We are developingin various stages of operating and constructing natural gas liquefaction and export facilities at the Corpus Christi LNG terminal (the “Liquefaction Facilities”) near Corpus Christi, Texas and a 23-mile natural gas supply pipeline that interconnects the Corpus Christi LNG terminal with several interstate and intrastate natural gas pipelines (the “Corpus Christi Pipeline” and together with the Liquefaction Facilities, the “Liquefaction Project”) through our wholly owned subsidiaries CCL and CCP, respectively. The Liquefaction Project is being developedconstructed in stages with the first phase being three3 Trains (“Phase 1”). The first stage includes Trains 1 and 2, two2 LNG storage tanks, one1 complete marine berth and a second partial berth and all of the Liquefaction Project’s necessary infrastructure facilities (“Stage 1”). The second stage includes Train 3, one1 LNG storage tank and the completion of the second partial berth (“Stage 2”). TrainTrains 1 isand 2 are operational Train 2 is undergoing commissioning and Train 3 is under construction.

Results of operations for the three and nine months ended March 31,September 30, 2019 are not necessarily indicative of the results of operations that will be realized for the year ending December 31, 2019.

We are a disregarded entity for federal and state income tax purposes. Our taxable income or loss, which may vary substantially from the net income or loss reported on our Consolidated Statements of Operations, is included in the consolidated federal income tax return of Cheniere. The provision for income taxes, taxes payable and deferred income tax balances have been recorded as if we had filed all tax returns on a separate return basis from Cheniere. Tax elections under a separate return basis may differ from tax elections taken on the consolidated federal income tax return of Cheniere.

As of March 31,September 30, 2019 and December 31, 2018, inventory consisted of the following (in thousands):

As of March 31,September 30, 2019 and December 31, 2018, property, plant and equipment, net consisted of the following (in thousands):

Depreciation expense was $22.3$66.2 million and $0.3$3.4 million during the three months ended March 31,September 30, 2019 and 2018, respectively, and $145.6 million and $5.1 million during the nine months ended September 30, 2019 and 2018, respectively.

We realized offsets to LNG terminal costs of $74.2$73.7 million inand $156.1 million during the three and nine months ended March 31,September 30, 2019, respectively, that were related to the sale of commissioning cargoes because these amounts were earned or loaded prior to the start of commercial operations of Train 1 of the Liquefaction Project, during the testing phase for its construction. We did not0t realize any offsets to LNG terminal costs induring the three and nine months ended March 31,September 30, 2018.

We recognize our derivative instruments as either assets or liabilities and measure those instruments at fair value. None of our derivative instruments are designated as cash flow or fair value hedging instruments, and changes in fair value are recorded within our Consolidated Statements of Operations to the extent not utilized for the commissioning process.

The following table shows the fair value of our derivative instruments that are required to be measured at fair value on a recurring basis as of March 31,September 30, 2019 and December 31, 2018, which are classified as derivative assets, derivative assets—related party, non-current derivative assets, non-current derivative assets—related party, derivative liabilities or non-current derivative liabilities in our Consolidated Balance Sheets (in thousands):

We value our CCH Interest Rate Derivatives using an income-based approach, utilizing observable inputs to the valuation model including interest rate curves, risk adjusted discount rates, credit spreads and other relevant data. We value our Liquefaction Supply Derivatives using a market-based approach incorporating present value techniques, as needed, using observable commodity price curves, when available, and other relevant data.

 

The fair value of our Physical Liquefaction Supply Derivatives is predominantly driven by observable and unobservable market commodity basis prices and, as applicable to our natural gas supply contracts, our assessment of the associated conditions precedent, including evaluating whether the respective market is available as pipeline infrastructure is developed. UponThe fair value of our Physical Liquefaction Supply Derivatives incorporates risk premiums related to the satisfaction of conditions precedent, includingsuch as completion and placement into service of relevant pipeline infrastructure to accommodate marketable physical gas flow, we recognize a gain or loss based onflow. As of September 30, 2019 and December 31, 2018, some of our Physical Liquefaction Supply Derivatives existed within markets for which the fair value of the respective naturalpipeline infrastructure was under development to accommodate marketable physical gas supply contracts.flow.

We include a portion of our Physical Liquefaction Supply Derivatives as Level 3 within the valuation hierarchy as the fair value is developed through the use of internal models which may be impacted by inputsincorporate significant unobservable inputs. In instances where observable data is unavailable, consideration is given to the assumptions that aremarket participants would use in valuing the asset or liability. This includes assumptions about market risks, such as future prices of energy units for unobservable in the marketplace. The curves used to generate the fair value of our Physical Liquefaction Supply Derivatives are based on basis adjustments applied to forward curves for a liquid trading point. In addition, there may be observable liquid market basis information in the near term, but terms of a Physical Liquefaction Supply Derivativesperiods, liquidity, volatility and contract may exceed the period for which such information is available, resulting in a Level 3 classification. In these instances, the fair value of the contract incorporates extrapolation assumptions made in the determination of the market basis price for future delivery periods in which applicable commodity basis prices were either not observable or lacked corroborative market data. As of March 31, 2019 and December 31, 2018, some of our Physical Liquefaction Supply Derivatives existed within markets for which the pipeline infrastructure is under development to accommodate marketable physical gas flow.duration.

The Level 3 fair value measurements of natural gas positions within our Physical Liquefaction Supply Derivatives could be materially impacted by a significant change in certain natural gas market basis spreads due to the contractual notional amount represented by our Level 3 positions, which is a substantial portion of our overall Physical Liquefaction Supply Derivatives portfolio. The following table includes quantitative information for the unobservable inputs for our Level 3 Physical Liquefaction Supply Derivatives as of March 31,September 30, 2019:

The following table shows the changes in the fair value of our Level 3 Physical Liquefaction Supply Derivatives, including those with related parties, during the three and nine months ended March 31,September 30, 2019 and 2018 (in thousands):

Derivative assets and liabilities arising from our derivative contracts with the same counterparty are reported on a net basis, as all counterparty derivative contracts provide for net settlement.the unconditional right of set-off in the event of default. The use of derivative instruments exposes us to counterparty credit risk, or the risk that a counterparty will be unable to meet its commitments in instances when our derivative instruments are in an asset position. Additionally, counterparties are at risk that we evaluate our own abilitywill be unable to meet our commitments in instances where our derivative instruments are in a liability position. OurWe incorporate both our own nonperformance risk and the respective counterparty’s nonperformance risk in fair value measurements. In adjusting the fair value of our derivative instruments are subject to contractual provisions which providecontracts for the unconditional righteffect of nonperformance risk, we have considered the impact of netting and any applicable credit enhancements, such as collateral postings, set-off for all derivative assetsrights and liabilities with a given counterparty in the event of default.guarantees.

During the threenine months ended March 31,September 30, 2019, there were no changes to the terms of our Interest Rate Derivatives, which we entered into to protect against volatility of future cash flows and hedge a portion of the variable interest payments on the CCH Credit Facility.

As of March 31,September 30, 2019, we had the following CCH Interest Rate Derivatives outstanding:

The following table shows the fair value and location of our CCH Interest Rate Derivatives on our Consolidated Balance Sheets (in thousands):

The following table shows the changes in the fair value and settlements of our CCH Interest Rate Derivatives recorded in derivative gain (loss), net on our Consolidated Statements of Operations during the three and nine months ended March 31,September 30, 2019 and 2018 (in thousands):

CCL has entered into primarily index-based physical natural gas supply contracts and associated economic hedges to purchase natural gas for the commissioning and operation of the Liquefaction Project. The terms of the physical natural gas supply contracts range up to eight years, some of which commence upon the satisfaction of certain conditions precedent.

As of March 31,September 30, 2019 and December 31, 2018, CCL had secured up to approximately 2,8053,065 TBtu and 2,801 TBtu, respectively, of natural gas feedstock through natural gas supply contracts.contracts, of which 122 TBtu and 55 TBtu, respectively, were for a natural gas supply contract CCL has with a related party. The forward notional for our Liquefaction Supply Derivatives was approximately 2,9383,213 TBtu and 2,854 TBtu as of March 31,September 30, 2019 and December 31, 2018, respectively.

The following table shows the fair value and location of our Liquefaction Supply Derivatives on our Consolidated Balance Sheets (in thousands):

The following table shows the changes in the fair value, settlements and location of our Liquefaction Supply Derivatives recorded on our Consolidated Statements of Operations during the three and nine months ended March 31,September 30, 2019 and 2018 (in thousands):

Our derivative instruments are presented on a net basis on our Consolidated Balance Sheets as described above. The following table shows the fair value of our derivatives outstanding on a gross and net basis (in thousands):

As of March 31,September 30, 2019 and December 31, 2018, our debt consisted of the following (in thousands): 

Below is a summary of our credit facilities outstanding as of March 31,September 30, 2019 (in thousands):

As of March 31,September 30, 2019, we were in compliance with all covenants related to our debt agreements.

The following table shows the carrying amount, which is net of unamortized premium, discount and debt issuance costs, and estimated fair value of our debt (in thousands):

For the three months ended March 31, 2019, the entire balanceThe following table represents a disaggregation of LNG revenues—affiliate represented revenue earned from contracts with customers during the three and the entire balance of LNG revenues represented gains from derivative instruments, including a portion of derivative instruments that settled through physical delivery.nine months ended September 30, 2019 and 2018 (in thousands):

Because many of our sales contracts have long-term durations, we are contractually entitled to significant future consideration which we have not yet recognized as revenue. The following table discloses the aggregate amount of the transaction price that is allocated to performance obligations that have not yet been satisfied as of March 31,September 30, 2019 and December 31, 2018:

We have entered into contracts to sell LNG that are conditioned upon one or both of the parties achieving certain milestones such as reaching a final investment decision on a certain liquefaction Train, obtaining financing or achieving substantial completion of a Train and any related facilities. These contracts are considered completed contracts for revenue recognition purposes and are included in the transaction price above when the conditions are considered probable of being met.

Below is a summary of our related party transactions as reported on our Consolidated Statements of Operations for the three and nine months ended March 31,September 30, 2019 and 2018 (in thousands):

We had $17.0$19.2 million and $25.1 million due to affiliates as of March 31,September 30, 2019 and December 31, 2018, respectively, under agreements with affiliates, as described below.

CCL has a fixed price SPA with Cheniere Marketing International LLP (“Cheniere Marketing”) (the “Cheniere Marketing Base SPA”) with a term of 20 years which allows Cheniere Marketing to purchase, at its option, (1) up to a cumulative total of 150 TBtu of LNG within the commissioning periods for Trains 1 through 3, (2) any LNG produced from the end of the commissioning period for Train 1 until the date of first commercial delivery of LNG from Train 1 and (3) any excess LNG produced by the Liquefaction Facilities that is not committed to customers under third-party SPAs. Under the Cheniere Marketing Base SPA, Cheniere Marketing may, without charge, elect to suspend deliveries of cargoes (other than commissioning cargoes) scheduled for any month under the applicable annual delivery program by providing specified notice in advance. Additionally, CCL has a fixed price SPA with an approximate term of 23 years with Cheniere Marketing which allows them to purchase volumes of approximately 15 TBtu per annum of LNG. As of March 31,September 30, 2019 and December 31, 2018, CCL had $43.8$48.7 million and $21.1 million of accounts receivable—affiliate, respectively, under these agreements.

CCL has a G&P Agreement with Cheniere Energy Shared Services, Inc. (“Shared Services”), a wholly owned subsidiary of Cheniere, pursuant to which Shared Services will manage the gas and power procurement requirements of CCL. The services include, among other services, exercising the day-to-day management of CCL’s natural gas and power supply requirements, negotiating agreements on CCL’s behalf and providing other administrative services. Prior to the substantial completion of each Train of the Liquefaction Facilities, no monthly fee payment is required except for reimbursement of operating expenses. After