”), Access, and Avenue Capital Group (collectively, with the Initial Supporting Noteholders and Access, the “Supporting Noteholders”), to support a restructuring on the terms of a chapter 11 plan described therein. On October 18, 2019, the Debtors also entered into a backstop commitment agreement (the “BCA”) with the Supporting Noteholders, pursuant to which the Supporting Noteholders agreed to backstop $463 million (to consist of $325 million in cash and $138 million in exchanged reinstated 1.25L Notes) of the Rights Offering. For additional information, see Termination of Plan Support Agreement and Backstop Commitment Agreement below. Plan of Reorganization. On November 18, 2019, the Debtors filed a proposed Joint Chapter 11 Plan and a proposed Disclosure Statement for Joint Chapter 11 Plan of Reorganization describing the Plan and the solicitation of votes to approve the same from certain of the Debtors’ creditors with respect to the Chapter 11 Cases. The Debtors subsequently filed various amendments to the Plan and Disclosure Statement and on January 13, 2020, filed an updated Fourth Amended Joint Chapter 11 Plan of EP Energy Corporation and its Affiliated Debtors (as further amended from time to time, the “Plan”) and an updated Disclosure Statement for Fourth Amended Joint Chapter 11 Plan of Reorganization of EP Energy Corporation and its Affiliated Debtors (as further amended from time to time, the “Disclosure Statement”). On March 6, 2020, after a hearing to confirm the Plan, the Bankruptcy Court stated that it would confirm the Plan. On March 12, 2020, pursuant to its ruling on March 6, 2020, the Bankruptcy Court entered an order confirming the Plan (ECF No. 1049). Termination of Plan Support Agreement and Backstop Commitment Agreement. Commodity prices for oil, natural gas and NGLs historically have been volatile and may continue to be volatile in the future, especially given current global geopolitical and economic conditions. As a result of a decrease in global demand for oil and natural gas due to the recent coronavirus outbreaks, in March 2020, members of the Organization of the Petroleum Exporting Countries (“OPEC”) and Russia considered extending their agreed oil production cuts and making additional oil production cuts. However, negotiations to date have been unsuccessful. Saudi Arabia announced a significant increase in its maximum crude oil production capacity, targeting to supply 12.3 million barrels per day, an increase of 2.5 million barrels per day, effective immediately, and Russia announced that all agreed oil production cuts between members of OPEC and Russia will expire on April 1, 2020. Following these announcements, within one day, global oil prices declined to their lowest levels since 2016 and partially recovered, but may continue to decline. In addition, coronavirus outbreaks have resulted in delays, supply chain disruptions and travel restrictions that have impacted the oil and gas industry. Subsequent to these events, on March 18, 2020, the Debtors and the Supporting Noteholders under the PSA and in their capacities as the Commitment Parties under the BCA, mutually agreed to amend and terminate the PSA and the BCA pursuant to the terms of a Stipulation of Settlement Regarding Backstop Agreement and Plan Support Agreement (as may be amended or modified from time to time, the “Stipulation”). Among other things, the Stipulation provides that (i) the PSA and BCA are terminated consensually by the parties pursuant to Section 9.1 of the BCA and Section 7(f) of the PSA, (ii) the Termination Fee (as defined in the BCA) shall not be payable to the Commitment Parties, (iii) the Debtors will reimburse all fees, costs and expenses of the Supporting Noteholders, and the Commitment Parties through the date on which the Bankruptcy Court approves the Stipulation, and (iv) through November 25, 2020 the Supporting Noteholders and Commitment Parties will not interfere, directly or indirectly, with any further restructuring of the Debtors, that treats their applicable claims no less favorably than other similarly situated claims. The Debtors and the Supporting Noteholders and Commitment Parties also agreed to mutual waivers and releases of certain claims relating to, or arising from, the Chapter 11 Cases, the BCA, the PSA, and the termination of the BCA and the PSA, against the other as described in the Stipulation. On March 23, 2020, the Bankruptcy Court approved the Stipulation. The Debtors are working with their constituents to explore various alternatives. Debtor-in-Possession Agreement. On November 25, 2019, EPE Acquisition, LLC and EP Energy LLC entered into a Senior Secured Superpriority Debtor-In-Possession Credit Agreement (as amended or modified from time to time, the “DIP Credit Agreement”) with JPMorgan Chase Bank, N.A., as administrative agent, collateral agent and an issuing bank and the RBL Lenders which are party thereto as lenders (in such capacity, the “DIP Lenders”). Under the DIP Credit Agreement and the order of the Bankruptcy Court entered on November 25, 2019 (the “DIP Order”), a portion of the RBL Facility was converted into revolving commitments under the DIP Credit Agreement which provides for an approximately $315 million debtor-in-possession senior secured superpriority revolving credit facility (the “DIP Facility”, and the loans thereunder, the “DIP Loans”), and which includes a letter of credit sublimit of $50 million . As of December 31, 2019, we had $150 million capacity remaining with approximately $17 million of letters of credit (“LCs”) issued and $148 million outstanding under the DIP Facility. For a further discussion of the additional terms of the DIP Facility, see Part II, Item 7. “Management's Discussion and Analysis of Financial Condition and Results of Operations- Liquidity and Capital Resources” and Part II, Item 8. “Financial Statements and Supplementary Data”, Note 8. EP Energy LLC will use the proceeds of the DIP Facility for, among other things, (i) the acquisition, development and exploration of oil and gas properties, for working capital and general corporate purposes, (ii) the payment of professional fees as provided for in the DIP Order, (iii) the payment of expenses incurred in the administration of the Chapter 11 Cases or as permitted by the certain orders and (iv) payments due thereunder or under the DIP Order. The maturity date of the DIP Facility is the earlier of (a) November 25, 2020, (b) the effective date of an “Acceptable Plan of Reorganization” (as defined in the DIP Credit Agreement), (c) the closing of a sale of substantially all of the equity or assets of EP Energy LLC (unless consummated pursuant to an Acceptable Plan of Reorganization), or (d) the termination of the DIP Facility during the continuation of an event of default. On March 12, 2020, EP Energy LLC, EPE Acquisition, LLC, the agent and certain of the lenders under the RBL Facility, the DIP Agent and certain of the DIP Lenders entered into that certain Waiver of Credit Agreements which waived the occurrence of any event of default triggered under the RBL Credit Agreement and the DIP Credit Agreement as a result of a going concern or like qualification or exception to the audited financials for the year ending December 31, 2019 . Exit Facility. The Debtors have received an underwritten commitment from the DIP Lenders to convert their DIP Loans and their remaining claims under the RBL Facility into an approximately $629 million exit senior secured reserve-based revolving credit facility (the “Exit Facility”) subject to certain conditions set forth therein, which will be evidenced by a senior secured revolving credit agreement, by and among EP Energy LLC, as borrower, EPE Acquisition, LLC, as holdings, the lenders party thereto from time to time, and JPMorgan Chase Bank, N.A., as administrative agent, collateral agent and an issuing bank (the “Exit Credit Agreement”). Ability to Continue as a Going Concern . The significant risks and uncertainties related to the Company’s liquidity and the Chapter 11 Cases described above raise substantial doubt about the Company’s ability to continue as a going concern. Our operations and our ability to develop and execute our business plan are subject to a high degree of risks and uncertainty associated with the Chapter 11 Cases which are dependent upon factors that are outside of the Company’s control, including actions of the Bankruptcy Court and the Company’s creditors. Further, completion of a plan of reorganization could materially change the amounts and classifications of assets and liabilities reported in the consolidated financial statements. The accompanying consolidated financial statements have (i) been prepared on a going concern basis, which contemplates the realization of assets and satisfaction of liabilities and other commitments in the normal course of business and (ii) do not include any adjustments to reflect the possible future effects of this uncertainty on the recoverability or classification of recorded asset amounts or the amounts or classifications of liabilities. Reorganization Items, Net . Expenses and gains/(losses) realized or incurred subsequent to our bankruptcy filing petition date and that are a direct result of the Chapter 11 Cases have been expensed as incurred as reorganization items in our consolidated statements of income. For the year ended December 31, 2019 , reorganization items, net were $65 million and consisted of: Year ended (in millions) Professional fees $ 44 Rejection of executory contracts approved by Bankruptcy Court 16 DIP Facility costs 5 Total reorganization items, net $ 65 Liabilities subject to compromise . Prepetition unsecured and under-secured obligations that may be impacted by the Chapter 11 Cases have been classified as liabilities subject to compromise on our consolidated balance sheet. These liabilities are reported at the amounts expected to be allowed as claims by the Bankruptcy Court, although they may be settled for less or adjusted depending on Bankruptcy Court actions, further developments with respect to disputed claims, determination of secured status of certain claims, the determination as to the value of any collateral securing claims, proof of claims or other events. Differences between estimated liabilities recorded and claims filed, or to be filed, will be evaluated and resolved in connection with the claims resolution process and adjusted as necessary, and such adjustments may be material. Liabilities subject to compromise includes allowed claims, prepetition accounts payable and other amounts related to the rejection of executory contracts approved by the Bankruptcy Court. Additional amounts may be included in liabilities subject to compromise in future periods if additional executory contracts and certain unexpired leases are rejected prior to emerging from bankruptcy. Based on the nature of potential allowed claims, future adjustments to amounts recorded as liabilities subject to compromise may be material. As of December 31, 2019 , liabilities subject to compromise were $2,932 million and consisted of: Year ended (in millions) Senior secured 1.5 lien notes $ 2,092 Senior unsecured notes 688 Prepetition accrued interest on senior secured 1.5 lien and unsecured notes 117 Allowed claims, prepetition accounts payable and other 35 Total liabilities subject to compromise $ 2,932 As a result of the commencement of the Chapter 11 cases, the principal balance on the 1.5 lien notes and senior unsecured notes of $2,092 million and $688 million , respectively, as of December 31, 2019 has been reclassif |
