Sabine Pass Liquefaction S-4 9 Jun 17 Registration of securities issued in business combination transactions Financial data

Document and Entity Information

Document and Entity Information	3 Months Ended
	Mar. 31, 2017
Document and Entity Information [Abstract]
Entity Registrant Name	Sabine Pass Liquefaction, LLC
Entity Central Index Key	1,499,200
Entity Filer Category	Non-accelerated Filer
Document Type	S4
Document Period End Date	Mar. 31, 2017
Amendment Flag	false

Balance Sheets

Balance Sheets - USD ($) $ in Thousands	Mar. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Current assets
Cash and cash equivalents	$ 0	$ 0	$ 0
Restricted cash	531,000	357,953	189,260
Accounts and other receivables	101,000	89,729	577
Accounts receivable—affiliate	93,000	99,765	2,457
Advances to affiliate	51,000	25,892	28,312
Inventory	78,000	88,521	5,742
Other current assets	23,000	25,242	8,412
Other current assets—affiliate	11,000	10,585	0
Total current assets	888,000	697,687	234,760
Non-current restricted cash	1,000,000	0	0
Property, plant and equipment, net	12,369,000	11,874,843	9,841,407
Debt issuance costs, net	22,000	58,655	132,091
Non-current derivative assets	28,000	66,788	30,304
Other non-current assets, net	168,000	185,343	194,818
Total assets	14,475,000	12,883,316	10,433,380
Current liabilities
Accounts payable	32,000	22,750	13,420
Accrued liabilities	406,000	407,469	201,559
Current debt	0	223,500	15,000
Due to affiliates	35,000	33,016	53,848
Deferred revenue	36,000	45,921	0
Deferred revenue—affiliate	19,000
Derivative liabilities	4,000	11,481	6,430
Total current liabilities	532,000	744,137	290,257
Long-term debt, net	13,460,000	11,649,229	9,205,559
Non-current derivative liabilities	1,000	2,001	2,884
Other non-current liabilities—affiliate	0	1,679	3,393
Commitments and contingencies
Member’s equity	482,000	486,270	931,287
Liabilities and Equity	$ 14,475,000	$ 12,883,316	$ 10,433,380

Statements of Operations

Statements of Operations - USD ($) $ in Thousands	3 Months Ended		12 Months Ended
	Mar. 31, 2017	Mar. 31, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Revenues
LNG revenues	$ 492,000	$ 0	$ 539,454	$ 0	$ 0
LNG revenues—affiliate	331,000	0	293,957	0	0
Total revenues	823,000	28	833,411	0	0
Operating costs and expenses
Cost of sales (excluding depreciation and amortization expense shown separately below)	510,000	4,000	415,746	(32,453)	(342)
Cost of sales—affiliate	4,000	0	6,754	0	0
Operating and maintenance expense	39,000	5,000	73,785	4,557	5,553
Operating and maintenance expense—affiliate	59,000	1,000	128,423	1,331	95
Terminal use agreement maintenance expense (recovery)			(543)	18,428	25,677
Terminal use agreement maintenance expense—affiliate			208	400	387
Development expense			126	2,850	9,319
Development expense—affiliate			511	722	1,153
General and administrative expense	2,000	1,000	7,246	5,637	5,305
General and administrative expense—affiliate	17,000	17,000	68,070	87,681	71,065
Depreciation and amortization expense	47,000	2,000	83,238	2,479	967
Total operating costs and expenses	678,000	30,000	783,564	91,632	119,179
Income (loss) from operations	145,000	(30,061)	49,847	(91,632)	(119,179)
Other income (expense)
Interest expense, net of capitalized interest	(105,000)	(6,000)	(185,825)	(36,330)	(23,909)
Loss on early extinguishment of debt	(42,000)	0	(52,180)	(96,273)	(114,335)
Derivative loss, net	(2,000)	(11,000)	(5,934)	(41,722)	(119,401)
Other income (expense)			627	340	(29)
Total other expense	(149,000)	(17,000)	(243,312)	(173,985)	(257,674)
Net loss	$ (4,000)	$ (47,241)	$ (193,465)	$ (265,617)	$ (376,853)

Statement of Member's Equity

Statement of Member's Equity - USD ($) $ in Thousands	Total	Sabine Pass LNG-LP, LLC [Member]
Members' equity, beginning of period at Dec. 31, 2013	$ 1,638,265	$ 1,638,265
Increase (Decrease) in Partners' Capital [Roll Forward]
Capital contributions from Cheniere Partners	11,734	11,734
Partners' Capital Account, Contributions	11,734
Non-cash distributions to affiliates	(745)	(745)
Net loss	(376,853)	(376,853)
Member's equity, end of period at Dec. 31, 2014	1,272,401	1,272,401
Increase (Decrease) in Partners' Capital [Roll Forward]
Capital contributions from Cheniere Partners	15,297	15,297
Partners' Capital Account, Contributions	15,297
Non-cash distributions to affiliates	(90,794)	(90,794)
Net loss	(265,617)	(265,617)
Member's equity, end of period at Dec. 31, 2015	931,287	931,287
Increase (Decrease) in Partners' Capital [Roll Forward]
Capital contributions from Cheniere Partners	1,250	1,250
Non-cash distributions to affiliates	(252,802)	(252,802)
Net loss	(193,465)	(193,465)
Member's equity, end of period at Dec. 31, 2016	486,270	486,270
Increase (Decrease) in Partners' Capital [Roll Forward]
Capital contributions from Cheniere Partners	0
Net loss	(4,000)	(4,000)
Member's equity, end of period at Mar. 31, 2017	$ 482,000	$ 482,000

Statements of Cash Flows

Statements of Cash Flows - USD ($) $ in Thousands	3 Months Ended		12 Months Ended
	Mar. 31, 2017	Mar. 31, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Cash flows from operating activities
Net loss	$ (4,000)	$ (47,241)	$ (193,465)	$ (265,617)	$ (376,853)
Adjustments to reconcile net loss to net cash provided by (used in) operating activities:
Non-cash terminal use agreement maintenance expense			160	16,763	24,461
Depreciation and amortization expense	47,000	2,000	83,238	2,479	967
Amortization of debt issuance costs, deferred commitment fees, premium and discount	5,000	0	11,711	2,100	0
Loss on early extinguishment of debt	42,000	0	52,180	96,273	114,335
Total (gains) losses on derivatives, net	41,000	15,000	(36,380)	7,377	118,199
Net cash used for settlement of derivative instruments	(11,000)	(3,000)	(6,705)	(41,756)	(22,093)
Other			(432)	0	0
Changes in operating assets and liabilities:
Accounts and other receivables	(11,000)	0	(89,820)	15	(22)
Accounts receivable—affiliate	56,000	0	(98,590)	350	(1,584)
Advances to affiliate	(40,000)	0	722	(4,342)	(14,539)
Inventory	18,000	(3,000)	(60,045)	(3,565)	(22,963)
Accounts payable and accrued liabilities	(39,000)	(3,000)	179,295	(4,967)	9,234
Due to affiliates	2,000	(2,000)	954	6,347	(2,373)
Deferred revenue	(10,000)	0	45,921	0	0
Deferred revenue—affiliate	19,000	0
Other, net	3,000	(3,000)	(10,219)	(975)	(2,622)
Other, net—affiliate	(2,000)	2,000	(9,052)	(17,713)	0
Net cash provided by (used in) operating activities	116,000	(42,000)	(129,663)	(207,231)	(175,853)
Cash flows from investing activities
Property, plant and equipment, net	(528,000)	(712,000)	(2,305,737)	(2,861,000)	(2,548,855)
Other	0	(28,000)	(32,127)	(62,034)	(38,710)
Net cash used in investing activities	(528,000)	(740,000)	(2,337,864)	(2,923,034)	(2,587,565)
Cash flows from financing activities
Proceeds from issuances of debt	2,314,000	785,000	5,442,500	2,860,000	2,584,500
Repayments of debt	(703,000)	(15,000)	(2,765,000)	0	(177,000)
Debt issuance and deferred financing costs	(26,000)	0	(42,106)	(168,635)	(102,687)
Debt extinguishment costs			(424)	0	0
Capital contributions from Cheniere Partners	0	1,000	1,250	15,297	11,734
Net cash provided by financing activities	1,585,000	771,000	2,636,220	2,706,662	2,316,547
Net increase (decrease) in cash, cash equivalents and restricted cash	1,173,000	(11,000)	168,693	(423,603)	(446,871)
Cash, cash equivalents and restricted cash—beginning of period	357,953	189,260	189,260	612,863	1,059,734
Cash, cash equivalents and restricted cash—end of period	1,531,000	178,000	357,953	189,260	612,863
Balances per Balance Sheets:
Cash and cash equivalents	0	0	0	0	0
Restricted cash	531,000	178,000	357,953	189,260	155,810
Non-current restricted cash	1,000,000	0	0	0	457,053
Total cash, cash equivalents and restricted cash	$ 1,531,000	$ 178,000	$ 357,953	$ 189,260	$ 612,863

Organization and Nature of Oper

Organization and Nature of Operations	12 Months Ended
	Dec. 31, 2016
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Organization and Nature of Operations	ORGANIZATION AND NATURE OF OPERATIONS We are a Delaware limited liability company formed by Cheniere Partners to own, develop and operate natural gas liquefaction facilities in Cameron Parish, Louisiana (the “Liquefaction Project”) at the Sabine Pass LNG terminal adjacent to the existing regasification facilities owned and operated by SPLNG. We are a Houston-based company with one member, Sabine Pass LNG-LP, LLC, an indirect wholly owned subsidiary of Cheniere Partners. We and SPLNG are each indirect wholly owned subsidiaries of Cheniere Investments, which is a wholly owned subsidiary of Cheniere Partners, a publicly traded limited partnership (NYSE MKT: CQP). Cheniere Partners is a 55.9% owned subsidiary of Cheniere Holdings, which is, in turn, an 82.6% owned subsidiary of Cheniere, a Houston-based energy company primarily engaged in LNG-related businesses. Our Liquefaction Project is being developed and constructed at the Sabine Pass LNG terminal, which is located on the Sabine-Neches Waterway less than four miles from the Gulf Coast. The Sabine Pass LNG terminal includes existing infrastructure of five LNG storage tanks with capacity of approximately 16.9 Bcfe, two marine berths that can accommodate vessels with nominal capacity of up to 266,000 cubic meters and vaporizers with regasification capacity of approximately 4.0 Bcf/d. We plan to construct up to six Trains, which are in various stages of development, construction and operations. Trains 1 and 2 have commenced operating activities, Train 3 is undergoing commissioning and has produced LNG, Trains 4 and 5 are under construction and Train 6 is fully permitted. Each Train is expected to have a nominal production capacity, which is prior to adjusting for planned maintenance, production reliability and potential overdesign, of approximately 4.5 mtpa of LNG. In June 2014, the Financial Accounting Standards Board (the “FASB”) amended its guidance on development stage entities. The amendment removed all incremental financial reporting requirements from GAAP for development stage entities. This guidance is effective for interim and annual periods beginning after December 15, 2014, with early adoption permitted. We adopted this guidance in the quarterly period ended June 30, 2014. Prior to our adoption of this guidance, we were a development stage entity because we devoted substantially all of our efforts to establish a new natural gas liquefaction business for which planned principal operations had not yet commenced. The adoption of this guidance did not have a material impact on our financial position, operating results or cash flows other than the removal of inception-to-date information about income statement line items, cash flows and equity transactions

Nature of Operations and Basis

Nature of Operations and Basis of Presentation	3 Months Ended
	Mar. 31, 2017
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Nature of Operations and Basis of Presentation	NATURE OF OPERATIONS AND BASIS OF PRESENTATION We were formed by Cheniere Partners to own, develop and operate natural gas liquefaction facilities in Cameron Parish, Louisiana (the “Liquefaction Project”) at the Sabine Pass LNG terminal adjacent to the existing regasification facilities owned and operated by SPLNG. Our Liquefaction Project is being developed and constructed at the Sabine Pass LNG terminal, which is located on the Sabine-Neches Waterway less than four miles from the Gulf Coast. We plan to construct up to six Trains, which are in various stages of development, construction and operations. Trains 1 through 3 have commenced commercial operations, Train 4 is undergoing commissioning, Train 5 is under construction and Train 6 is being commercialized and has all necessary regulatory approvals in place. In the second quarter of 2016, we started production at the Liquefaction Project and began recognizing LNG revenues, which include fees that are received pursuant to our SPAs. During the three months ended March 31, 2017 , we received 94% of our net LNG revenues from two SPA customers. Basis of Presentation The accompanying unaudited Financial Statements of SPL have been prepared in accordance with GAAP for interim financial information and with Rule 10-01 of Regulation S-X. Accordingly, they do not include all of the information and footnotes required by GAAP for complete financial statements and should be read in conjunction with the Audited Financial Statements and accompanying notes included elsewhere in this registration statement. In our opinion, all adjustments, consisting only of normal recurring adjustments necessary for a fair presentation, have been included. Certain reclassifications have been made to conform prior period information to the current presentation. The reclassifications had no effect on our overall financial position, results of operations or cash flows. Results of operations for the three months ended March 31, 2017 are not necessarily indicative of the results of operations that will be realized for the year ending December 31, 2017 . 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 Statements of Operations, is able to be included in the federal income tax return of Cheniere Partners, a publicly traded partnership which indirectly owns us. Accordingly, no provision or liability for federal or state income taxes is included in the accompanying Financial Statements.

Summary of Significant Accounti

Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2016
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES Basis of Presentation The accompanying Financial Statements of SPL have been prepared in accordance with GAAP . Certain reclassifications have been made to conform prior period information to the current presentation. The reclassifications had no effect on our overall financial position, operating results or cash flows. In 2016, we started production at the Liquefaction Project . As a result, we introduced a new line item entitled “cost of sales” and modified the components of activity included in “operating and maintenance expense” on our Statements of Operations. To conform to the new presentation, reclassifications were made to the prior periods. Cost of sales includes costs incurred directly for the production and delivery of LNG from the Liquefaction Project such as natural gas feedstock, variable transportation and storage costs, derivative gains and losses associated with economic hedges to secure natural gas feedstock for the Liquefaction Project , and other costs related to converting natural gas into LNG, all to the extent not utilized for the commissioning process. These costs were reclassified from operating and maintenance expense. Operating and maintenance expense now includes costs associated with operating and maintaining the Liquefaction Project such as third-party service and maintenance contract costs, payroll and benefit costs of operations personnel, natural gas transportation and storage capacity demand charges, derivative gains and losses related to the sale and purchase of LNG associated with the regasification terminal, insurance and regulatory costs. Additionally, we renamed our “revenues” line item as “LNG revenues”, which include fees that are received pursuant to our SPAs and related LNG marketing activities. Use of Estimates The preparation of Financial Statements in conformity with GAAP requires management to make certain estimates and assumptions that affect the amounts reported in the Financial Statements and the accompanying notes. Management evaluates its estimates and related assumptions regularly, including those related to the value of property, plant and equipment, collectability of accounts receivable, derivative instruments, asset retirement obligations (“AROs”) and fair value measurements. Changes in facts and circumstances or additional information may result in revised estimates, and actual results may differ from these estimates. Fair Value Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants. Hierarchy Levels 1, 2 and 3 are terms for the priority of inputs to valuation techniques used to measure fair value. Hierarchy Level 1 inputs are quoted prices in active markets for identical assets or liabilities. Hierarchy Level 2 inputs are inputs other than quoted prices included within Level 1 that are directly or indirectly observable for the asset or liability. Hierarchy Level 3 inputs are inputs that are not observable in the market. In determining fair value, we use observable market data when available, or models that incorporate observable market data. In addition to market information, we incorporate transaction-specific details that, in management’s judgment, market participants would take into account in measuring fair value. We maximize the use of observable inputs and minimize our use of unobservable inputs in arriving at fair value estimates. Recurring fair-value measurements are performed for derivative instruments as disclosed in Note 7—Derivative Instruments . The carrying amount of cash and cash equivalents, restricted cash, accounts receivable and accounts payable reported on our Balance Sheets approximates fair value. The fair value of debt is the estimated amount we would have to pay to repurchase our debt in the open market, including any premium or discount attributable to the difference between the stated interest rate and market interest rate at each balance sheet date. Debt fair values, as disclosed in Note 10—Debt , are based on quoted market prices for identical instruments, if available, or based on valuations of similar debt instruments using observable or unobservable inputs. Non-financial assets and liabilities initially measured at fair value include intangible assets and AROs. Revenue Recognition Fees received pursuant to SPAs are recognized as LNG revenues after substantial completion of the respective Train. Prior to substantial completion, sales generated during the commissioning phase are offset against the cost of construction for the respective Train, as the production and removal of LNG from storage is necessary to test the facility and bring the asset to the condition necessary for its intended use. LNG revenues are recognized when LNG is delivered to the counterparty, either at the Sabine Pass LNG terminal or at the counterparty’s LNG receiving terminal, based on the terms of the contract. Cash and Cash Equivalents We consider all highly liquid investments with an original maturity of three months or less to be cash equivalents. Restricted Cash Restricted cash consists of funds that are contractually restricted as to usage or withdrawal and have been presented separately from cash and cash equivalents on our Balance Sheets. Accounts Receivable Accounts receivable is reported net of allowances for doubtful accounts. Impaired receivables are specifically identified and evaluated for expected losses. The expected loss on impaired receivables is primarily determined based on the debtor’s ability to pay and the estimated value of any collateral. We did no t recognize any bad debt expense related to accounts receivable during the years ended December 31, 2016, 2015 and 2014 . Inventory LNG and natural gas inventory are recorded at weighted average cost and materials and other inventory are recorded at cost. Inventory is subject to lower of cost or market (“LCM”) adjustments at the end of each period. Recoveries of losses resulting from interim period LCM adjustments are recorded when market price recoveries occur on the same inventory in the same fiscal year. These recoveries are recognized as gains in later interim periods with such gains not exceeding previously recognized losses. Reimbursement to SPLNG for our portion of its fuel costs related to maintaining the cryogenic readiness of the Sabine Pass LNG terminal is recorded in terminal use agreement maintenance expense—affiliate. Accounting for LNG Activities Generally, we begin capitalizing the costs of a Train once it meets the following criteria: (1) regulatory approval has been received, (2) financing for the Train is available and (3) management has committed to commence construction. Prior to meeting these criteria, most of the costs associated with a Train are expensed as incurred. These costs primarily include professional fees associated with front-end engineering and design work, costs of securing necessary regulatory approvals and other preliminary investigation and development activities related to the Train. Generally, costs that are capitalized prior to a project meeting the criteria otherwise necessary for capitalization include: land and lease option costs that are capitalized as property, plant and equipment and certain permits that are capitalized as other non-current assets. The costs of lease options are amortized over the life of the lease once obtained. If no lease is obtained, the costs are expensed. We capitalize interest and other related debt costs during the construction period of a Train. Upon commencement of operations, capitalized interest, as a component of the total cost, is amortized over the estimated useful life of the asset. Property, Plant and Equipment Property, plant and equipment are recorded at cost. Expenditures for construction and commissioning activities, major renewals and betterments that extend the useful life of an asset are capitalized, while expenditures for maintenance and repairs and general and administrative activities are charged to expense as incurred. Interest costs incurred on debt obtained for the construction of property, plant and equipment are capitalized as construction-in-process over the construction period or related debt term, whichever is shorter. We depreciate our property, plant and equipment using the straight-line depreciation method. Upon retirement or other disposition of property, plant and equipment, the cost and related accumulated depreciation are removed from the account, and the resulting gains or losses are recorded in other operating costs and expenses. Management tests property, plant and equipment for impairment whenever events or changes in circumstances have indicated that the carrying amount of property, plant and equipment might not be recoverable. Assets are grouped at the lowest level for which there are identifiable cash flows that are largely independent of the cash flows of other groups of assets for purposes of assessing recoverability. Recoverability generally is determined by comparing the carrying value of the asset to the expected undiscounted future cash flows of the asset. If the carrying value of the asset is not recoverable, the amount of impairment loss is measured as the excess, if any, of the carrying value of the asset over its estimated fair value. We recorded $0.4 million , zero and zero impairments related to property, plant and equipment during the years ended December 31, 2016, 2015 and 2014 , respectively. Derivative Instruments We use derivative instruments to hedge our exposure to cash flow variability from interest rate and commodity price risk. Derivative instruments are recorded at fair value and included in our Balance Sheets as assets or liabilities depending on the derivative position and the expected timing of settlement, unless they satisfy criteria and we elect the normal purchases and sales exception. When we have the contractual right and intend to net settle, derivative assets and liabilities are reported on a net basis. Changes in the fair value of our derivative instruments are recorded in current earnings, unless we elect to apply hedge accounting and meet specified criteria, including completing contemporaneous hedge documentation. We did no t have any derivative instruments designated as cash flow hedges during the years ended December 31, 2016, 2015 and 2014 . See Note 7—Derivative Instruments for additional details about our derivative instruments. Concentration of Credit Risk Financial instruments that potentially subject us to a concentration of credit risk consist principally of cash and cash equivalents and restricted cash. We maintain cash balances at financial institutions, which may at times be in excess of federally insured levels. We have not incurred losses related to these balances to date. The use of derivative instruments exposes us to counterparty credit risk, or the risk that a counterparty will be unable to meet its commitments. Our interest rate derivative instruments are placed with investment grade financial institutions whom we believe are acceptable credit risks. Our commodity derivative transactions are executed through over-the-counter contracts which are subject to nominal credit risk as these transactions are settled on a daily margin basis with investment grade financial institutions. Collateral deposited for such contracts is recorded as other current asset. We monitor counterparty creditworthiness on an ongoing basis; however, we cannot predict sudden changes in counterparties’ creditworthiness. In addition, even if such changes are not sudden, we may be limited in our ability to mitigate an increase in counterparty credit risk. Should one of these counterparties not perform, we may not realize the benefit of some of our derivative instruments. We have entered into six fixed price 20 -year SPAs with six unaffiliated third parties. We are dependent on the respective counterparties’ creditworthiness and their willingness to perform under their respective SPAs. During the year ended December 31, 2016 , we received 77% of our net LNG revenues from one SPA customer. Debt Our debt consists of current and long-term secured debt securities and credit facilities with banks and other lenders. Debt issuances are placed directly by us or through securities dealers or underwriters and are held by institutional and retail investors. Debt is recorded on our Balance Sheets at par value adjusted for unamortized discount or premium. Discounts, premiums and debt issuance costs directly related to the issuance of debt are amortized over the life of the debt and are recorded in interest expense, net of capitalized interest using the effective interest method. Gains and losses on the extinguishment of debt are recorded in gains and losses on the extinguishment of debt on our Statements of Operations. Debt issuance costs consist primarily of arrangement fees, professional fees, legal fees and printing costs. These costs are recorded as a direct deduction from the debt liability unless incurred in connection with a line of credit arrangement, in which case they are presented as an asset on our Balance Sheet. Debt issuance costs are amortized to interest expense or property, plant and equipment over the term of the related debt facility. Upon early retirement of debt or amendment to a debt agreement, certain fees are written off to loss on early extinguishment of debt. Asset Retirement Obligations We recognize AROs for legal obligations associated with the retirement of long-lived assets that result from the acquisition, construction, development and/or normal use of the asset and for conditional AROs in which the timing or method of settlement are conditional on a future event that may or may not be within our control. The fair value of a liability for an ARO is recognized in the period in which it is incurred, if a reasonable estimate of fair value can be made. The fair value of the liability is added to the carrying amount of the associated asset. This additional carrying amount is depreciated over the estimated useful life of the asset. Our assessment of AROs is described below. We have not recorded an ARO associated with the Sabine Pass LNG terminal. Based on the real property lease agreements at the Sabine Pass LNG terminal, at the expiration of the term of the leases we are required to surrender the LNG terminal in good working order and repair, with normal wear and tear and casualty expected. Our property lease agreements at the Sabine Pass LNG terminal have terms of up to 90 years including renewal options. We have determined that the cost to surrender the liquefaction facilities at the Sabine Pass LNG terminal in good order and repair, with normal wear and tear and casualty expected, is zero . Income Taxes 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 Statements of Operations, is able to be included in the federal income tax return of Cheniere Partners, a publicly traded partnership which indirectly owns us. Accordingly, no provision or liability for federal or state income taxes is included in the accompanying Financial Statements. At December 31, 2016 , the tax basis of our assets and liabilities was $268.0 million more than the reported amounts of our assets and liabilities. Pursuant to the indentures governing our debt, we are permitted to make distributions (“Tax Distributions”) for any fiscal year or portion thereof in which we are a limited partnership, disregarded entity or other substantially similar pass-through entity for federal and state income tax purposes. The Tax Distributions are equal to the tax that we would owe if we were a corporation subject to federal and state income tax that filed separate federal and state income tax returns, excluding the amounts covered by the state tax sharing agreement discussed in Note 11—Related Party Transactions . The Tax Distributions are limited to the amount of federal and/or state income taxes paid by Cheniere to the appropriate taxing authorities and are payable by us within 30 days of the date that Cheniere is required to make federal or state income tax payments to the appropriate taxing authorities. Business Segment Our liquefaction operations at the Sabine Pass LNG terminal represent a single reportable segment. Our chief operating decision maker reviews the financial results of SPL in total when evaluating financial performance and for purposes of allocating resources.

Restricted Cash

Restricted Cash	3 Months Ended	12 Months Ended
	Mar. 31, 2017	Dec. 31, 2016
Cash and Cash Equivalents [Abstract]
Restricted Cash	RESTRICTED CASH Restricted cash consists of funds that are contractually restricted as to usage or withdrawal and have been presented separately from cash and cash equivalents on our Balance Sheets. As of March 31, 2017 and December 31, 2016 , restricted cash consisted of the following (in millions): March 31, December 31, 2017 2016 Current restricted cash Liquefaction Project $ 531 $ 358 Non-current restricted cash Liquefaction Project 1,000 —	RESTRICTED CASH Restricted cash consists of funds that are contractually restricted as to usage or withdrawal and have been presented separately from cash and cash equivalents on our Balance Sheets. As of December 31, 2016 and 2015 , restricted cash consisted of the following (in thousands): December 31, 2016 2015 Current restricted cash Liquefaction Project $ 357,953 $ 189,260

Accounts and Other Receivables

Accounts and Other Receivables	3 Months Ended	12 Months Ended
	Mar. 31, 2017	Dec. 31, 2016
Receivables [Abstract]
Accounts and Other Receivables	ACCOUNTS AND OTHER RECEIVABLES As of March 31, 2017 and December 31, 2016 , accounts and other receivables consisted of the following (in millions): March 31, December 31, 2017 2016 Trade receivable $ 92 $ 88 Other accounts receivable 9 2 Total accounts and other receivables $ 101 $ 90 Pursuant to the accounts agreement entered into with the collateral trustee for the benefit of our debt holders, we are required to deposit all cash received into reserve accounts controlled by the collateral trustee. The usage or withdrawal of such cash is restricted to the payment of liabilities related to the Liquefaction Project and other restricted payments. As of March 31, 2017 and December 31, 2016 , substantially all of our trade receivable balance was from two SPA customers.	ACCOUNTS AND OTHER RECEIVABLES As of December 31, 2016 and 2015 , accounts and other receivables consisted of the following (in thousands): December 31, 2016 2015 Trade receivable $ 87,555 $ — Other accounts receivable 2,174 577 Total accounts and other receivables $ 89,729 $ 577 Pursuant to the accounts agreement entered into with the collateral trustee for the benefit of our debt holders, we are required to deposit all cash received into reserve accounts controlled by the collateral trustee. The usage or withdrawal of such cash is restricted to the payment of liabilities related to the Liquefaction Project and other restricted payments. As of December 31, 2016 , approximately 99% of our trade receivable balance was from two SPA customers.

Inventory

Inventory	3 Months Ended	12 Months Ended
	Mar. 31, 2017	Dec. 31, 2016
Inventory Disclosure [Abstract]
Inventory	INVENTORY As of March 31, 2017 and December 31, 2016 , inventory consisted of the following (in millions): March 31, December 31, 2017 2016 Natural gas $ 19 $ 15 LNG 21 45 Materials and other 38 29 Total inventory $ 78 $ 89	INVENTORY As of December 31, 2016 and 2015 , inventory consisted of the following (in thousands): December 31, 2016 2015 Natural gas $ 14,755 $ 5,724 LNG 45,008 — Materials and other 28,758 18 Total inventory $ 88,521 $ 5,742

Property, Plant and Equipment

Property, Plant and Equipment	3 Months Ended	12 Months Ended
	Mar. 31, 2017	Dec. 31, 2016
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	PROPERTY, PLANT AND EQUIPMENT Property, plant and equipment, net consists of LNG terminal costs and fixed assets, as follows (in millions): March 31, December 31, 2017 2016 LNG terminal costs LNG terminal $ 7,696 $ 5,270 LNG terminal construction-in-process 4,789 6,675 Accumulated depreciation (121 ) (75 ) Total LNG terminal costs, net 12,364 11,870 Fixed assets Fixed assets 10 9 Accumulated depreciation (5 ) (4 ) Total fixed assets, net 5 5 Property, plant and equipment, net $ 12,369 $ 11,875 Depreciation expense during the three months ended March 31, 2017 and 2016 was $45 million and $1 million , respectively. During the three months ended March 31, 2017 and 2016 , we realized offsets to LNG terminal costs of $124 million and $14 million , respectively, that were related to the sale of commissioning cargoes because these amounts were earned prior to the start of commercial operations, during the testing phase for the construction of the Liquefaction Project .	PROPERTY, PLANT AND EQUIPMENT Property, plant and equipment consists of LNG terminal costs and fixed assets, as follows (in thousands): December 31, 2016 2015 LNG terminal costs LNG terminal $ 5,270,039 $ 42,220 LNG terminal construction-in-process 6,675,317 9,795,309 Accumulated depreciation (75,662 ) (789 ) Total LNG terminal costs, net 11,869,694 9,836,740 Fixed assets and other Furniture and fixtures 1,446 1,154 Computer software 4,373 3,782 Machinery and equipment 405 339 Vehicles 2,731 1,405 Other 714 390 Accumulated depreciation (4,520 ) (2,403 ) Total fixed assets and other, net 5,149 4,667 Property, plant and equipment, net $ 11,874,843 $ 9,841,407 Depreciation expense during the years ended December 31, 2016, 2015 and 2014 was $76.8 million , $1.9 million and $1.0 million , respectively. During the year ended December 31, 2016 , we realized offsets to LNG terminal costs of $201.0 million that was related to the sale of commissioning cargoes because this amount was earned prior to the start of commercial operations, during the testing phase for the construction of Trains 1 and 2 of the Liquefaction Project . LNG Terminal Costs LNG terminal costs related to the Liquefaction Project are depreciated using the straight-line depreciation method applied to groups of LNG terminal assets with varying useful lives. The identifiable components of the Liquefaction Project with similar estimated useful lives have a depreciable range between 6 and 50 years, as follows: Components Useful life (yrs) Water pipelines 30 Liquefaction processing equipment 6-50 Other 15-30 Fixed Assets and Other Our fixed assets and other are recorded at cost and are depreciated on a straight-line method based on estimated lives of the individual assets or groups of assets.

Derivative Instruments

Derivative Instruments	3 Months Ended	12 Months Ended
	Mar. 31, 2017	Dec. 31, 2016
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments	DERIVATIVE INSTRUMENTS We have entered into the following derivative instruments that are reported at fair value: • interest rate swaps to hedge the exposure to volatility in a portion of the floating-rate interest payments under one of our credit facilities (“Interest Rate Derivatives”) and • commodity derivatives consisting of natural gas supply contracts for the commissioning and operation of the Liquefaction Project (“Physical Liquefaction Supply Derivatives”) and associated economic hedges (collectively, the “Liquefaction Supply Derivatives”) . None of our derivative instruments are designated as cash flow hedging instruments, and changes in fair value are recorded within our Statements of Operations . The following table (in millions) 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, 2017 and December 31, 2016 , which are classified as other current assets , non-current derivative assets , derivative liabilities or non-current derivative liabilities in our Balance Sheets. Fair Value Measurements as of March 31, 2017 December 31, 2016 Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total Interest Rate Derivatives liability $ — $ — $ — $ — $ — $ (6 ) $ — $ (6 ) Liquefaction Supply Derivatives asset (liability) (2 ) — 41 39 (4 ) (2 ) 79 73 There have been no changes to our evaluation of and accounting for our derivative positions designated as Level 1 during the three months ended March 31, 2017 . See Note 7—Derivative Instruments of our Notes to Audited Financial Statements included elsewhere in this registration statement for additional information. We value our Interest Rate Derivatives using valuations based on the initial trade prices. Using an income-based approach, subsequent valuations are based on observable inputs to the valuation model including interest rate curves, risk adjusted discount rates, credit spreads and other relevant data. The fair value of our Physical Liquefaction Supply Derivatives is predominantly driven by market commodity basis prices and our assessment of the associated conditions precedent, including evaluating whether the respective market is available as pipeline infrastructure is developed. Upon the completion and placement into service of relevant pipeline infrastructure to accommodate marketable physical gas flow, we recognize a gain or loss based on the fair value of the respective natural gas supply contracts as of the reporting date. The fair value of substantially all of our Physical Liquefaction Supply Derivatives is developed through the use of internal models which are impacted by inputs that are unobservable in the marketplace. As a result, the fair value of our Physical Liquefaction Supply Derivatives is designated as Level 3 within the valuation hierarchy. 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 particular Physical Liquefaction Supply Derivatives 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. Internal fair value models include conditions precedent to the respective long-term natural gas supply contracts. As of March 31, 2017 and December 31, 2016 , some of our Physical Liquefaction Supply Derivatives existed within markets for which the pipeline infrastructure is under development to accommodate marketable physical gas flow. The following table includes quantitative information for the unobservable inputs for our Level 3 Physical Liquefaction Supply Derivatives as of March 31, 2017 : Net Fair Value Asset (in millions) Valuation Technique Significant Unobservable Input Significant Unobservable Inputs Range Physical Liquefaction Supply Derivatives $41 Income Approach Basis Spread $(0.345) - $0.081 The following table (in millions) shows the changes in the fair value of our Level 3 Physical Liquefaction Supply Derivatives during the three months ended March 31, 2017 and 2016 : Three Months Ended March 31, 2017 2016 Balance, beginning of period $ 79 $ 32 Realized and mark-to-market losses: Included in cost of sales (1) (41 ) (2 ) Purchases and settlements: Purchases 4 — Settlements (1) (1 ) — Balance, end of period $ 41 $ 30 Change in unrealized gains relating to instruments still held at end of period $ (41 ) $ (2 ) (1) Does not include the decrease in fair value of $1 million related to the realized gains capitalized during the three months ended March 31, 2016 . 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 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. Our derivative instruments are subject to contractual provisions which provide for the unconditional right of set-off for all derivative assets and liabilities with a given counterparty in the event of default. Interest Rate Derivatives We had entered into Interest Rate Derivatives to protect against volatility of future cash flows and hedge a portion of the variable interest payments on the credit facilities we entered into in June 2015 (the “2015 Credit Facilities”) . In March 2017, we settled the Interest Rate Derivatives and recognized a derivative loss of $7 million in conjunction with the termination of approximately $1.6 billion of commitments under the 2015 Credit Facilities , as discussed in Note 9—Debt . The following table (in millions) shows the fair value and location of our Interest Rate Derivatives on our Balance Sheets: Fair Value Measurements as of Balance Sheet Location March 31, 2017 December 31, 2016 Interest Rate Derivatives Derivative liabilities $ — $ (4 ) Interest Rate Derivatives Non-current derivative liabilities — (2 ) The following table (in millions) shows the changes in the fair value and settlements of our Interest Rate Derivatives recorded in derivative loss, net on our Statements of Operations during the three months ended March 31, 2017 and 2016 : Three Months Ended March 31, 2017 2016 Interest Rate Derivatives loss $ (2 ) $ (11 ) Liquefaction Supply Derivatives The following table (in millions) shows the fair value and location of our Liquefaction Supply Derivatives on our Balance Sheets: Fair Value Measurements as of (1) Balance Sheet Location March 31, 2017 December 31, 2016 Liquefaction Supply Derivatives Other current assets $ 16 $ 13 Liquefaction Supply Derivatives Non-current derivative assets 28 67 Liquefaction Supply Derivatives Derivative liabilities (4 ) (7 ) Liquefaction Supply Derivatives Non-current derivative liabilities (1 ) — (1) Does not include collateral of $5 million and $6 million deposited for such contracts, which is included in other current assets in our Balance Sheets as of March 31, 2017 and December 31, 2016 , respectively. We had secured up to approximately 2,051 million MMBtu and 1,994 million MMBtu of natural gas feedstock through natural gas supply contracts as of March 31, 2017 and December 31, 2016 , respectively. The notional natural gas position of our Liquefaction Supply Derivatives was approximately 1,214 million MMBtu and 1,117 million MMBtu as of March 31, 2017 and December 31, 2016 , respectively. The following table (in millions) shows the changes in the fair value, settlements and location of our Liquefaction Supply Derivatives recorded on our Statements of Operations during the three months ended March 31, 2017 and 2016 : Three Months Ended March 31, Statement of Operations Location (1) 2017 2016 Liquefaction Supply Derivatives loss (2) Cost of sales $ 39 $ 4 (1) Fair value fluctuations associated with commodity derivative activities are classified and presented consistently with the item economically hedged and the nature and intent of the derivative instrument. (2) Does not include the realized value associated with derivative instruments that settle through physical delivery. Balance Sheet Presentation Our derivative instruments are presented on a net basis on our Balance Sheets as described above. The following table (in millions) shows the fair value of our derivatives outstanding on a gross and net basis: Gross Amounts Recognized Gross Amounts Offset in the Balance Sheets Net Amounts Presented in the Balance Sheets Offsetting Derivative Assets (Liabilities) As of March 31, 2017 Liquefaction Supply Derivatives $ 48 $ (4 ) $ 44 Liquefaction Supply Derivatives 2 (7 ) (5 ) As of December 31, 2016 Interest Rate Derivatives $ (6 ) $ — $ (6 ) Liquefaction Supply Derivatives 82 (2 ) 80 Liquefaction Supply Derivatives (11 ) 4 (7 )	DERIVATIVE INSTRUMENTS We have entered into the following derivative instruments that are reported at fair value: • interest rate swaps to hedge the exposure to volatility in a portion of the floating-rate interest payments under one of our credit facilities (“Interest Rate Derivatives”) ; • commodity derivatives consisting of natural gas supply contracts for the commissioning and operation of the Liquefaction Project (“Physical Liquefaction Supply Derivatives”) and associated economic hedges (“Financial Liquefaction Supply Derivatives”, and collectively with the Physical Liquefaction Supply Derivatives, the “Liquefaction Supply Derivatives”) ; and • commodity derivatives to hedge the exposure to price risk attributable to future sales of our LNG inventory (“Natural Gas Derivatives”) . None of our derivative instruments are designated as cash flow hedging instruments, and changes in fair value are recorded within our Statements of Operations . The following table (in thousands) shows the fair value of the derivative instruments that are required to be measured at fair value on a recurring basis as of December 31, 2016 and 2015 , which are classified as other current assets , non-current derivative assets , derivative liabilities or non-current derivative liabilities in our Balance Sheets. Fair Value Measurements as of December 31, 2016 December 31, 2015 Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total Interest Rate Derivatives liability $ — $ (6,224 ) $ — $ (6,224 ) $ — $ (8,740 ) $ — $ (8,740 ) Liquefaction Supply Derivatives asset (liability) (4,483 ) (1,474 ) 79,022 73,065 — (25 ) 32,492 32,467 Natural Gas Derivatives asset — — — — — 29 — 29 We value our Interest Rate Derivatives using valuations based on the initial trade prices. Using an income-based approach, subsequent valuations are based on observable inputs to the valuation model including interest rate curves, risk adjusted discount rates, credit spreads and other relevant data. The estimated fair values of our Natural Gas Derivatives are the amounts at which the instruments could be exchanged currently between willing parties. We value these derivatives using observable commodity price curves and other relevant data. The fair value of substantially all of our Physical Liquefaction Supply Derivatives is developed through the use of internal models which are impacted by inputs that are unobservable in the marketplace. As a result, the fair value of our Physical Liquefaction Supply Derivatives is designated as Level 3 within the valuation hierarchy. 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 particular Physical Liquefaction Supply Derivatives 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. Internal fair value models include conditions precedent to the respective long-term natural gas supply contracts. As of December 31, 2016 and 2015 , some of our Physical Liquefaction Supply Derivatives existed within markets for which the pipeline infrastructure is under development to accommodate marketable physical gas flow. Accordingly, our internal fair value models are based on market prices that equate to our own contractual pricing due to: (1) the inactive and unobservable market and (2) conditions precedent and their impact on the uncertainty in the timing of our actual receipt of the physical volumes associated with each forward. The fair value of our Physical Liquefaction Supply Derivatives is predominantly driven by market commodity basis prices and our assessment of the associated conditions precedent, including evaluating whether the respective market is available as pipeline infrastructure is developed. Upon the completion and placement into service of relevant pipeline infrastructure to accommodate marketable physical gas flow, we recognize a gain or loss based on the fair value of the respective natural gas supply contracts as of the reporting date. As all of our Physical Liquefaction Supply Derivatives are either purely index-priced or index-priced with a fixed basis, we do not believe that a significant change in market commodity prices would have a material impact on our Level 3 fair value measurements. The following table includes quantitative information for the unobservable inputs for our Level 3 Physical Liquefaction Supply Derivatives as of December 31, 2016 : Net Fair Value Asset (in thousands) Valuation Technique Significant Unobservable Input Significant Unobservable Inputs Range Physical Liquefaction Supply Derivatives $79,022 Income Approach Basis Spread $(0.260) - $(0.003) The following table (in thousands) shows the changes in the fair value of our Level 3 Physical Liquefaction Supply Derivatives during the years ended December 31, 2016 and 2015 : Year Ended December 31, 2016 2015 Balance, beginning of period $ 32,492 $ 342 Realized and mark-to-market gains: Included in cost of sales (1) 48,218 32,150 Purchases and settlements: Purchases 538 — Settlements (1) (2,226 ) — Transfers out of Level 3 — — Balance, end of period $ 79,022 $ 32,492 Change in unrealized gains relating to instruments still held at end of period $ 48,938 $ 32,150 (1) Does not include the decrease in fair value of $0.7 million related to the realized gains capitalized during the year ended December 31, 2016 . 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 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. Our derivative instruments are subject to contractual provisions which provide for the unconditional right of set-off for all derivative assets and liabilities with a given counterparty in the event of default. Interest Rate Derivatives We have entered into Interest Rate Derivatives to protect against volatility of future cash flows and hedge a portion of the variable interest payments on the credit facilities we entered into in June 2015 (the “2015 Credit Facilities”) . The Interest Rate Derivatives hedge a portion of the expected outstanding borrowings over the term of the 2015 Credit Facilities . In March 2015, we settled a portion of our Interest Rate Derivatives and recognized a derivative loss of $34.7 million within our Statements of Operations in conjunction with the termination of approximately $1.8 billion of commitments under the previous credit facilities. As of December 31, 2016 , we had the following Interest Rate Derivatives outstanding: Initial Notional Amount Maximum Notional Amount Effective Date Maturity Date Weighted Average Fixed Interest Rate Paid Variable Interest Rate Received Interest Rate Derivatives $20.0 million $628.8 million August 14, 2012 July 31, 2019 1.98% One-month LIBOR The following table (in thousands) shows the fair value and location of our Interest Rate Derivatives on our Balance Sheets: Fair Value Measurements as of Balance Sheet Location December 31, 2016 December 31, 2015 Interest Rate Derivatives Derivative liabilities $ (4,223 ) $ (5,940 ) Interest Rate Derivatives Non-current derivative liabilities (2,001 ) (2,800 ) The following table (in thousands) shows the changes in the fair value and settlements of our Interest Rate Derivatives recorded in derivative loss, net on our Statements of Operations during the years ended December 31, 2016, 2015 and 2014 : Year Ended December 31, 2016 2015 2014 Interest Rate Derivatives loss $ (5,934 ) $ (41,722 ) $ (119,401 ) Commodity Derivatives Liquefaction Supply Derivatives We have entered into 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 primarily range from approximately one to seven years and commence upon the satisfaction of certain conditions precedent, including but not limited to the date of first commercial delivery of specified Train s of the Liquefaction Project . We recognize our Physical Liquefaction Supply Derivatives as either assets or liabilities and measure those instruments at fair value. Changes in the fair value of our Physical Liquefaction Supply Derivatives are reported in earnings. As of December 31, 2016 , we have secured up to approximately 1,993.9 million MMBtu of natural gas feedstock through natural gas supply contracts. The notional natural gas position of our Physical Liquefaction Supply Derivatives was approximately 1,111.4 million MMBtu as of December 31, 2016 . Our Financial Liquefaction Supply Derivatives are executed through over-the-counter contracts which are subject to nominal credit risk as these transactions are settled on a daily margin basis with investment grade financial institutions. We are required by these financial institutions to use margin deposits as credit support for our Financial Liquefaction Supply Derivatives activities. The notional natural gas position of our Financial Liquefaction Supply Derivatives was approximately 5.6 million MMBtu as of December 31, 2016 . Natural Gas Derivatives Our Natural Gas Derivatives were executed through over-the-counter contracts which were subject to nominal credit risk as these transactions settled on a daily margin basis with investment grade financial institutions. We were required by these financial institutions to use margin deposits as credit support for our Natural Gas Derivatives activities. As of December 31, 2016 , we did not have any open Natural Gas Derivatives positions or margin deposits at financial institutions. We recognize all commodity derivative instruments, including our Liquefaction Supply Derivatives and our Natural Gas Derivatives (collectively, “Commodity Derivatives”) , as either assets or liabilities and measure those instruments at fair value. Changes in the fair value of our Commodity Derivatives are reported in earnings. The following table (in thousands) shows the fair value and location of our Commodity Derivatives on our Balance Sheets: December 31, 2016 December 31, 2015 Liquefaction Supply Derivatives (1) Natural Gas Derivatives Total Liquefaction Supply Derivatives Natural Gas Derivatives (2) Total Balance Sheet Location Other current assets $ 13,535 $ — $ 13,535 $ 2,737 $ 29 $ 2,766 Non-current derivative assets 66,788 — 66,788 30,304 — 30,304 Total derivative assets 80,323 — 80,323 33,041 29 33,070 Derivative liabilities (7,258 ) — (7,258 ) (490 ) — (490 ) Non-current derivative liabilities — — — (84 ) — (84 ) Total derivative liabilities (7,258 ) — (7,258 ) (574 ) — (574 ) Derivative asset, net $ 73,065 $ — $ 73,065 $ 32,467 $ 29 $ 32,496 (1) Does not include collateral of $6.0 million deposited for such contracts, which is included in other current assets in our Balance Sheet as of December 31, 2016 . (2) Does not include collateral of $0.4 million deposited for such contracts, which is included in other current assets in our Balance Sheet as of December 31, 2015 . The following table (in thousands) shows the changes in the fair value, settlements and location of our Commodity Derivatives recorded on our Statements of Operations during the years ended December 31, 2016, 2015 and 2014 : Year Ended December 31, Statement of Operations Location (1) 2016 2015 2014 Liquefaction Supply Derivatives loss LNG revenues $ (8 ) $ — $ — Liquefaction Supply Derivatives gain (2) Cost (cost recovery) of sales (42,172 ) (32,503 ) (342 ) Natural Gas Derivatives gain Operating and maintenance expense (150 ) (1,842 ) (860 ) (1) Fair value fluctuations associated with commodity derivative activities are classified and presented consistently with the item economically hedged and the nature and intent of the derivative instrument. (2) Does not include the realized value associated with derivative instruments that settle through physical delivery. The use of Commodity Derivatives exposes us to counterparty credit risk, or the risk that a counterparty will be unable to meet its commitments in instances when our Commodity Derivatives are in an asset position. Balance Sheet Presentation Our derivative instruments are presented on a net basis on our Balance Sheets as described above. The following table (in thousands) shows the fair value of our derivatives outstanding on a gross and net basis: Gross Amounts Recognized Gross Amounts Offset in the Balance Sheets Net Amounts Presented in the Balance Sheets Offsetting Derivative Assets (Liabilities) As of December 31, 2016 Interest Rate Derivatives $ (6,229 ) $ 5 $ (6,224 ) Liquefaction Supply Derivatives 82,116 (1,793 ) 80,323 Liquefaction Supply Derivatives (11,078 ) 3,820 (7,258 ) As of December 31, 2015 Interest Rate Derivatives $ (8,740 ) $ — $ (8,740 ) Liquefaction Supply Derivatives 33,636 (595 ) 33,041 Liquefaction Supply Derivatives (574 ) — (574 ) Natural Gas Derivatives 152 (123 ) 29

Other Non-Current Assets

Other Non-Current Assets	3 Months Ended	12 Months Ended
	Mar. 31, 2017	Dec. 31, 2016
Other Assets, Noncurrent [Abstract]
Other Non-Current Assets	OTHER NON-CURRENT ASSETS As of March 31, 2017 and December 31, 2016 , other non-current assets consisted of the following (in millions): March 31, December 31, 2017 2016 Advances made under EPC and non-EPC contracts $ 20 $ 23 Advances made to municipalities for water system enhancements 95 95 Advances and other asset conveyances to third parties to support LNG terminals 30 31 Tax-related payments and receivables — 3 Information technology service assets 21 22 Other 2 11 Total other non-current assets, net $ 168 $ 185	OTHER NON-CURRENT ASSETS As of December 31, 2016 and 2015 , other non-current assets consisted of the following (in thousands): December 31, 2016 2015 Advances made under EPC and non-EPC contracts $ 22,809 $ 32,049 Advances made to municipalities for water system enhancements 95,495 89,953 Advances and other asset conveyances to third parties to support LNG terminals 30,707 28,850 Tax-related payments and receivables 3,248 5,535 Information technology service assets 22,145 24,166 Other 10,939 14,265 Total other non-current assets, net $ 185,343 $ 194,818

Accrued Liabilities

Accrued Liabilities	3 Months Ended	12 Months Ended
	Mar. 31, 2017	Dec. 31, 2016
Accrued Liabilities, Current [Abstract]
Accrued Liabilities	ACCRUED LIABILITIES As of March 31, 2017 and December 31, 2016 , accrued liabilities consisted of the following (in millions): March 31, December 31, 2017 2016 Interest costs and related debt fees $ 147 $ 204 Liquefaction Project costs 259 203 Total accrued liabilities $ 406 $ 407	ACCRUED LIABILITIES As of December 31, 2016 and 2015 , accrued liabilities consisted of the following (in thousands): December 31, 2016 2015 Interest costs and related debt fees $ 204,110 $ 135,336 Liquefaction Project costs 203,316 66,223 Other accrued liabilities 43 — Total accrued liabilities $ 407,469 $ 201,559

Debt

Debt	3 Months Ended	12 Months Ended
	Mar. 31, 2017	Dec. 31, 2016
Debt Disclosure [Abstract]
Debt	DEBT As of March 31, 2017 and December 31, 2016 , our debt consisted of the following (in millions): March 31, December 31, 2017 2016 Long-term debt 5.625% Senior Secured Notes due 2021 (“2021 Senior Notes”), net of unamortized premium of $7 and $7 $ 2,007 $ 2,007 6.25% Senior Secured Notes due 2022 (“2022 Senior Notes”) 1,000 1,000 5.625% Senior Secured Notes due 2023 (“2023 Senior Notes”), net of unamortized premium of $5 and $6 1,505 1,506 5.75% Senior Secured Notes due 2024 (“2024 Senior Notes”) 2,000 2,000 5.625% Senior Secured Notes due 2025 (“2025 Senior Notes”) 2,000 2,000 5.875% Senior Secured Notes due 2026 (“2026 Senior Notes”) 1,500 1,500 5.00% Senior Secured Notes due 2027 (“2027 Senior Notes”) 1,500 1,500 4.200% Senior Secured Notes due 2028 (“2028 Senior Notes”), net of unamortized discount of $1 and zero 1,349 — 5.00% Senior Secured Notes due 2037 (“2037 Senior Notes”) 800 — 2015 Credit Facilities — 314 Unamortized debt issuance costs (201 ) (178 ) Total long-term debt, net 13,460 11,649 Current debt $1.2 billion Working Capital Facility (“Working Capital Facility”) — 224 Total debt, net $ 13,460 $ 11,873 2017 Debt Issuances and Redemptions Senior Notes In February 2017, we issued an aggregate principal amount of $800 million of the 2037 Senior Notes on a private placement basis in reliance on the exemption from registration provided for under Section 4(a)(2) of the Securities Act of 1933, as amended. In March 2017, we issued an aggregate principal amount of $1.35 billion , before discount, of the 2028 Senior Notes . Net proceeds of the offerings of the 2037 Senior Notes and the 2028 Senior Notes were $789 million and $1.33 billion , respectively, after deducting the initial purchasers’ commissions (for the 2028 Senior Notes ) and estimated fees and expenses. The net proceeds of the 2037 Senior Notes were used to repay the then outstanding borrowings of $369 million under the 2015 Credit Facilities and, along with the net proceeds of the 2028 Senior Notes , the remainder is being used to pay a portion of the capital costs in connection with the construction of Trains 1 through 5 of the Liquefaction Project in lieu of the terminated portion of the commitments under the 2015 Credit Facilities . In connection with the issuance of the 2037 Senior Notes and the 2028 Senior Notes , we terminated the remaining available balance of $1.6 billion under the 2015 Credit Facilities , resulting in a write-off of debt issuance costs associated with the 2015 Credit Facilities of $42 million during the three months ended March 31, 2017 . The 2037 Senior Notes and the 2028 Senior Notes accrue interest at fixed rates of 5.00% and 4.200% , respectively, and interest is payable semi-annually in arrears. The terms of the 2037 Senior Notes are governed by an indenture which contains customary terms and events of default and certain covenants that, among other things, limit our ability and the ability of our restricted subsidiaries to incur additional indebtedness or issue preferred stock, make certain investments or pay dividends or distributions on capital stock or subordinated indebtedness or purchase, redeem or retire capital stock, sell or transfer assets, including capital stock of our restricted subsidiaries, restrict dividends or other payments by restricted subsidiaries, incur liens, enter into transactions with affiliates, dissolve, liquidate, consolidate, merge, sell or lease all or substantially all of our assets and enter into certain LNG sales contracts. The 2028 Senior Notes are governed by the same common indenture as our other senior notes, which also contains customary terms and events of default, covenants and redemption terms. At any time prior to six months before the respective dates of maturity of the 2037 Senior Notes and the 2028 Senior Notes , we may redeem all or part of such notes at a redemption price equal to the “optional redemption” price for the 2037 Senior Notes or the “make-whole” price for the 2028 Senior Notes , as set forth in the respective indentures governing the notes, plus accrued and unpaid interest, if any, to the date of redemption. We may also, at any time within six months of the respective maturity dates for the 2037 Senior Notes and the 2028 Senior Notes , redeem all or part of such notes at a redemption price equal to 100% of the principal amount of such notes to be redeemed, plus accrued and unpaid interest, if any, to the date of redemption. In connection with the issuance of the 2028 Senior Notes , we entered into a registration rights agreement (the “Registration Rights Agreement”) . Under the terms of the Registration Rights Agreement , we have agreed, and any future guarantors will agree, to use commercially reasonable efforts to file with the SEC and cause to become effective a registration statement relating to an offer to exchange any and all of the 2028 Senior Notes for a like aggregate principal amount of our debt securities with terms identical in all material respects to the 2028 Senior Notes sought to be exchanged (other than with respect to restrictions on transfer or to any increase in annual interest rate), within 360 days after March 6, 2017. Under specified circumstances, we have also agreed, and any future guarantors will also agree, to use commercially reasonable efforts to cause to become effective a shelf registration statement relating to resales of the 2028 Senior Notes . We will be obligated to pay additional interest on the 2028 Senior Notes if we fail to comply with our obligation to register them within the specified time period. Credit Facilities Below is a summary (in millions) of our Working Capital Facility as of March 31, 2017 : Working Capital Facility Original facility size $ 1,200 Outstanding balance — Letters of credit issued 377 Available commitment $ 823 Interest rate LIBOR plus 1.75% or base rate plus 0.75% Maturity date December 31, 2020, with various terms for underlying loans Interest Expense Total interest expense consisted of the following (in millions): Three Months Ended March 31, 2017 2016 Total interest cost $ 186 $ 147 Capitalized interest (81 ) (141 ) Total interest expense, net $ 105 $ 6 Fair Value Disclosures The following table (in millions) shows the carrying amount and estimated fair value of our debt: March 31, 2017 December 31, 2016 Carrying Amount Estimated Fair Value Carrying Amount Estimated Fair Value Senior notes, net of premium or discount (1) $ 12,861 $ 13,807 $ 11,513 $ 12,309 2037 Senior Notes (2) 800 826 — — Credit facilities (3) — — 538 538 (1) Includes 2021 Senior Notes , 2022 Senior Notes , 2023 Senior Notes , 2024 Senior Notes , 2025 Senior Notes , 2026 Senior Notes , 2027 Senior Notes and 2028 Senior Notes . The Level 2 estimated fair value was based on quotes obtained from broker-dealers or market makers of these senior notes and other similar instruments. (2) The Level 3 estimated fair value was calculated based on inputs that are observable in the market or that could be derived from, or corroborated with, observable market data, including our stock price and interest rates based on debt issued by parties with comparable credit ratings to us and inputs that are not observable in the market. (3) Includes 2015 Credit Facilities and Working Capital Facility . The Level 3 estimated fair value approximates the principal amount because the interest rates are variable and reflective of market rates and the debt may be repaid, in full or in part, at any time without penalty.	DEBT As of December 31, 2016 and 2015 , our debt consisted of the following (in thousands): December 31, 2016 2015 Long-term debt 5.625% Senior Secured Notes due 2021 (“2021 Senior Notes”), net of unamortized premium of $7,181 and $8,718 $ 2,007,181 $ 2,008,718 6.25% Senior Secured Notes due 2022 (“2022 Senior Notes”) 1,000,000 1,000,000 5.625% Senior Secured Notes due 2023 (“2023 Senior Notes”), net of unamortized premium of $5,657 and $6,392 1,505,657 1,506,392 5.75% Senior Secured Notes due 2024 (“2024 Senior Notes”) 2,000,000 2,000,000 5.625% Senior Secured Notes due 2025 (“2025 Senior Notes”) 2,000,000 2,000,000 5.875% Senior Secured Notes due 2026 (“2026 Senior Notes”) 1,500,000 — 5.00% Senior Secured Notes due 2027 (“2027 Senior Notes”) 1,500,000 — 2015 Credit Facilities 314,000 845,000 Unamortized debt issuance costs (1) (177,609 ) (154,551 ) Total long-term debt, net 11,649,229 9,205,559 Current debt $1.2 billion Working Capital Facility (“Working Capital Facility”) 223,500 15,000 Total debt, net $ 11,872,729 $ 9,220,559 (1) Effective January 1, 2016, we adopted ASU 2015-03 and ASU 2015-15, which require debt issuance costs related to term notes to be presented in the balance sheet as a direct deduction from the debt liability, rather than as an asset, retrospectively for each reporting period presented. As a result, we reclassified $154.6 million from debt issuance costs, net to long-term debt, net as of December 31, 2015 . Below is a schedule of future principal payments that we are obligated to make, based on current construction schedules, on our outstanding debt at December 31, 2016 (in thousands): Years Ending December 31, Principal Payments 2017 $ 223,500 2018 — 2019 — 2020 314,000 2021 2,000,000 Thereafter 9,500,000 Total $ 12,037,500 Senior Notes The terms of the 2021 Senior Notes , 2022 Senior Notes , 2023 Senior Notes , 2024 Senior Notes , 2025 Senior Notes , 2026 Senior Notes and 2027 Senior Notes (collectively, the “Senior Notes”) are governed by a common indenture (the “Indenture”) , and interest on the Senior Notes is payable semi-annually in arrears. The Indenture contains customary terms and events of default and certain covenants that, among other things, limit our ability and the ability of our restricted subsidiaries to: incur additional indebtedness; issue preferred stock, make certain investments or pay dividends or distributions on capital stock or subordinated indebtedness; purchase, redeem or retire capital stock; sell or transfer assets, including capital stock of our restricted subsidiaries; restrict dividends or other payments by restricted subsidiaries; incur liens; enter into transactions with affiliates; consolidate, merge, sell or lease all or substantially all of our assets; and enter into certain LNG sales contracts. See Note 16—Subsequent Events for additional information regarding covenants under the Indenture . Subject to permitted liens, the Senior Notes are secured on a pari passu first-priority basis by a security interest in all of the membership interests in us and substantially all of our assets. We may not make any distributions until, among other requirements, deposits are made into debt service reserve accounts as required and a debt service coverage ratio for the prior 12 -month period and a projected debt service coverage ratio for the upcoming 12 -month period of 1.25 :1.00 are satisfied. At any time prior to three months before the respective dates of maturity for each series of the Senior Notes (except for the 2026 Senior Notes and 2027 Senior Notes , in which case the time period is six months before the respective dates of maturity), we may redeem all or part of such series of the Senior Notes at a redemption price equal to the “make-whole” price set forth in the Indenture , plus accrued and unpaid interest, if any, to the date of redemption. We may also, at any time within three months of the respective maturity dates for each series of the Senior Notes (except for the 2026 Senior Notes and 2027 Senior Notes , in which case the time period is six months before the respective dates of maturity), redeem all or part of such series of the Senior Notes at a redemption price equal to 100% of the principal amount of such series of the Senior Notes to be redeemed, plus accrued and unpaid interest, if any, to the date of redemption. In connection with the issuance of the 2026 Senior Notes and the 2027 Senior Notes , we entered into registration rights agreements (the “Registration Rights Agreements”) . Under the terms of the Registration Rights Agreements , we have agreed, and any future guarantors will agree, to use commercially reasonable efforts to file with the SEC and cause to become effective registration statements relating to offers to exchange any and all of the 2026 Senior Notes and 2027 Senior Notes for like aggregate principal amounts of our debt securities with terms identical in all material respects to the respective senior notes sought to be exchanged (other than with respect to restrictions on transfer or to any increase in annual interest rate), within 360 days after June 14, 2016 and September 23, 2016, respectively. Under specified circumstances, we have also agreed, and any future guarantors will also agree, to use commercially reasonable efforts to cause to become effective shelf registration statements relating to resales of the 2026 Senior Notes and the 2027 Senior Notes . We will be obligated to pay additional interest on these senior notes if we fail to comply with our obligation to register them within the specified time period. Credit Facilities Below is a summary of our credit facilities outstanding as of December 31, 2016 (in thousands): 2015 Credit Facilities Working Capital Facility Original facility size $ 4,600,000 $ 1,200,000 Outstanding balance 314,000 223,500 Commitments prepaid or terminated 2,643,867 — Letters of credit issued — 323,677 Available commitment $ 1,642,133 $ 652,823 Interest rate LIBOR plus 1.30% - 1.75% or base rate plus 1.75% LIBOR plus 1.75% or base rate plus 0.75% Maturity date Earlier of December 31, 2020 or second anniversary of Trains 1 through 5 completion date December 31, 2020, with various terms for underlying loans 2015 Credit Facilities In June 2015, we entered into the 2015 Credit Facilities with commitments aggregating $4.6 billion . The 2015 Credit Facilities are being used to fund a portion of the costs of developing, constructing and placing into operation Trains 1 through 5 of the Liquefaction Project. Borrowings under the 2015 Credit Facilities may be refinanced, in whole or in part, at any time without premium or penalty; however, interest rate hedging and interest rate breakage costs may be incurred. During 2016, in conjunction with the issuance of the 2026 Senior Notes and the 2027 Senior Notes , we prepaid outstanding borrowings and terminated commitments under the 2015 Credit Facilities for approximately $2.6 billion . These prepayments and termination of commitments resulted in a write-off of debt issuance costs and payment of fees associated with the 2015 Credit Facilities of $52.2 million during the year ended December 31, 2016 . Loans under the 2015 Credit Facilities accrue interest at a variable rate per annum equal to, at SPL’s election, LIBOR or the base rate plus the applicable margin. The applicable margin for LIBOR loans ranges from 1.30% to 1.75% , depending on the applicable 2015 Credit Facility, and the applicable margin for base rate loans is 1.75% . Interest on LIBOR loans is due and payable at the end of each LIBOR period and interest on base rate loans is due and payable at the end of each quarter. In addition to interest, we are required to pay insurance/guarantee premiums of 0.45% per annum on any drawn amounts under the covered tranches of the 2015 Credit Facilities . The 2015 Credit Facilities also require us to pay a quarterly commitment fee calculated at a rate per annum equal to either: (1) 40% of the applicable margin, multiplied by the average daily amount of the undrawn commitment or (2) 0.70% of the undrawn commitment, depending on the applicable 2015 Credit Facility . The principal of the loans made under the 2015 Credit Facilities must be repaid in quarterly installments, commencing with the earlier of June 30, 2020 and the last day of the first full calendar quarter after the completion date of Trains 1 through 5 of the Liquefaction Project . Scheduled repayments are based upon an 18 -year amortization profile, with the remaining balance due upon the maturity of the 2015 Credit Facilities . The 2015 Credit Facilities contain conditions precedent for borrowings, as well as customary affirmative and negative covenants. Our obligations under the 2015 Credit Facilities are secured by substantially all of our assets as well as all of our membership interests on a pari passu basis with the Senior Notes and the Working Capital Facility . Under the terms of the 2015 Credit Facilities , we are required to hedge not less than 65% of the variable interest rate exposure of our projected outstanding borrowings, calculated on a weighted average basis in comparison to our anticipated draw of principal. Additionally, we may not make any distributions until certain conditions have been met, including that deposits are made into debt service reserve accounts and a debt service coverage ratio test of 1.25 :1.00 is satisfied. Working Capital Facility In September 2015, we entered into the Working Capital Facility , which is intended to be used for loans (“Working Capital Loans”) , the issuance of letters of credit, as well as for swing line loans (“Swing Line Loans”) , primarily for certain working capital requirements related to developing and placing into operation the Liquefaction Project . We may, from time to time, request increases in the commitments under the Working Capital Facility of up to $760 million and, upon the completion of the debt financing of Train 6 of the Liquefaction Project , request an incremental increase in commitments of up to an additional $390 million . Loans under the Working Capital Facility accrue interest at a variable rate per annum equal to LIBOR or the base rate (equal to the highest of the senior facility agent’s published prime rate, the federal funds effective rate, as published by the Federal Reserve Bank of New York, plus 0.50% and one month LIBOR plus 0.50% ), plus the applicable margin. The applicable margin for LIBOR loans under the Working Capital Facility is 1.75% per annum, and the applicable margin for base rate loans under the Working Capital Facility is 0.75% per annum. Interest on Swing Line Loans and loans deemed made in connection with a draw upon a letter of credit (“LC Loans”) is due and payable on the date the loan becomes due. Interest on LIBOR loans is due and payable at the end of each applicable LIBOR period, and interest on base rate loans is due and payable at the end of each fiscal quarter. However, if such base rate loan is converted into a LIBOR loan, interest is due and payable on that date. Additionally, if the loans become due prior to such periods, the interest also becomes due on that date. We pay (1) a commitment fee equal to an annual rate of 0.70% on the average daily amount of the excess of the total commitment amount over the principal amount outstanding without giving effect to any outstanding Swing Line Loans and (2) a letter of credit fee equal to an annual rate of 1.75% of the undrawn portion of all letters of credit issued under the Working Capital Facility . If draws are made upon a letter of credit issued under the Working Capital Facility and we do not elect for such draw (an “LC Draw”) to be deemed an LC Loan, we are required to pay the full amount of the LC Draw on or prior to the business day following the notice of the LC Draw . An LC Draw accrues interest at an annual rate of 2.0% plus the base rate. As of December 31, 2016 , no LC Draw s had been made upon any letters of credit issued under the Working Capital Facility . The Working Capital Facility matures on December 31, 2020, and the outstanding balance may be repaid, in whole or in part, at any time without premium or penalty upon three business days’ notice. LC Loans have a term of up to one year . Swing Line Loans terminate upon the earliest of (1) the maturity date or earlier termination of the Working Capital Facility , (2) the date 15 days after such Swing Line Loan is made and (3) the first borrowing date for a Working Capital Loan or Swing Line Loan occurring at least three business days following the date the Swing Line Loan is made. We are required to reduce the aggregate outstanding principal amount of all Working Capital Loans to zero for a period of five consecutive business days at least once each year. The Working Capital Facility contains conditions precedent for extensions of credit, as well as customary affirmative and negative covenants. Our obligations under the Working Capital Facility are secured by substantially all of our assets as well as all of our membership interests on a pari passu basis with the Senior Notes and the 2015 Credit Facilities . Interest Expense Total interest expense consisted of the following (in thousands): Year Ended December 31, 2016 2015 2014 Total interest cost $ 648,915 $ 531,495 $ 397,949 Capitalized interest (463,090 ) (495,165 ) (374,040 ) Total interest expense, net $ 185,825 $ 36,330 $ 23,909 Fair Value Disclosures The following table (in thousands) shows the carrying amount and estimated fair value of our debt: December 31, 2016 December 31, 2015 Carrying Amount Estimated Fair Value Carrying Amount Estimated Fair Value Senior Notes, net of premium (1) $ 11,512,838 $ 12,308,736 $ 8,515,110 $ 7,469,718 Credit facilities (2) 537,500 537,500 860,000 860,000 (1) The Level 2 estimated fair value was based on quotes obtained from broker-dealers or market makers of the Senior Notes and other similar instruments. (2) Includes 2015 Credit Facilities and Working Capital Facility . The Level 3 estimated fair value approximates the principal amount because the interest rates are variable and reflective of market rates and the debt may be repaid, in full or in part, at any time without penalty.

Related Party Transactions

Related Party Transactions	3 Months Ended	12 Months Ended
	Mar. 31, 2017	Dec. 31, 2016
Related Party Transactions [Abstract]
Related Party Transactions	RELATED PARTY TRANSACTIONS Below is a summary of our related party transactions as reported on our Statements of Operations for the three months ended March 31, 2017 and 2016 (in millions): Three Months Ended March 31, 2017 2016 LNG revenues—affiliate Cheniere Marketing SPA and Cheniere Marketing Master SPA $ 331 $ — Cost of sales—affiliate Cargo loading fees under the Terminal Use Rights Assignment and Agreement (the “TURA”) 4 — Operating and maintenance expense—affiliate TUA 33 — Natural Gas Transportation Agreement 16 — Services Agreements 10 1 Total operating and maintenance expense—affiliate 59 1 General and administrative expense—affiliate Services Agreements 17 17 LNG Terminal-Related Agreements Terminal Use Agreements We have entered into a TUA with SPLNG to provide berthing for LNG vessels and for the unloading, loading, storage and regasification of LNG . We have reserved approximately 2.0 Bcf/d of regasification capacity and we are obligated to make monthly capacity payments to SPLNG aggregating approximately $250 million per year (the “TUA Fees”) , continuing until at least 20 years after we deliver our first commercial cargo at the Liquefaction Project . We obtained this reserved capacity as a result of an assignment in July 2012 by Cheniere Investments of its rights, title and interest under its TUA . In connection with the assignment, we, Cheniere Investments and SPLNG also entered into the TURA pursuant to which Cheniere Investments has the right to use our reserved capacity under the TUA and has the obligation to pay the TUA Fees required by the TUA to SPLNG. Cheniere Investments’ right to use our capacity at the Sabine Pass LNG terminal and its respective percentage of TUA fees payable is reduced from 100% to zero (unless Cheniere Investments utilizes terminal use capacity after Train 4 reaches commercial operations) as each of Trains 1 through 4 reaches commercial operation. The percentage of the TUA Fees payable by Cheniere Investments and by us varies based upon the number of Trains that have reached commercial operations. The following table shows the percentages of all TUA Fees payable to SPLNG by Cheniere Investments and us in accordance with the TURA : Period Percentage of TUA Fees Payable by Investments Percentage of TUA Fees Payable by SPL Prior to May 2016 (substantial completion of Train 1) 100% 0% May 2016 - September 2016 (substantial completion of Train 2) 75% 25% September 2016 - March 2017 (substantial completion of Train 3) 50% 50% March 2017 through substantial completion of Train 4 25% 75% After substantial completion of Train 4 0% 100% Cheniere Partners has guaranteed our obligations under our TUA and the obligations of Cheniere Investments under the TURA . Cargo loading fees incurred under this agreement are recorded as cost of sales—affiliate, except for the portion related to commissioning activities which is capitalized as LNG terminal construction-in-process. In connection with our TUA , we are required to pay for a portion of the cost to maintain the cryogenic readiness of the regasification facilities at the Sabine Pass LNG terminal, which is based on our approximately 41% share of the commercial LNG storage capacity at the Sabine Pass LNG terminal. Cheniere Marketing SPA Cheniere Marketing has entered into an SPA with us to purchase, at Cheniere Marketing’s option, any LNG produced by us in excess of that required for other customers at a price of 115% of Henry Hub plus $3.00 per MMBtu of LNG . Cheniere Marketing Master SPA We have entered into an agreement with Cheniere Marketing that allows us to sell and purchase LNG with Cheniere Marketing by executing and delivering confirmations under this agreement. Commissioning Confirmation Under the Cheniere Marketing Master SPA, we have executed a confirmation with Cheniere Marketing that obligates Cheniere Marketing in certain circumstances to buy LNG cargoes produced during the periods while Bechtel Oil, Gas and Chemicals, Inc. has control of, and is commissioning, the first four Trains of the Liquefaction Project. Pre-commercial LNG Marketing Agreement We have entered into an agreement with Cheniere Marketing that authorizes Cheniere Marketing to act on our behalf to market and sell certain quantities of pre-commercial LNG that has not been accepted by BG Gulf Coast LNG, LLC, one of our SPA customers. We pay a fee to Cheniere Marketing for marketing and transportation, which is based on volume sold under this agreement. Natural Gas Transportation Agreement To ensure we are able to transport adequate natural gas feedstock to the Sabine Pass LNG terminal, we have entered into transportation precedent and other agreements to secure firm pipeline transportation capacity with CTPL, a wholly owned subsidiary of Cheniere Partners, and third-party pipeline companies. Services Agreements As of March 31, 2017 and December 31, 2016 , we had $51 million and $26 million of advances to affiliates, respectively, under the services agreements described below. The non-reimbursement amounts incurred under these agreements are recorded in general and administrative expense—affiliate. Liquefaction O&M Agreement We have entered into an operation and maintenance agreement (the “Liquefaction O&M Agreement”) with Cheniere Investments, a wholly owned subsidiary of Cheniere Partners, pursuant to which we receive all of the necessary services required to construct, operate and maintain the Liquefaction Project . Before the Liquefaction Project is operational, the services to be provided include, among other services, obtaining governmental approvals on our behalf, preparing an operating plan for certain periods, obtaining insurance, preparing staffing plans and preparing status reports. After the Liquefaction Project is operational, the services include all necessary services required to operate and maintain the Liquefaction Project . Before the Liquefaction Project is operational, in addition to reimbursement of operating expenses, we are required to pay a monthly fee equal to 0.6% of the capital expenditures incurred in the previous month. After substantial completion of each Train, for services performed while the Liquefaction Project is operational, we will pay, in addition to the reimbursement of operating expenses, a fixed monthly fee of $83,333 (indexed for inflation) for services with respect to such Train. Liquefaction MSA We have entered into a management services agreement (the “Liquefaction MSA”) with Cheniere Terminals pursuant to which Cheniere Terminals manages the construction and operation of the Liquefaction Project, excluding those matters provided for under the Liquefaction O&M Agreement . The services include, among other services, exercising the day-to-day management of our affairs and business, managing our regulatory matters, managing bank and brokerage accounts and financial books and records of our business and operations, entering into financial derivatives on our behalf and providing contract administration services for all contracts associated with the Liquefaction Project . Under the Liquefaction MSA , we pay a monthly fee equal to 2.4% of the capital expenditures incurred in the previous month, which is recorded as general and administrative expense—affiliate on our Statements of Operations. After substantial completion of each Train, we will pay a fixed monthly fee of $541,667 (indexed for inflation) for services with respect to such Train. Cheniere Investments Information Technology Services Agreement Cheniere Investments has entered into an information technology services agreement with Cheniere, pursuant to which Cheniere Investment’s subsidiaries, including us, receive certain information technology services. On a quarterly basis, the various entities receiving the benefit are invoiced by Cheniere according to the cost allocation percentages set forth in the agreement. In addition, Cheniere is entitled to reimbursement for all costs incurred by Cheniere that are necessary to perform the services under the agreement. LNG Site Sublease Agreement We have entered into agreements with SPLNG to sublease a portion of the Sabine Pass LNG terminal site for the Liquefaction Project . The aggregate annual sublease payment is $1 million . The initial terms of the subleases expire on December 31, 2034, with options to renew for multiple 10 -year extensions with similar terms as the initial terms. The annual sublease payments will be adjusted for inflation every five years based on a consumer price index, as defined in the sublease agreements. Cooperation Agreement We have entered into an agreement with SPLNG that allows us to retain and acquire certain rights to access the property and facilities that are owned by SPLNG for the purpose of constructing, modifying and operating the Liquefaction Project . In consideration for access given to us, we have agreed to transfer to SPLNG title of certain facilities, equipment and modifications, which SPLNG is obligated to operate and maintain. The term of this agreement is consistent with our TUA described above. Under this agreement, we conveyed to SPLNG zero and $253 million of assets during the three months ended March 31, 2017 and 2016 , respectively, which have been recorded as non-cash distributions to affiliates. Contract for Sale and Purchase of Natural Gas and LNG We have entered into an agreement with SPLNG that allows us to sell and purchase natural gas and LNG with SPLNG. Natural gas and LNG purchased under this agreement are recorded as inventory, except for purchases related to commissioning activities which are capitalized as LNG terminal construction-in-process. State Tax Sharing Agreement We have entered into a state tax sharing agreement with Cheniere. Under this agreement, Cheniere has agreed to prepare and file all state and local tax returns which we and Cheniere are required to file on a combined basis and to timely pay the combined state and local tax liability. If Cheniere, in its sole discretion, demands payment, we will pay to Cheniere an amount equal to the state and local tax that we would be required to pay if our state and local tax liability were calculated on a separate company basis. There have been no state and local taxes paid by Cheniere for which Cheniere could have demanded payment from us under this agreement; therefore, Cheniere has not demanded any such payments from us. The agreement is effective for tax returns due on or after August 2012.	RELATED PARTY TRANSACTIONS Below is a summary of our related party transactions as reported on our Statements of Operations for the years ended December 31, 2016, 2015 and 2014 (in thousands): Year Ended December 31, 2016 2015 2014 LNG revenues—affiliate Cheniere Marketing SPA and Cheniere Marketing Master SPA $ 293,957 $ — $ — Cost of sales—affiliate Cargo loading fees under the Terminal Use Rights Assignment and Agreement (the “TURA”) 5,264 — — Fees under the Pre-commercial LNG Marketing Agreement 1,490 — — Total cost of sales—affiliate 6,754 — — Operating and maintenance expense—affiliate TUA 60,516 — — Natural Gas Transportation Agreement 44,656 — — Services Agreements 22,424 860 95 LNG Site Sublease Agreement 827 471 — Total operating and maintenance expense—affiliate 128,423 1,331 95 Terminal use agreement maintenance expense—affiliate TUA 208 400 387 Development expense—affiliate Services Agreements 396 722 1,153 LNG Site Sublease Agreement 115 — — Total development expense—affiliate 511 722 1,153 General and administrative expense—affiliate Services Agreements 68,070 87,425 70,553 LNG Site Sublease Agreement — 241 482 Other agreements — 15 30 Total general and administrative expense—affiliate 68,070 87,681 71,065 LNG Terminal-Related Agreements Terminal Use Agreements We have entered into a TUA with SPLNG to provide berthing for LNG vessels and for the unloading, loading, storage and regasification of LNG . We have reserved approximately 2.0 Bcf/d of regasification capacity and we are obligated to make monthly capacity payments to SPLNG aggregating approximately $250 million per year (the “TUA Fees”) , continuing until at least 20 years after we deliver our first commercial cargo at the Liquefaction Project . We obtained this reserved capacity as a result of an assignment in July 2012 by Cheniere Investments of its rights, title and interest under its TUA . In connection with the assignment, we, Cheniere Investments and SPLNG also entered into the TURA pursuant to which Cheniere Investments has the right to use our reserved capacity under the TUA and has the obligation to pay the TUA Fees required by the TUA to SPLNG. Cheniere Investments’ right to use our capacity at the Sabine Pass LNG terminal will be reduced as each of Trains 1 through 4 reaches commercial operation. The percentage of the TUA Fees payable by Cheniere Investments will be reduced from 100% to zero (unless Cheniere Investments utilizes terminal use capacity after Train 4 reaches commercial operations), and the percentage of the TUA Fees payable by us will increase by the amount that Cheniere Investments’ percentage decreases. In May 2016, upon substantial completion of Train 1 of the Liquefaction Project , Cheniere Investments’ percentage of all TUA Fees payable to SPLNG was reduced from 100% to 75% and our percentage of all TUA Fees payable to SPLNG was increased from zero to 25% in accordance with the TURA . Subsequently, in September 2016, upon substantial completion of Train 2 of the Liquefaction Project , Cheniere Investments’ percentage of all TUA Fees payable to SPLNG was further reduced from 75% to 50% and our percentage of all TUA Fees payable to SPLNG was further increased from 25% to 50% in accordance with the TURA . Cheniere Partners has guaranteed our obligations under our TUA and the obligations of Cheniere Investments under the TURA . Cargo loading fees incurred under this agreement are recorded as cost of sales—affiliate, except for the portion related to commissioning activities which is capitalized as LNG terminal construction-in-process. In connection with our TUA , we are required to pay for a portion of the cost to maintain the cryogenic readiness of the regasification facilities at the Sabine Pass LNG terminal. We are required to reimburse SPLNG for a portion of its fuel costs related to maintaining the cryogenic readiness of the Sabine Pass LNG terminal, which is recorded as terminal use agreement maintenance expense on our Statements of Operations. Our portion of the cost (including affiliate) to maintain the cryogenic readiness of the regasification facilities at the Sabine Pass LNG terminal is based on our approximately 41% share of the commercial LNG storage capacity at the Sabine Pass LNG terminal. Cheniere Marketing SPA Cheniere Marketing has entered into an SPA with us to purchase, at Cheniere Marketing’s option, any LNG produced by us in excess of that required for other customers at a price of 115% of Henry Hub plus $3.00 per MMBtu of LNG . Cheniere Marketing Master SPA In May 2015, we entered into an agreement with Cheniere Marketing that allows us to sell and purchase LNG with Cheniere Marketing by executing and delivering confirmations under this agreement. Commissioning Confirmation In May 2015, under the Cheniere Marketing Master SPA, we executed a confirmation with Cheniere Marketing that obligates Cheniere Marketing in certain circumstances to buy LNG cargoes produced during the periods while Bechtel Oil, Gas and Chemicals, Inc. (“Bechtel”) has control of, and is commissioning, the first four Trains of the Liquefaction Project. Pre-commercial LNG Marketing Agreement In May 2015, we entered into an agreement with Cheniere Marketing that authorizes Cheniere Marketing to act on our behalf to market and sell certain quantities of pre-commercial LNG that has not been accepted by BG Gulf Coast LNG, LLC, one of our SPA customers. We pay a fee to Cheniere Marketing for marketing and transportation, which is based on volume sold under this agreement. Natural Gas Transportation Agreement To ensure we are able to transport adequate natural gas feedstock to the Sabine Pass LNG terminal, we have entered into transportation precedent and other agreements to secure firm pipeline transportation capacity with CTPL, a wholly owned subsidiary of Cheniere Partners, and third-party pipeline companies. Services Agreements As of December 31, 2016 and 2015 , we had $25.9 million and $28.3 million of advances to affiliates, respectively, under the services agreements described below. The non-reimbursement amounts incurred under this agreement are recorded in general and administrative expense—affiliate. Liquefaction O&M Agreement We have entered into an operation and maintenance agreement (the “Liquefaction O&M Agreement”) with Cheniere Investments, a wholly owned subsidiary of Cheniere Partners, pursuant to which we receive all of the necessary services required to construct, operate and maintain the Liquefaction Project . Before the Liquefaction Project is operational, the services to be provided include, among other services, obtaining governmental approvals on our behalf, preparing an operating plan for certain periods, obtaining insurance, preparing staffing plans and preparing status reports. After the Liquefaction Project is operational, the services include all necessary services required to operate and maintain the Liquefaction Project . Before the Liquefaction Project is operational, in addition to reimbursement of operating expenses, we are required to pay a monthly fee equal to 0.6% of the capital expenditures incurred in the previous month. After substantial completion of each Train, for services performed while the Liquefaction Project is operational, we will pay, in addition to the reimbursement of operating expenses, a fixed monthly fee of $83,333 (indexed for inflation) for services with respect to such Train. Liquefaction MSA We have entered into a management services agreement (the “Liquefaction MSA”) with Cheniere Terminals pursuant to which Cheniere Terminals manages the construction and operation of the Liquefaction Project, excluding those matters provided for under the Liquefaction O&M Agreement . The services include, among other services, exercising the day-to-day management of our affairs and business, managing our regulatory matters, managing bank and brokerage accounts and financial books and records of our business and operations, entering into financial derivatives on our behalf and providing contract administration services for all contracts associated with the Liquefaction Project . Under the Liquefaction MSA , we pay a monthly fee equal to 2.4% of the capital expenditures incurred in the previous month, which is recorded as general and administrative expense—affiliate on our Statements of Operations. After substantial completion of each Train, we will pay a fixed monthly fee of $541,667 (indexed for inflation) for services with respect to such Train. Cheniere Investments Information Technology Services Agreement Cheniere Investments has entered into an information technology services agreement with Cheniere, pursuant to which Cheniere Investment’s subsidiaries, including us, receive certain information technology services. On a quarterly basis, the various entities receiving the benefit are invoiced by Cheniere according to the cost allocation percentages set forth in the agreement. In addition, Cheniere is entitled to reimbursement for all costs incurred by Cheniere that are necessary to perform the services under the agreement. LNG Site Sublease Agreement We have entered into agreements with SPLNG to sublease a portion of the Sabine Pass LNG terminal site for the Liquefaction Project . The aggregate annual sublease payment is $0.9 million , which was increased from $0.5 million during 2015. The initial terms of the subleases expire on December 31, 2034, with options to renew for multiple 10 -year extensions with similar terms as the initial terms. The annual sublease payments will be adjusted for inflation every five years based on a consumer price index, as defined in the sublease agreements. Cooperation Agreement We have entered into an agreement with SPLNG that allows us to retain and acquire certain rights to access the property and facilities that are owned by SPLNG for the purpose of constructing, modifying and operating the Liquefaction Project . In consideration for access given to us, we have agreed to transfer to SPLNG title of certain facilities, equipment and modifications, which SPLNG is obligated to operate and maintain. The term of this agreement is consistent with our TUA described above. Under this agreement, we conveyed to SPLNG $252.8 million , $80.5 million and $0.7 million of assets during the years ended December 31, 2016, 2015 and 2014 , respectively, which have been recorded as non-cash distributions to affiliates. Interconnect Agreement We have entered into an agreement with CTPL to construct certain interconnect facilities between a 94 -mile pipeline that interconnects the Sabine Pass LNG terminal with a number of large interstate pipelines and the Liquefaction Project , with ownership and responsibility for maintenance and operation transferred to CTPL following construction. Upon completion of modifications during the third quarter of 2015, we conveyed to CTPL $10.1 million of assets under this agreement. Contract for Sale and Purchase of Natural Gas and LNG We have entered into an agreement with SPLNG that allows us to sell and purchase natural gas and LNG with SPLNG. Natural gas and LNG purchased under this agreement are recorded as inventory, except for purchases related to commissioning activities which are capitalized as LNG terminal construction-in-process. State Tax Sharing Agreement In August 2012, we entered into a state tax sharing agreement with Cheniere. Under this agreement, Cheniere has agreed to prepare and file all state and local tax returns which we and Cheniere are required to file on a combined basis and to timely pay the combined state and local tax liability. If Cheniere, in its sole discretion, demands payment, we will pay to Cheniere an amount equal to the state and local tax that we would be required to pay if our state and local tax liability were calculated on a separate company basis. There have been no state and local taxes paid by Cheniere for which Cheniere could have demanded payment from us under this agreement; therefore, Cheniere has not demanded any such payments from us. The agreement is effective for tax returns due on or after August 2012.

Leases

Leases	12 Months Ended
	Dec. 31, 2016
Leases [Abstract]
Leases	During the years ended December 31, 2016, 2015 and 2014 , we recognized rental expense for all operating leases of $1.8 million , $1.2 million and $0.9 million , respectively, related primarily to land sites for the Liquefaction Project. In June 2012, we entered into an agreement with SPLNG to sublease a portion of its Sabine Pass LNG terminal site for the Liquefaction Project. See Note 11—Related Party Transactions for additional information regarding this sublease agreement. Future annual minimum lease payments, excluding inflationary adjustments and payments to affiliates, are as follows (in thousands): Years ending December 31, Operating Leases (1) 2017 $ 396 2018 396 2019 396 2020 396 2021 373 Thereafter 5,137 Total $ 7,094 (1) Includes certain lease option renewals that are reasonably assured .

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2016
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	COMMITMENTS AND CONTINGENCIES We have various contractual obligations which are recorded as liabilities in our Financial Statements. Other items, such as certain purchase commitments and other executed contracts which do not meet the definition of a liability as of December 31, 2016 , are not recognized as liabilities but require disclosures in our Financial Statements. LNG Terminal Commitments and Contingencies Obligations under EPC Contracts We have entered into lump sum turnkey contracts with Bechtel for the engineering, procurement and construction of Trains 3 through 5 of the Liquefaction Project . The EPC contract for Trains 3 and 4 and the EPC contract for Train 5 provide that we will pay Bechtel contract prices of $3.9 billion and $3.0 billion , respectively, subject to adjustment by change order. We have the right to terminate each EPC contract for our convenience, in which case Bechtel will be paid (1) the portion of the contract price for the work performed, (2) costs reasonably incurred by Bechtel on account of such termination and demobilization, and (3) a lump sum of up to $30.0 million depending on the termination date. Obligations under SPAs We have entered into third-party SPAs which obligate us to purchase and liquefy sufficient quantities of natural gas to deliver 401.5 million MMBtu per year of LNG to the customers’ vessels for Trains 1 and 2 of the Liquefaction Project and 628.5 million MMBtu per year of LNG for Trains 3 through 5 of the Liquefaction Project , subject to completion of construction. Obligations under Natural Gas Supply, Transportation and Storage Service Agreements We have entered into index-based physical natural gas supply contracts to secure natural gas feedstock for the Liquefaction Project . The terms of these contracts primarily range from approximately one to six years and commence upon the occurrence of conditions precedent, including our declaration to the respective natural gas supplier that we are ready to commence the term of the supply arrangement in anticipation of the date of first commercial operation of the applicable, specified Trains of the Liquefaction Project . As of December 31, 2016 , we have secured up to approximately 1,993.9 million MMBtu of natural gas feedstock through natural gas supply contracts, of which we determined that we have purchase obligations for the contracts for which conditions precedent were met. Additionally, we have entered into transportation and storage service agreements for the Liquefaction Project . The initial term of the transportation agreements ranges from 10 to 20 years, with renewal options for certain contracts, and commences upon the occurrence of conditions precedent. The term of our storage service agreements ranges from three to ten years. As of December 31, 2016 , our obligations under natural gas supply, transportation and storage service agreements for contracts in which conditions precedent were met were as follows (in thousands): Years Ending December 31, Payments Due (1) 2017 $ 1,611,296 2018 1,192,791 2019 1,019,309 2020 1,055,497 2021 903,425 Thereafter 2,169,912 Total $ 7,952,230 (1) Pricing of natural gas supply contracts are variable based on market commodity basis prices adjusted for basis spread . Amounts included are based on prices and basis spreads as of December 31, 2016 . Obligations under LNG TUAs We have entered into a TUA with SPLNG pursuant to which we have reserved approximately 2.0 Bcf/d of regasification capacity. See Note 11—Related Party Transactions for additional information regarding this TUA. In September 2012, we entered into a partial TUA assignment agreement with Total Gas & Power North America, Inc. (“Total”) , whereby we will progressively gain access to Total ’s capacity and other services provided under Total ’s TUA with SPLNG. This agreement provides us with additional berthing and storage capacity at the Sabine Pass LNG terminal that may be used to accommodate the development of Trains 5 and 6, provides increased flexibility in managing LNG cargo loading and unloading activity starting with the commencement of commercial operations of Train 3 and permits us to more flexibly manage our storage with the commencement of Train 1. Notwithstanding any arrangements between Total and us, payments required to be made by Total to SPLNG continue to be made by Total to SPLNG in accordance with its TUA. Services Agreements We have entered into certain services agreements with affiliates. See Note 11—Related Party Transactions for information regarding such agreements. State Tax Sharing Agreement In August 2012, we entered into a state tax sharing agreement with Cheniere. See Note 11—Related Party Transactions for additional information regarding this agreement. Other Commitments In the ordinary course of business, we have entered into certain multi-year licensing and service agreements, none of which are considered material to our financial position. Additionally, we have various lease commitments, as disclosed in Note 12—Leases . Legal Proceedings We may in the future be involved as a party to various legal proceedings, which are incidental to the ordinary course of business. We regularly analyze current information and, as necessary, provide accruals for probable liabilities on the eventual disposition of these matters. In the opinion of management, as of December 31, 2016 , there were no pending legal matters that would reasonably be expected to have a material impact on our operating results, financial position or cash flows.

Supplemental Cash Flow Informat

Supplemental Cash Flow Information	3 Months Ended	12 Months Ended
	Mar. 31, 2017	Dec. 31, 2016
Supplemental Cash Flow Information [Abstract]
Supplemental Cash Flow Information	SUPPLEMENTAL CASH FLOW INFORMATION The following table (in millions) provides supplemental disclosure of cash flow information: Three Months Ended March 31, 2017 2016 Cash paid during the period for interest, net of amounts capitalized $ 154 $ 27 Non-cash distributions to affiliates for conveyance of assets — 253 The balance in property, plant and equipment, net funded with accounts payable and accrued liabilities (including affiliate) was $306 million and $303 million , as of March 31, 2017 and 2016 , respectively.	SUPPLEMENTAL CASH FLOW INFORMATION The following table (in thousands) provides supplemental disclosure of cash flow information: Year Ended December 31, 2016 2015 2014 Cash paid during the period for interest, net of amounts capitalized $ 74,519 $ — $ — Non-cash distributions to affiliates for conveyance of assets 252,802 90,645 745 Other non-cash distribution to affiliates — 149 — Non-cash conveyance of assets to non-affiliate — 13,169 — The balance in property, plant and equipment, net funded with accounts payable and accrued liabilities (including affiliate) was $262.6 million , $228.2 million and $117.4 million , as of December 31, 2016 , 2015 and 2014 , respectively.

Recent Accounting Standards

Recent Accounting Standards	3 Months Ended	12 Months Ended
	Mar. 31, 2017	Dec. 31, 2016
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
Recent Accounting Standards	RECENT ACCOUNTING STANDARDS The following table provides a brief description of recent accounting standards that had not been adopted by the Company as of March 31, 2017 : Standard Description Expected Date of Adoption Effect on our Financial Statements or Other Significant Matters ASU 2014-09, Revenue from Contracts with Customers (Topic 606) , and subsequent amendments thereto This standard provides a single, comprehensive revenue recognition model which replaces and supersedes most existing revenue recognition guidance and requires an entity to recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. The standard requires that the costs to obtain and fulfill contracts with customers should be recognized as assets and amortized to match the pattern of transfer of goods or services to the customer if expected to be recoverable. The standard also requires enhanced disclosures. This guidance may be adopted either retrospectively to each prior reporting period presented subject to allowable practical expedients (“full retrospective approach”) or as a cumulative-effect adjustment as of the date of adoption (“modified retrospective approach”). January 1, 2018 We continue to evaluate the effect of this standard on our Financial Statements. Preliminarily, we plan to adopt this standard using the full retrospective approach and we do not currently anticipate that the adoption will have a material impact upon our revenues. The Financial Accounting Standards Board has issued and may issue in the future amendments and interpretive guidance which may cause our evaluation to change. Furthermore, we routinely enter into new contracts and we cannot predict with certainty whether the accounting for any future contract under the new standard would result in a significant change from existing guidance. Because this assessment is preliminary and the accounting for revenue recognition is subject to significant judgment, this conclusion could change as we finalize our assessment. We have not yet determined the impact that recognizing fulfillment costs as assets will have on our Financial Statements. ASU 2016-02, Leases (Topic 842) This standard requires a lessee to recognize leases on its balance sheet by recording a lease liability representing the obligation to make future lease payments and a right-of-use asset representing the right to use the underlying asset for the lease term. A lessee is permitted to make an election not to recognize lease assets and liabilities for leases with a term of 12 months or less. The standard also modifies the definition of a lease and requires expanded disclosures. This guidance may be early adopted, and must be adopted using a modified retrospective approach with certain available practical expedients. January 1, 2019 We continue to evaluate the effect of this standard on our Financial Statements. Preliminarily, we expect that the requirement to recognize all leases on our Balance Sheets will be a significant change from current practice but will not have a material impact upon our Balance Sheets. Because this assessment is preliminary and the accounting for leases is subject to significant judgment, this conclusion could change as we finalize our assessment. We have not yet determined the impact of the adoption of this standard upon our results of operations or cash flows, whether we will elect to early adopt this standard or which, if any, practical expedients we will elect upon transition. ASU 2016-16, Income Taxes (Topic 740): Intra-Entity Transfers of Assets Other Than Inventory This standard requires the immediate recognition of the tax consequences of intercompany asset transfers other than inventory. This guidance may be early adopted, but only at the beginning of an annual period, and must be adopted using a modified retrospective approach. January 1, 2018 We are currently evaluating the impact of the provisions of this guidance on our Financial Statements and related disclosures. Additionally, the following table provides a brief description of a recent accounting standard that was adopted by the Company during the reporting period: Standard Description Date of Adoption Effect on our Financial Statements or Other Significant Matters ASU 2015-11, Inventory (Topic 330): Simplifying the Measurement of Inventory This standard requires inventory to be measured at the lower of cost and net realizable value. Net realizable value is the estimated selling prices in the ordinary course of business, less reasonably predictable costs of completion, disposal and transportation. This guidance may be early adopted and must be adopted prospectively. January 1, 2017 The adoption of this guidance did not have a material impact on our Financial Statements or related disclosures.	RECENT ACCOUNTING STANDARDS The following table provides a brief description of recent accounting standards that had not been adopted by the Company as of December 31, 2016 : Standard Description Expected Date of Adoption Effect on our Financial Statements or Other Significant Matters ASU 2014-09, Revenue from Contracts with Customers (Topic 606) , and subsequent amendments thereto This standard provides a single, comprehensive revenue recognition model which replaces and supersedes most existing revenue recognition guidance and requires an entity to recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. The standard requires that the costs to obtain and fulfill contracts with customers should be recognized as assets and amortized to match the pattern of transfer of goods or services to the customer if expected to be recoverable. The standard also requires enhanced disclosures. This guidance may be adopted either retrospectively to each prior reporting period presented subject to allowable practical expedients (“full retrospective approach”) or as a cumulative-effect adjustment as of the date of adoption (“modified retrospective approach”). January 1, 2018 We continue to evaluate the effect of this standard on our Financial Statements. Preliminarily, we plan to adopt this standard using the full retrospective approach and we do not currently anticipate that the adoption will have a material impact upon our revenues. The FASB has issued and may issue in the future amendments and interpretive guidance which may cause our evaluation to change. Furthermore, we routinely enter into new contracts and we cannot predict with certainty whether the accounting for any future contract under the new standard would result in a significant change from existing guidance. Because this assessment is preliminary and the accounting for revenue recognition is subject to significant judgment, this conclusion could change as we finalize our assessment. We have not yet determined the impact that recognizing fulfillment costs as assets will have on our Financial Statements. ASU 2015-11, Inventory (Topic 330): Simplifying the Measurement of Inventory This standard requires inventory to be measured at the lower of cost and net realizable value. Net realizable value is the estimated selling prices in the ordinary course of business, less reasonably predictable costs of completion, disposal and transportation. This guidance may be early adopted and must be adopted prospectively. January 1, 2017 The adoption of this guidance will not have a material impact on our Financial Statements or related disclosures. ASU 2016-02, Leases (Topic 842) This standard requires a lessee to recognize leases on its balance sheet by recording a lease liability representing the obligation to make future lease payments and a right-of-use asset representing the right to use the underlying asset for the lease term. A lessee is permitted to make an election not to recognize lease assets and liabilities for leases with a term of 12 months or less. The standard also modifies the definition of a lease and requires expanded disclosures. This guidance may be early adopted, and must be adopted using a modified retrospective approach with certain available practical expedients. January 1, 2019 We continue to evaluate the effect of this standard on our Financial Statements. Preliminarily, we expect that the requirement to recognize all leases will be a significant change from current practice but will not have a material impact upon our Balance Sheets. Because this assessment is preliminary and the accounting for leases is subject to significant judgment, this conclusion could change as we finalize our assessment. We have not yet determined the impact of the adoption of this standard upon our results of operations or cash flows, whether we will elect to early adopt this standard or which, if any, practical expedients we will elect upon transition. Standard Description Expected Date of Adoption Effect on our Financial Statements or Other Significant Matters ASU 2016-16, Income Taxes (Topic 740): Intra-Entity Transfers of Assets Other Than Inventory This standard requires the immediate recognition of the tax consequences of intercompany asset transfers other than inventory. This guidance may be early adopted, but only at the beginning of an annual period, and must be adopted using a modified retrospective approach. January 1, 2018 We are currently evaluating the impact of the provisions of this guidance on our Financial Statements and related disclosures. Additionally, the following table provides a brief description of recent accounting standards that were adopted by the Company during the reporting period: Standard Description Date of Adoption Effect on our Financial Statements or Other Significant Matters ASU 2015-03, Interest - Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs and ASU 2015-15, Presentation and Subsequent Measurement of Debt Issuance Costs Associated with Line-of-Credit Arrangements These standards require debt issuance costs related to a recognized debt liability to be presented in the balance sheet as a direct deduction from the debt liability rather than as an asset. Debt issuance costs incurred in connection with line of credit arrangements may be presented as an asset and subsequently amortized ratably over the term of the line of credit arrangement. This guidance may be early adopted, and must be adopted retrospectively to each prior reporting period presented. January 1, 2016 Upon adoption of these standards, the balance of debt, net was reduced by the balance of debt issuance costs, net, except for the balance related to line of credit arrangements, on our Balance Sheets. See Note 10—Debt for additional disclosures. ASU 2014-15, Presentation of Financial Statements-Going Concern (Subtopic 205-40): Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern This standard requires an entity’s management to evaluate, for each reporting period, whether there are conditions and events that raise substantial doubt about the entity’s ability to continue as a going concern within one year after the financial statements are issued. Additional disclosures are required if management concludes that conditions or events raise substantial doubt about the entity’s ability to continue as a going concern. Early adoption is permitted. December 31, 2016 The adoption of this guidance did not have an impact on our Financial Statements or related disclosures. ASU 2016-18, Statement of Cash Flows (Topic 230): Restricted Cash (a consensus of the FASB Emerging Issues Task Force) This standard requires an entity to show the changes in the total of cash, cash equivalents, restricted cash and restricted cash equivalents in the statement of cash flows. This guidance may be early adopted, and must be adopted retrospectively to each prior reporting period presented. December 31, 2016 As a result of adopting this standard, our Statements of Cash Flows now reconciles the balance of total cash, cash equivalents and restricted cash from the beginning of the period to the end of the period. This resulted in changes to previously reported cash flows from operating, investing and financing activities. Standard Description Date of Adoption Effect on our Financial Statements or Other Significant Matters ASU 2017-01, Business Combinations (Topic 805): Clarifying the Definition of a Business This standard narrows the accounting definition of a business and clarifies that when substantially all of the fair value of an integrated set of assets and activities is concentrated in a single asset or a group of similar assets, the integrated set of assets and activities is not a business. The definition of a business affects many areas of accounting including acquisitions, disposals, goodwill and consolidation. This guidance may be early adopted and must be adopted prospectively. December 31, 2016 The adoption of this guidance did not have an impact on our Financial Statements or related disclosures.

Subsequent Events

Subsequent Events	12 Months Ended
	Dec. 31, 2016
Subsequent Events [Abstract]
Subsequent Events	SUBSEQUENT EVENTS Senior Notes In January 2017, we were assigned a second investment grade rating on our senior secured notes by rating agencies. As a result, certain covenants, including those that limit SPL’s ability to make certain investments, under the Indenture are no longer applicable. Private Placement Notes In February 2017, we entered into a Note Purchase Agreement with various purchasers to issue and sell $800 million aggregate principal amount of 5.00% senior secured notes due 2037 in a private placement conducted pursuant to Section 4(a)(2) of the Securities Act.

Summarized Quarterly Financial

Summarized Quarterly Financial Data (unaudited)	12 Months Ended
	Dec. 31, 2016
Quarterly Financial Information Disclosure [Abstract]
Summarized Quarterly Financial Data (unaudited)	Summarized Quarterly Financial Data—(in thousands) First Quarter Second Quarter Third Quarter Fourth Quarter Year ended December 31, 2016: Revenues $ 28 $ 85,326 $ 264,424 $ 483,633 Income (loss) from operations (30,061 ) (28,521 ) (15,375 ) 123,804 Net income (loss) (47,241 ) (86,690 ) (104,343 ) 44,809 Year ended December 31, 2015: Revenues $ — $ — $ — $ — Loss from operations (37,089 ) (29,532 ) (9,891 ) (15,120 ) Net loss (169,549 ) (48,101 ) (12,835 ) (35,132 )

Nature of Operations and Basi24

Nature of Operations and Basis of Presentation (Policies)	3 Months Ended	12 Months Ended
	Mar. 31, 2017	Dec. 31, 2016
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Basis of Presentation, Policy	The accompanying unaudited Financial Statements of SPL have been prepared in accordance with GAAP for interim financial information and with Rule 10-01 of Regulation S-X. Accordingly, they do not include all of the information and footnotes required by GAAP for complete financial statements and should be read in conjunction with the Audited Financial Statements and accompanying notes included elsewhere in this registration statement. In our opinion, all adjustments, consisting only of normal recurring adjustments necessary for a fair presentation, have been included. Certain reclassifications have been made to conform prior period information to the current presentation. The reclassifications had no effect on our overall financial position, results of operations or cash flows.	Basis of Presentation The accompanying Financial Statements of SPL have been prepared in accordance with GAAP . Certain reclassifications have been made to conform prior period information to the current presentation. The reclassifications had no effect on our overall financial position, operating results or cash flows. In 2016, we started production at the Liquefaction Project . As a result, we introduced a new line item entitled “cost of sales” and modified the components of activity included in “operating and maintenance expense” on our Statements of Operations. To conform to the new presentation, reclassifications were made to the prior periods. Cost of sales includes costs incurred directly for the production and delivery of LNG from the Liquefaction Project such as natural gas feedstock, variable transportation and storage costs, derivative gains and losses associated with economic hedges to secure natural gas feedstock for the Liquefaction Project , and other costs related to converting natural gas into LNG, all to the extent not utilized for the commissioning process. These costs were reclassified from operating and maintenance expense. Operating and maintenance expense now includes costs associated with operating and maintaining the Liquefaction Project such as third-party service and maintenance contract costs, payroll and benefit costs of operations personnel, natural gas transportation and storage capacity demand charges, derivative gains and losses related to the sale and purchase of LNG associated with the regasification terminal, insurance and regulatory costs. Additionally, we renamed our “revenues” line item as “LNG revenues”, which include fees that are received pursuant to our SPAs and related LNG marketing activities.
Income Taxes, Policy	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 Statements of Operations, is able to be included in the federal income tax return of Cheniere Partners, a publicly traded partnership which indirectly owns us. Accordingly, no provision or liability for federal or state income taxes is included in the accompanying Financial Statements.	Income Taxes 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 Statements of Operations, is able to be included in the federal income tax return of Cheniere Partners, a publicly traded partnership which indirectly owns us. Accordingly, no provision or liability for federal or state income taxes is included in the accompanying Financial Statements. At December 31, 2016 , the tax basis of our assets and liabilities was $268.0 million more than the reported amounts of our assets and liabilities. Pursuant to the indentures governing our debt, we are permitted to make distributions (“Tax Distributions”) for any fiscal year or portion thereof in which we are a limited partnership, disregarded entity or other substantially similar pass-through entity for federal and state income tax purposes. The Tax Distributions are equal to the tax that we would owe if we were a corporation subject to federal and state income tax that filed separate federal and state income tax returns, excluding the amounts covered by the state tax sharing agreement discussed in Note 11—Related Party Transactions . The Tax Distributions are limited to the amount of federal and/or state income taxes paid by Cheniere to the appropriate taxing authorities and are payable by us within 30 days of the date that Cheniere is required to make federal or state income tax payments to the appropriate taxing authorities.

Summary of Significant Accoun25

Summary of Significant Accounting Policies (Policies)	3 Months Ended	12 Months Ended
	Mar. 31, 2017	Dec. 31, 2016
Accounting Policies [Abstract]
Basis of Presentation, Policy	The accompanying unaudited Financial Statements of SPL have been prepared in accordance with GAAP for interim financial information and with Rule 10-01 of Regulation S-X. Accordingly, they do not include all of the information and footnotes required by GAAP for complete financial statements and should be read in conjunction with the Audited Financial Statements and accompanying notes included elsewhere in this registration statement. In our opinion, all adjustments, consisting only of normal recurring adjustments necessary for a fair presentation, have been included. Certain reclassifications have been made to conform prior period information to the current presentation. The reclassifications had no effect on our overall financial position, results of operations or cash flows.	Basis of Presentation The accompanying Financial Statements of SPL have been prepared in accordance with GAAP . Certain reclassifications have been made to conform prior period information to the current presentation. The reclassifications had no effect on our overall financial position, operating results or cash flows. In 2016, we started production at the Liquefaction Project . As a result, we introduced a new line item entitled “cost of sales” and modified the components of activity included in “operating and maintenance expense” on our Statements of Operations. To conform to the new presentation, reclassifications were made to the prior periods. Cost of sales includes costs incurred directly for the production and delivery of LNG from the Liquefaction Project such as natural gas feedstock, variable transportation and storage costs, derivative gains and losses associated with economic hedges to secure natural gas feedstock for the Liquefaction Project , and other costs related to converting natural gas into LNG, all to the extent not utilized for the commissioning process. These costs were reclassified from operating and maintenance expense. Operating and maintenance expense now includes costs associated with operating and maintaining the Liquefaction Project such as third-party service and maintenance contract costs, payroll and benefit costs of operations personnel, natural gas transportation and storage capacity demand charges, derivative gains and losses related to the sale and purchase of LNG associated with the regasification terminal, insurance and regulatory costs. Additionally, we renamed our “revenues” line item as “LNG revenues”, which include fees that are received pursuant to our SPAs and related LNG marketing activities.
Use of Estimates, Policy		Use of Estimates The preparation of Financial Statements in conformity with GAAP requires management to make certain estimates and assumptions that affect the amounts reported in the Financial Statements and the accompanying notes. Management evaluates its estimates and related assumptions regularly, including those related to the value of property, plant and equipment, collectability of accounts receivable, derivative instruments, asset retirement obligations (“AROs”) and fair value measurements. Changes in facts and circumstances or additional information may result in revised estimates, and actual results may differ from these estimates.
Fair Value, Policy		Fair Value Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants. Hierarchy Levels 1, 2 and 3 are terms for the priority of inputs to valuation techniques used to measure fair value. Hierarchy Level 1 inputs are quoted prices in active markets for identical assets or liabilities. Hierarchy Level 2 inputs are inputs other than quoted prices included within Level 1 that are directly or indirectly observable for the asset or liability. Hierarchy Level 3 inputs are inputs that are not observable in the market. In determining fair value, we use observable market data when available, or models that incorporate observable market data. In addition to market information, we incorporate transaction-specific details that, in management’s judgment, market participants would take into account in measuring fair value. We maximize the use of observable inputs and minimize our use of unobservable inputs in arriving at fair value estimates. Recurring fair-value measurements are performed for derivative instruments as disclosed in Note 7—Derivative Instruments . The carrying amount of cash and cash equivalents, restricted cash, accounts receivable and accounts payable reported on our Balance Sheets approximates fair value. The fair value of debt is the estimated amount we would have to pay to repurchase our debt in the open market, including any premium or discount attributable to the difference between the stated interest rate and market interest rate at each balance sheet date. Debt fair values, as disclosed in Note 10—Debt , are based on quoted market prices for identical instruments, if available, or based on valuations of similar debt instruments using observable or unobservable inputs. Non-financial assets and liabilities initially measured at fair value include intangible assets and AROs.
Revenue Recognition, Policy		Revenue Recognition Fees received pursuant to SPAs are recognized as LNG revenues after substantial completion of the respective Train. Prior to substantial completion, sales generated during the commissioning phase are offset against the cost of construction for the respective Train, as the production and removal of LNG from storage is necessary to test the facility and bring the asset to the condition necessary for its intended use. LNG revenues are recognized when LNG is delivered to the counterparty, either at the Sabine Pass LNG terminal or at the counterparty’s LNG receiving terminal, based on the terms of the contract.
Cash and Cash Equivalents, Policy		Cash and Cash Equivalents We consider all highly liquid investments with an original maturity of three months or less to be cash equivalents.
Restricted Cash, Policy		Restricted Cash Restricted cash consists of funds that are contractually restricted as to usage or withdrawal and have been presented separately from cash and cash equivalents on our Balance Sheets.
Accounts Receivable, Policy		Accounts Receivable Accounts receivable is reported net of allowances for doubtful accounts. Impaired receivables are specifically identified and evaluated for expected losses. The expected loss on impaired receivables is primarily determined based on the debtor’s ability to pay and the estimated value of any collateral. We did no t recognize any bad debt expense related to accounts receivable during the years ended December 31, 2016, 2015 and 2014 .
Inventory, Policy		Inventory LNG and natural gas inventory are recorded at weighted average cost and materials and other inventory are recorded at cost. Inventory is subject to lower of cost or market (“LCM”) adjustments at the end of each period. Recoveries of losses resulting from interim period LCM adjustments are recorded when market price recoveries occur on the same inventory in the same fiscal year. These recoveries are recognized as gains in later interim periods with such gains not exceeding previously recognized losses. Reimbursement to SPLNG for our portion of its fuel costs related to maintaining the cryogenic readiness of the Sabine Pass LNG terminal is recorded in terminal use agreement maintenance expense—affiliate. Inventory LNG and natural gas inventory are recorded at weighted average cost and materials and other inventory are recorded at cost. Inventory is subject to lower of cost or market (“LCM”) adjustments at the end of each period. Recoveries of losses resulting from interim period LCM adjustments are recorded when market price recoveries occur on the same inventory in the same fiscal year. These recoveries are recognized as gains in later interim periods with such gains not exceeding previously recognized losses. Reimbursement to SPLNG for our portion of its fuel costs related to maintaining the cryogenic readiness of the Sabine Pass LNG terminal is recorded in terminal use agreement maintenance expense—affiliate.
Accounting For LNG Activities, Policy		Accounting for LNG Activities Generally, we begin capitalizing the costs of a Train once it meets the following criteria: (1) regulatory approval has been received, (2) financing for the Train is available and (3) management has committed to commence construction. Prior to meeting these criteria, most of the costs associated with a Train are expensed as incurred. These costs primarily include professional fees associated with front-end engineering and design work, costs of securing necessary regulatory approvals and other preliminary investigation and development activities related to the Train. Generally, costs that are capitalized prior to a project meeting the criteria otherwise necessary for capitalization include: land and lease option costs that are capitalized as property, plant and equipment and certain permits that are capitalized as other non-current assets. The costs of lease options are amortized over the life of the lease once obtained. If no lease is obtained, the costs are expensed. We capitalize interest and other related debt costs during the construction period of a Train. Upon commencement of operations, capitalized interest, as a component of the total cost, is amortized over the estimated useful life of the asset.
Property, Plant and Equipment, Policy		Property, Plant and Equipment Property, plant and equipment are recorded at cost. Expenditures for construction and commissioning activities, major renewals and betterments that extend the useful life of an asset are capitalized, while expenditures for maintenance and repairs and general and administrative activities are charged to expense as incurred. Interest costs incurred on debt obtained for the construction of property, plant and equipment are capitalized as construction-in-process over the construction period or related debt term, whichever is shorter. We depreciate our property, plant and equipment using the straight-line depreciation method. Upon retirement or other disposition of property, plant and equipment, the cost and related accumulated depreciation are removed from the account, and the resulting gains or losses are recorded in other operating costs and expenses. Management tests property, plant and equipment for impairment whenever events or changes in circumstances have indicated that the carrying amount of property, plant and equipment might not be recoverable. Assets are grouped at the lowest level for which there are identifiable cash flows that are largely independent of the cash flows of other groups of assets for purposes of assessing recoverability. Recoverability generally is determined by comparing the carrying value of the asset to the expected undiscounted future cash flows of the asset. If the carrying value of the asset is not recoverable, the amount of impairment loss is measured as the excess, if any, of the carrying value of the asset over its estimated fair value. We recorded $0.4 million , zero and zero impairments related to property, plant and equipment during the years ended December 31, 2016, 2015 and 2014 , respectively.
Derivatives Instruments, Policy		Derivative Instruments We use derivative instruments to hedge our exposure to cash flow variability from interest rate and commodity price risk. Derivative instruments are recorded at fair value and included in our Balance Sheets as assets or liabilities depending on the derivative position and the expected timing of settlement, unless they satisfy criteria and we elect the normal purchases and sales exception. When we have the contractual right and intend to net settle, derivative assets and liabilities are reported on a net basis. Changes in the fair value of our derivative instruments are recorded in current earnings, unless we elect to apply hedge accounting and meet specified criteria, including completing contemporaneous hedge documentation. We did no t have any derivative instruments designated as cash flow hedges during the years ended December 31, 2016, 2015 and 2014 . See Note 7—Derivative Instruments for additional details about our derivative instruments.
Concentration of Credit Risk, Policy		Concentration of Credit Risk Financial instruments that potentially subject us to a concentration of credit risk consist principally of cash and cash equivalents and restricted cash. We maintain cash balances at financial institutions, which may at times be in excess of federally insured levels. We have not incurred losses related to these balances to date. The use of derivative instruments exposes us to counterparty credit risk, or the risk that a counterparty will be unable to meet its commitments. Our interest rate derivative instruments are placed with investment grade financial institutions whom we believe are acceptable credit risks. Our commodity derivative transactions are executed through over-the-counter contracts which are subject to nominal credit risk as these transactions are settled on a daily margin basis with investment grade financial institutions. Collateral deposited for such contracts is recorded as other current asset. We monitor counterparty creditworthiness on an ongoing basis; however, we cannot predict sudden changes in counterparties’ creditworthiness. In addition, even if such changes are not sudden, we may be limited in our ability to mitigate an increase in counterparty credit risk. Should one of these counterparties not perform, we may not realize the benefit of some of our derivative instruments. We have entered into six fixed price 20 -year SPAs with six unaffiliated third parties. We are dependent on the respective counterparties’ creditworthiness and their willingness to perform under their respective SPAs. During the year ended December 31, 2016 , we received 77% of our net LNG revenues from one SPA customer.
Debt, Policy		Debt Our debt consists of current and long-term secured debt securities and credit facilities with banks and other lenders. Debt issuances are placed directly by us or through securities dealers or underwriters and are held by institutional and retail investors. Debt is recorded on our Balance Sheets at par value adjusted for unamortized discount or premium. Discounts, premiums and debt issuance costs directly related to the issuance of debt are amortized over the life of the debt and are recorded in interest expense, net of capitalized interest using the effective interest method. Gains and losses on the extinguishment of debt are recorded in gains and losses on the extinguishment of debt on our Statements of Operations. Debt issuance costs consist primarily of arrangement fees, professional fees, legal fees and printing costs. These costs are recorded as a direct deduction from the debt liability unless incurred in connection with a line of credit arrangement, in which case they are presented as an asset on our Balance Sheet. Debt issuance costs are amortized to interest expense or property, plant and equipment over the term of the related debt facility. Upon early retirement of debt or amendment to a debt agreement, certain fees are written off to loss on early extinguishment of debt.
Asset Retirement Obligations, Policy		Asset Retirement Obligations We recognize AROs for legal obligations associated with the retirement of long-lived assets that result from the acquisition, construction, development and/or normal use of the asset and for conditional AROs in which the timing or method of settlement are conditional on a future event that may or may not be within our control. The fair value of a liability for an ARO is recognized in the period in which it is incurred, if a reasonable estimate of fair value can be made. The fair value of the liability is added to the carrying amount of the associated asset. This additional carrying amount is depreciated over the estimated useful life of the asset. Our assessment of AROs is described below. We have not recorded an ARO associated with the Sabine Pass LNG terminal. Based on the real property lease agreements at the Sabine Pass LNG terminal, at the expiration of the term of the leases we are required to surrender the LNG terminal in good working order and repair, with normal wear and tear and casualty expected. Our property lease agreements at the Sabine Pass LNG terminal have terms of up to 90 years including renewal options. We have determined that the cost to surrender the liquefaction facilities at the Sabine Pass LNG terminal in good order and repair, with normal wear and tear and casualty expected, is zero .
Income Taxes, Policy	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 Statements of Operations, is able to be included in the federal income tax return of Cheniere Partners, a publicly traded partnership which indirectly owns us. Accordingly, no provision or liability for federal or state income taxes is included in the accompanying Financial Statements.	Income Taxes 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 Statements of Operations, is able to be included in the federal income tax return of Cheniere Partners, a publicly traded partnership which indirectly owns us. Accordingly, no provision or liability for federal or state income taxes is included in the accompanying Financial Statements. At December 31, 2016 , the tax basis of our assets and liabilities was $268.0 million more than the reported amounts of our assets and liabilities. Pursuant to the indentures governing our debt, we are permitted to make distributions (“Tax Distributions”) for any fiscal year or portion thereof in which we are a limited partnership, disregarded entity or other substantially similar pass-through entity for federal and state income tax purposes. The Tax Distributions are equal to the tax that we would owe if we were a corporation subject to federal and state income tax that filed separate federal and state income tax returns, excluding the amounts covered by the state tax sharing agreement discussed in Note 11—Related Party Transactions . The Tax Distributions are limited to the amount of federal and/or state income taxes paid by Cheniere to the appropriate taxing authorities and are payable by us within 30 days of the date that Cheniere is required to make federal or state income tax payments to the appropriate taxing authorities.
Business Segment, Policy		Business Segment Our liquefaction operations at the Sabine Pass LNG terminal represent a single reportable segment. Our chief operating decision maker reviews the financial results of SPL in total when evaluating financial performance and for purposes of allocating resources.

Restricted Cash (Tables)

Restricted Cash (Tables)	3 Months Ended	12 Months Ended
	Mar. 31, 2017	Dec. 31, 2016
Cash and Cash Equivalents [Abstract]
Schedule of Restricted Cash	As of March 31, 2017 and December 31, 2016 , restricted cash consisted of the following (in millions): March 31, December 31, 2017 2016 Current restricted cash Liquefaction Project $ 531 $ 358 Non-current restricted cash Liquefaction Project 1,000 —	As of December 31, 2016 and 2015 , restricted cash consisted of the following (in thousands): December 31, 2016 2015 Current restricted cash Liquefaction Project $ 357,953 $ 189,260

Accounts and Other Receivables

Accounts and Other Receivables (Tables)	3 Months Ended	12 Months Ended
	Mar. 31, 2017	Dec. 31, 2016
Receivables [Abstract]
Schedule of Accounts and Other Receivables	As of March 31, 2017 and December 31, 2016 , accounts and other receivables consisted of the following (in millions): March 31, December 31, 2017 2016 Trade receivable $ 92 $ 88 Other accounts receivable 9 2 Total accounts and other receivables $ 101 $ 90	As of December 31, 2016 and 2015 , accounts and other receivables consisted of the following (in thousands): December 31, 2016 2015 Trade receivable $ 87,555 $ — Other accounts receivable 2,174 577 Total accounts and other receivables $ 89,729 $ 577

Inventory (Tables)

Inventory (Tables)	3 Months Ended	12 Months Ended
	Mar. 31, 2017	Dec. 31, 2016
Inventory Disclosure [Abstract]
Schedule of Inventory	As of March 31, 2017 and December 31, 2016 , inventory consisted of the following (in millions): March 31, December 31, 2017 2016 Natural gas $ 19 $ 15 LNG 21 45 Materials and other 38 29 Total inventory $ 78 $ 89	As of December 31, 2016 and 2015 , inventory consisted of the following (in thousands): December 31, 2016 2015 Natural gas $ 14,755 $ 5,724 LNG 45,008 — Materials and other 28,758 18 Total inventory $ 88,521 $ 5,742

Property, Plant and Equipment (

Property, Plant and Equipment (Tables)	3 Months Ended	12 Months Ended
	Mar. 31, 2017	Dec. 31, 2016
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	Property, plant and equipment, net consists of LNG terminal costs and fixed assets, as follows (in millions): March 31, December 31, 2017 2016 LNG terminal costs LNG terminal $ 7,696 $ 5,270 LNG terminal construction-in-process 4,789 6,675 Accumulated depreciation (121 ) (75 ) Total LNG terminal costs, net 12,364 11,870 Fixed assets Fixed assets 10 9 Accumulated depreciation (5 ) (4 ) Total fixed assets, net 5 5 Property, plant and equipment, net $ 12,369 $ 11,875	Property, plant and equipment consists of LNG terminal costs and fixed assets, as follows (in thousands): December 31, 2016 2015 LNG terminal costs LNG terminal $ 5,270,039 $ 42,220 LNG terminal construction-in-process 6,675,317 9,795,309 Accumulated depreciation (75,662 ) (789 ) Total LNG terminal costs, net 11,869,694 9,836,740 Fixed assets and other Furniture and fixtures 1,446 1,154 Computer software 4,373 3,782 Machinery and equipment 405 339 Vehicles 2,731 1,405 Other 714 390 Accumulated depreciation (4,520 ) (2,403 ) Total fixed assets and other, net 5,149 4,667 Property, plant and equipment, net $ 11,874,843 $ 9,841,407
Property Plant and Equipment, Estimated Useful Lives		The identifiable components of the Liquefaction Project with similar estimated useful lives have a depreciable range between 6 and 50 years, as follows: Components Useful life (yrs) Water pipelines 30 Liquefaction processing equipment 6-50 Other 15-30

Derivative Instruments (Tables)

Derivative Instruments (Tables)	3 Months Ended	12 Months Ended
	Mar. 31, 2017	Dec. 31, 2016
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Fair Value of Derivative Assets and Liabilities	The following table (in millions) 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, 2017 and December 31, 2016 , which are classified as other current assets , non-current derivative assets , derivative liabilities or non-current derivative liabilities in our Balance Sheets. Fair Value Measurements as of March 31, 2017 December 31, 2016 Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total Interest Rate Derivatives liability $ — $ — $ — $ — $ — $ (6 ) $ — $ (6 ) Liquefaction Supply Derivatives asset (liability) (2 ) — 41 39 (4 ) (2 ) 79 73	The following table (in thousands) shows the fair value of the derivative instruments that are required to be measured at fair value on a recurring basis as of December 31, 2016 and 2015 , which are classified as other current assets , non-current derivative assets , derivative liabilities or non-current derivative liabilities in our Balance Sheets. Fair Value Measurements as of December 31, 2016 December 31, 2015 Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total Interest Rate Derivatives liability $ — $ (6,224 ) $ — $ (6,224 ) $ — $ (8,740 ) $ — $ (8,740 ) Liquefaction Supply Derivatives asset (liability) (4,483 ) (1,474 ) 79,022 73,065 — (25 ) 32,492 32,467 Natural Gas Derivatives asset — — — — — 29 — 29
Fair Value Inputs, Assets, Quantitative Information	The following table includes quantitative information for the unobservable inputs for our Level 3 Physical Liquefaction Supply Derivatives as of March 31, 2017 : Net Fair Value Asset (in millions) Valuation Technique Significant Unobservable Input Significant Unobservable Inputs Range Physical Liquefaction Supply Derivatives $41 Income Approach Basis Spread $(0.345) - $0.081	The following table includes quantitative information for the unobservable inputs for our Level 3 Physical Liquefaction Supply Derivatives as of December 31, 2016 : Net Fair Value Asset (in thousands) Valuation Technique Significant Unobservable Input Significant Unobservable Inputs Range Physical Liquefaction Supply Derivatives $79,022 Income Approach Basis Spread $(0.260) - $(0.003)
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation	The following table (in millions) shows the changes in the fair value of our Level 3 Physical Liquefaction Supply Derivatives during the three months ended March 31, 2017 and 2016 : Three Months Ended March 31, 2017 2016 Balance, beginning of period $ 79 $ 32 Realized and mark-to-market losses: Included in cost of sales (1) (41 ) (2 ) Purchases and settlements: Purchases 4 — Settlements (1) (1 ) — Balance, end of period $ 41 $ 30 Change in unrealized gains relating to instruments still held at end of period $ (41 ) $ (2 ) (1) Does not include the decrease in fair value of $1 million related to the realized gains capitalized during the three months ended March 31, 2016	The following table (in thousands) shows the changes in the fair value of our Level 3 Physical Liquefaction Supply Derivatives during the years ended December 31, 2016 and 2015 : Year Ended December 31, 2016 2015 Balance, beginning of period $ 32,492 $ 342 Realized and mark-to-market gains: Included in cost of sales (1) 48,218 32,150 Purchases and settlements: Purchases 538 — Settlements (1) (2,226 ) — Transfers out of Level 3 — — Balance, end of period $ 79,022 $ 32,492 Change in unrealized gains relating to instruments still held at end of period $ 48,938 $ 32,150 (1) Does not include the decrease in fair value of $0.7 million related to the realized gains capitalized during the year ended December 31, 2016 .
Derivative Net Presentation on Balance Sheets	The following table (in millions) shows the fair value of our derivatives outstanding on a gross and net basis: Gross Amounts Recognized Gross Amounts Offset in the Balance Sheets Net Amounts Presented in the Balance Sheets Offsetting Derivative Assets (Liabilities) As of March 31, 2017 Liquefaction Supply Derivatives $ 48 $ (4 ) $ 44 Liquefaction Supply Derivatives 2 (7 ) (5 ) As of December 31, 2016 Interest Rate Derivatives $ (6 ) $ — $ (6 ) Liquefaction Supply Derivatives 82 (2 ) 80 Liquefaction Supply Derivatives (11 ) 4 (7 )	The following table (in thousands) shows the fair value of our derivatives outstanding on a gross and net basis: Gross Amounts Recognized Gross Amounts Offset in the Balance Sheets Net Amounts Presented in the Balance Sheets Offsetting Derivative Assets (Liabilities) As of December 31, 2016 Interest Rate Derivatives $ (6,229 ) $ 5 $ (6,224 ) Liquefaction Supply Derivatives 82,116 (1,793 ) 80,323 Liquefaction Supply Derivatives (11,078 ) 3,820 (7,258 ) As of December 31, 2015 Interest Rate Derivatives $ (8,740 ) $ — $ (8,740 ) Liquefaction Supply Derivatives 33,636 (595 ) 33,041 Liquefaction Supply Derivatives (574 ) — (574 ) Natural Gas Derivatives 152 (123 ) 29
Interest Rate Derivatives [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Schedule of Notional Amounts of Outstanding Derivative Positions		As of December 31, 2016 , we had the following Interest Rate Derivatives outstanding: Initial Notional Amount Maximum Notional Amount Effective Date Maturity Date Weighted Average Fixed Interest Rate Paid Variable Interest Rate Received Interest Rate Derivatives $20.0 million $628.8 million August 14, 2012 July 31, 2019 1.98% One-month LIBOR
Fair Value of Derivative Instruments by Balance Sheet Location	The following table (in millions) shows the fair value and location of our Interest Rate Derivatives on our Balance Sheets: Fair Value Measurements as of Balance Sheet Location March 31, 2017 December 31, 2016 Interest Rate Derivatives Derivative liabilities $ — $ (4 ) Interest Rate Derivatives Non-current derivative liabilities — (2 )	The following table (in thousands) shows the fair value and location of our Interest Rate Derivatives on our Balance Sheets: Fair Value Measurements as of Balance Sheet Location December 31, 2016 December 31, 2015 Interest Rate Derivatives Derivative liabilities $ (4,223 ) $ (5,940 ) Interest Rate Derivatives Non-current derivative liabilities (2,001 ) (2,800 )
Derivative Instruments, Gain (Loss)	The following table (in millions) shows the changes in the fair value and settlements of our Interest Rate Derivatives recorded in derivative loss, net on our Statements of Operations during the three months ended March 31, 2017 and 2016 : Three Months Ended March 31, 2017 2016 Interest Rate Derivatives loss $ (2 ) $ (11 )	The following table (in thousands) shows the changes in the fair value and settlements of our Interest Rate Derivatives recorded in derivative loss, net on our Statements of Operations during the years ended December 31, 2016, 2015 and 2014 : Year Ended December 31, 2016 2015 2014 Interest Rate Derivatives loss $ (5,934 ) $ (41,722 ) $ (119,401 )
Commodity Contract [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Fair Value of Derivative Instruments by Balance Sheet Location	The following table (in millions) shows the fair value and location of our Liquefaction Supply Derivatives on our Balance Sheets: Fair Value Measurements as of (1) Balance Sheet Location March 31, 2017 December 31, 2016 Liquefaction Supply Derivatives Other current assets $ 16 $ 13 Liquefaction Supply Derivatives Non-current derivative assets 28 67 Liquefaction Supply Derivatives Derivative liabilities (4 ) (7 ) Liquefaction Supply Derivatives Non-current derivative liabilities (1 ) — (1) Does not include collateral of $5 million and $6 million deposited for such contracts, which is included in other current assets in our Balance Sheets as of March 31, 2017 and December 31, 2016 , respectively.	The following table (in thousands) shows the fair value and location of our Commodity Derivatives on our Balance Sheets: December 31, 2016 December 31, 2015 Liquefaction Supply Derivatives (1) Natural Gas Derivatives Total Liquefaction Supply Derivatives Natural Gas Derivatives (2) Total Balance Sheet Location Other current assets $ 13,535 $ — $ 13,535 $ 2,737 $ 29 $ 2,766 Non-current derivative assets 66,788 — 66,788 30,304 — 30,304 Total derivative assets 80,323 — 80,323 33,041 29 33,070 Derivative liabilities (7,258 ) — (7,258 ) (490 ) — (490 ) Non-current derivative liabilities — — — (84 ) — (84 ) Total derivative liabilities (7,258 ) — (7,258 ) (574 ) — (574 ) Derivative asset, net $ 73,065 $ — $ 73,065 $ 32,467 $ 29 $ 32,496 (1) Does not include collateral of $6.0 million deposited for such contracts, which is included in other current assets in our Balance Sheet as of December 31, 2016 . (2) Does not include collateral of $0.4 million deposited for such contracts, which is included in other current assets in our Balance Sheet as of December 31, 2015 .
Derivative Instruments, Gain (Loss)	The following table (in millions) shows the changes in the fair value, settlements and location of our Liquefaction Supply Derivatives recorded on our Statements of Operations during the three months ended March 31, 2017 and 2016 : Three Months Ended March 31, Statement of Operations Location (1) 2017 2016 Liquefaction Supply Derivatives loss (2) Cost of sales $ 39 $ 4 (1) Fair value fluctuations associated with commodity derivative activities are classified and presented consistently with the item economically hedged and the nature and intent of the derivative instrument. (2) Does not include the realized value associated with derivative instruments that settle through physical delivery.	The following table (in thousands) shows the changes in the fair value, settlements and location of our Commodity Derivatives recorded on our Statements of Operations during the years ended December 31, 2016, 2015 and 2014 : Year Ended December 31, Statement of Operations Location (1) 2016 2015 2014 Liquefaction Supply Derivatives loss LNG revenues $ (8 ) $ — $ — Liquefaction Supply Derivatives gain (2) Cost (cost recovery) of sales (42,172 ) (32,503 ) (342 ) Natural Gas Derivatives gain Operating and maintenance expense (150 ) (1,842 ) (860 ) (1) Fair value fluctuations associated with commodity derivative activities are classified and presented consistently with the item economically hedged and the nature and intent of the derivative instrument. (2) Does not include the realized value associated with derivative instruments that settle through physical delivery.

Other Non-Current Assets (Table

Other Non-Current Assets (Tables)	3 Months Ended	12 Months Ended
	Mar. 31, 2017	Dec. 31, 2016
Other Assets, Noncurrent [Abstract]
Schedule of Other Non-Current Assets	As of March 31, 2017 and December 31, 2016 , other non-current assets consisted of the following (in millions): March 31, December 31, 2017 2016 Advances made under EPC and non-EPC contracts $ 20 $ 23 Advances made to municipalities for water system enhancements 95 95 Advances and other asset conveyances to third parties to support LNG terminals 30 31 Tax-related payments and receivables — 3 Information technology service assets 21 22 Other 2 11 Total other non-current assets, net $ 168 $ 185	As of December 31, 2016 and 2015 , other non-current assets consisted of the following (in thousands): December 31, 2016 2015 Advances made under EPC and non-EPC contracts $ 22,809 $ 32,049 Advances made to municipalities for water system enhancements 95,495 89,953 Advances and other asset conveyances to third parties to support LNG terminals 30,707 28,850 Tax-related payments and receivables 3,248 5,535 Information technology service assets 22,145 24,166 Other 10,939 14,265 Total other non-current assets, net $ 185,343 $ 194,818

Accrued Liabilities (Tables)

Accrued Liabilities (Tables)	3 Months Ended	12 Months Ended
	Mar. 31, 2017	Dec. 31, 2016
Accrued Liabilities, Current [Abstract]
Schedule of Accrued Liabilities	As of March 31, 2017 and December 31, 2016 , accrued liabilities consisted of the following (in millions): March 31, December 31, 2017 2016 Interest costs and related debt fees $ 147 $ 204 Liquefaction Project costs 259 203 Total accrued liabilities $ 406 $ 407	As of December 31, 2016 and 2015 , accrued liabilities consisted of the following (in thousands): December 31, 2016 2015 Interest costs and related debt fees $ 204,110 $ 135,336 Liquefaction Project costs 203,316 66,223 Other accrued liabilities 43 — Total accrued liabilities $ 407,469 $ 201,559

Debt (Tables)

Debt (Tables)	3 Months Ended	12 Months Ended
	Mar. 31, 2017	Dec. 31, 2016
Debt Disclosure [Abstract]
Schedule of Debt Instruments	As of March 31, 2017 and December 31, 2016 , our debt consisted of the following (in millions): March 31, December 31, 2017 2016 Long-term debt 5.625% Senior Secured Notes due 2021 (“2021 Senior Notes”), net of unamortized premium of $7 and $7 $ 2,007 $ 2,007 6.25% Senior Secured Notes due 2022 (“2022 Senior Notes”) 1,000 1,000 5.625% Senior Secured Notes due 2023 (“2023 Senior Notes”), net of unamortized premium of $5 and $6 1,505 1,506 5.75% Senior Secured Notes due 2024 (“2024 Senior Notes”) 2,000 2,000 5.625% Senior Secured Notes due 2025 (“2025 Senior Notes”) 2,000 2,000 5.875% Senior Secured Notes due 2026 (“2026 Senior Notes”) 1,500 1,500 5.00% Senior Secured Notes due 2027 (“2027 Senior Notes”) 1,500 1,500 4.200% Senior Secured Notes due 2028 (“2028 Senior Notes”), net of unamortized discount of $1 and zero 1,349 — 5.00% Senior Secured Notes due 2037 (“2037 Senior Notes”) 800 — 2015 Credit Facilities — 314 Unamortized debt issuance costs (201 ) (178 ) Total long-term debt, net 13,460 11,649 Current debt $1.2 billion Working Capital Facility (“Working Capital Facility”) — 224 Total debt, net $ 13,460 $ 11,873	As of December 31, 2016 and 2015 , our debt consisted of the following (in thousands): December 31, 2016 2015 Long-term debt 5.625% Senior Secured Notes due 2021 (“2021 Senior Notes”), net of unamortized premium of $7,181 and $8,718 $ 2,007,181 $ 2,008,718 6.25% Senior Secured Notes due 2022 (“2022 Senior Notes”) 1,000,000 1,000,000 5.625% Senior Secured Notes due 2023 (“2023 Senior Notes”), net of unamortized premium of $5,657 and $6,392 1,505,657 1,506,392 5.75% Senior Secured Notes due 2024 (“2024 Senior Notes”) 2,000,000 2,000,000 5.625% Senior Secured Notes due 2025 (“2025 Senior Notes”) 2,000,000 2,000,000 5.875% Senior Secured Notes due 2026 (“2026 Senior Notes”) 1,500,000 — 5.00% Senior Secured Notes due 2027 (“2027 Senior Notes”) 1,500,000 — 2015 Credit Facilities 314,000 845,000 Unamortized debt issuance costs (1) (177,609 ) (154,551 ) Total long-term debt, net 11,649,229 9,205,559 Current debt $1.2 billion Working Capital Facility (“Working Capital Facility”) 223,500 15,000 Total debt, net $ 11,872,729 $ 9,220,559 (1) Effective January 1, 2016, we adopted ASU 2015-03 and ASU 2015-15, which require debt issuance costs related to term notes to be presented in the balance sheet as a direct deduction from the debt liability, rather than as an asset, retrospectively for each reporting period presented. As a result, we reclassified $154.6 million from debt issuance costs, net to long-term debt, net as of December 31, 2015 .
Schedule of Maturities of Long-term Debt		Below is a schedule of future principal payments that we are obligated to make, based on current construction schedules, on our outstanding debt at December 31, 2016 (in thousands): Years Ending December 31, Principal Payments 2017 $ 223,500 2018 — 2019 — 2020 314,000 2021 2,000,000 Thereafter 9,500,000 Total $ 12,037,500
Schedule of Line of Credit Facilities	Below is a summary (in millions) of our Working Capital Facility as of March 31, 2017 : Working Capital Facility Original facility size $ 1,200 Outstanding balance — Letters of credit issued 377 Available commitment $ 823 Interest rate LIBOR plus 1.75% or base rate plus 0.75% Maturity date December 31, 2020, with various terms for underlying loans	Below is a summary of our credit facilities outstanding as of December 31, 2016 (in thousands): 2015 Credit Facilities Working Capital Facility Original facility size $ 4,600,000 $ 1,200,000 Outstanding balance 314,000 223,500 Commitments prepaid or terminated 2,643,867 — Letters of credit issued — 323,677 Available commitment $ 1,642,133 $ 652,823 Interest rate LIBOR plus 1.30% - 1.75% or base rate plus 1.75% LIBOR plus 1.75% or base rate plus 0.75% Maturity date Earlier of December 31, 2020 or second anniversary of Trains 1 through 5 completion date December 31, 2020, with various terms for underlying loans
Schedule of Interest Expense	Total interest expense consisted of the following (in millions): Three Months Ended March 31, 2017 2016 Total interest cost $ 186 $ 147 Capitalized interest (81 ) (141 ) Total interest expense, net $ 105 $ 6	Total interest expense consisted of the following (in thousands): Year Ended December 31, 2016 2015 2014 Total interest cost $ 648,915 $ 531,495 $ 397,949 Capitalized interest (463,090 ) (495,165 ) (374,040 ) Total interest expense, net $ 185,825 $ 36,330 $ 23,909
Schedule of Carrying Values and Estimated Fair Values of Debt Instruments	The following table (in millions) shows the carrying amount and estimated fair value of our debt: March 31, 2017 December 31, 2016 Carrying Amount Estimated Fair Value Carrying Amount Estimated Fair Value Senior notes, net of premium or discount (1) $ 12,861 $ 13,807 $ 11,513 $ 12,309 2037 Senior Notes (2) 800 826 — — Credit facilities (3) — — 538 538 (1) Includes 2021 Senior Notes , 2022 Senior Notes , 2023 Senior Notes , 2024 Senior Notes , 2025 Senior Notes , 2026 Senior Notes , 2027 Senior Notes and 2028 Senior Notes . The Level 2 estimated fair value was based on quotes obtained from broker-dealers or market makers of these senior notes and other similar instruments. (2) The Level 3 estimated fair value was calculated based on inputs that are observable in the market or that could be derived from, or corroborated with, observable market data, including our stock price and interest rates based on debt issued by parties with comparable credit ratings to us and inputs that are not observable in the market. (3) Includes 2015 Credit Facilities and Working Capital Facility . The Level 3 estimated fair value approximates the principal amount because the interest rates are variable and reflective of market rates and the debt may be repaid, in full or in part, at any time without penalty.	The following table (in thousands) shows the carrying amount and estimated fair value of our debt: December 31, 2016 December 31, 2015 Carrying Amount Estimated Fair Value Carrying Amount Estimated Fair Value Senior Notes, net of premium (1) $ 11,512,838 $ 12,308,736 $ 8,515,110 $ 7,469,718 Credit facilities (2) 537,500 537,500 860,000 860,000 (1) The Level 2 estimated fair value was based on quotes obtained from broker-dealers or market makers of the Senior Notes and other similar instruments. (2) Includes 2015 Credit Facilities and Working Capital Facility . The Level 3 estimated fair value approximates the principal amount because the interest rates are variable and reflective of market rates and the debt may be repaid, in full or in part, at any time without penalty.

Related Party Transactions (Tab

Related Party Transactions (Tables)	3 Months Ended	12 Months Ended
	Mar. 31, 2017	Dec. 31, 2016
Related Party Transactions [Abstract]
Schedule of Related Party Transactions	Below is a summary of our related party transactions as reported on our Statements of Operations for the three months ended March 31, 2017 and 2016 (in millions): Three Months Ended March 31, 2017 2016 LNG revenues—affiliate Cheniere Marketing SPA and Cheniere Marketing Master SPA $ 331 $ — Cost of sales—affiliate Cargo loading fees under the Terminal Use Rights Assignment and Agreement (the “TURA”) 4 — Operating and maintenance expense—affiliate TUA 33 — Natural Gas Transportation Agreement 16 — Services Agreements 10 1 Total operating and maintenance expense—affiliate 59 1 General and administrative expense—affiliate Services Agreements 17 17	Below is a summary of our related party transactions as reported on our Statements of Operations for the years ended December 31, 2016, 2015 and 2014 (in thousands): Year Ended December 31, 2016 2015 2014 LNG revenues—affiliate Cheniere Marketing SPA and Cheniere Marketing Master SPA $ 293,957 $ — $ — Cost of sales—affiliate Cargo loading fees under the Terminal Use Rights Assignment and Agreement (the “TURA”) 5,264 — — Fees under the Pre-commercial LNG Marketing Agreement 1,490 — — Total cost of sales—affiliate 6,754 — — Operating and maintenance expense—affiliate TUA 60,516 — — Natural Gas Transportation Agreement 44,656 — — Services Agreements 22,424 860 95 LNG Site Sublease Agreement 827 471 — Total operating and maintenance expense—affiliate 128,423 1,331 95 Terminal use agreement maintenance expense—affiliate TUA 208 400 387 Development expense—affiliate Services Agreements 396 722 1,153 LNG Site Sublease Agreement 115 — — Total development expense—affiliate 511 722 1,153 General and administrative expense—affiliate Services Agreements 68,070 87,425 70,553 LNG Site Sublease Agreement — 241 482 Other agreements — 15 30 Total general and administrative expense—affiliate 68,070 87,681 71,065
Schedule of Percentage of TUA Fees Payable	The following table shows the percentages of all TUA Fees payable to SPLNG by Cheniere Investments and us in accordance with the TURA : Period Percentage of TUA Fees Payable by Investments Percentage of TUA Fees Payable by SPL Prior to May 2016 (substantial completion of Train 1) 100% 0% May 2016 - September 2016 (substantial completion of Train 2) 75% 25% September 2016 - March 2017 (substantial completion of Train 3) 50% 50% March 2017 through substantial completion of Train 4 25% 75% After substantial completion of Train 4 0% 100%

Leases (Tables)

Leases (Tables)	12 Months Ended
	Dec. 31, 2016
Leases [Abstract]
Schedule of Future Minimum Rental Payments for Operating Leases	Future annual minimum lease payments, excluding inflationary adjustments and payments to affiliates, are as follows (in thousands): Years ending December 31, Operating Leases (1) 2017 $ 396 2018 396 2019 396 2020 396 2021 373 Thereafter 5,137 Total $ 7,094 (1) Includes certain lease option renewals that are reasonably assured .

Commitments and Contingencies (

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2016
Natural Gas Supply Transportation And Storage Service Agreements [Member]
Long-term Purchase Commitment [Line Items]
Contractual Obligation, Fiscal Year Maturity Schedule	As of December 31, 2016 , our obligations under natural gas supply, transportation and storage service agreements for contracts in which conditions precedent were met were as follows (in thousands): Years Ending December 31, Payments Due (1) 2017 $ 1,611,296 2018 1,192,791 2019 1,019,309 2020 1,055,497 2021 903,425 Thereafter 2,169,912 Total $ 7,952,230 (1) Pricing of natural gas supply contracts are variable based on market commodity basis prices adjusted for basis spread . Amounts included are based on prices and basis spreads as of December 31, 2016 .

Supplemental Cash Flow Inform37

Supplemental Cash Flow Information (Tables)	3 Months Ended	12 Months Ended
	Mar. 31, 2017	Dec. 31, 2016
Supplemental Cash Flow Information [Abstract]
Schedule of Cash Flow, Supplemental Disclosures	The following table (in millions) provides supplemental disclosure of cash flow information: Three Months Ended March 31, 2017 2016 Cash paid during the period for interest, net of amounts capitalized $ 154 $ 27 Non-cash distributions to affiliates for conveyance of assets — 253	The following table (in thousands) provides supplemental disclosure of cash flow information: Year Ended December 31, 2016 2015 2014 Cash paid during the period for interest, net of amounts capitalized $ 74,519 $ — $ — Non-cash distributions to affiliates for conveyance of assets 252,802 90,645 745 Other non-cash distribution to affiliates — 149 — Non-cash conveyance of assets to non-affiliate — 13,169 —

Recent Accounting Standards (Ta

Recent Accounting Standards (Tables)	3 Months Ended	12 Months Ended
	Mar. 31, 2017	Dec. 31, 2016
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
Recent Accounting Standards, Not Yet Adopted	The following table provides a brief description of recent accounting standards that had not been adopted by the Company as of March 31, 2017 : Standard Description Expected Date of Adoption Effect on our Financial Statements or Other Significant Matters ASU 2014-09, Revenue from Contracts with Customers (Topic 606) , and subsequent amendments thereto This standard provides a single, comprehensive revenue recognition model which replaces and supersedes most existing revenue recognition guidance and requires an entity to recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. The standard requires that the costs to obtain and fulfill contracts with customers should be recognized as assets and amortized to match the pattern of transfer of goods or services to the customer if expected to be recoverable. The standard also requires enhanced disclosures. This guidance may be adopted either retrospectively to each prior reporting period presented subject to allowable practical expedients (“full retrospective approach”) or as a cumulative-effect adjustment as of the date of adoption (“modified retrospective approach”). January 1, 2018 We continue to evaluate the effect of this standard on our Financial Statements. Preliminarily, we plan to adopt this standard using the full retrospective approach and we do not currently anticipate that the adoption will have a material impact upon our revenues. The Financial Accounting Standards Board has issued and may issue in the future amendments and interpretive guidance which may cause our evaluation to change. Furthermore, we routinely enter into new contracts and we cannot predict with certainty whether the accounting for any future contract under the new standard would result in a significant change from existing guidance. Because this assessment is preliminary and the accounting for revenue recognition is subject to significant judgment, this conclusion could change as we finalize our assessment. We have not yet determined the impact that recognizing fulfillment costs as assets will have on our Financial Statements. ASU 2016-02, Leases (Topic 842) This standard requires a lessee to recognize leases on its balance sheet by recording a lease liability representing the obligation to make future lease payments and a right-of-use asset representing the right to use the underlying asset for the lease term. A lessee is permitted to make an election not to recognize lease assets and liabilities for leases with a term of 12 months or less. The standard also modifies the definition of a lease and requires expanded disclosures. This guidance may be early adopted, and must be adopted using a modified retrospective approach with certain available practical expedients. January 1, 2019 We continue to evaluate the effect of this standard on our Financial Statements. Preliminarily, we expect that the requirement to recognize all leases on our Balance Sheets will be a significant change from current practice but will not have a material impact upon our Balance Sheets. Because this assessment is preliminary and the accounting for leases is subject to significant judgment, this conclusion could change as we finalize our assessment. We have not yet determined the impact of the adoption of this standard upon our results of operations or cash flows, whether we will elect to early adopt this standard or which, if any, practical expedients we will elect upon transition. ASU 2016-16, Income Taxes (Topic 740): Intra-Entity Transfers of Assets Other Than Inventory This standard requires the immediate recognition of the tax consequences of intercompany asset transfers other than inventory. This guidance may be early adopted, but only at the beginning of an annual period, and must be adopted using a modified retrospective approach. January 1, 2018 We are currently evaluating the impact of the provisions of this guidance on our Financial Statements and related disclosures.	The following table provides a brief description of recent accounting standards that had not been adopted by the Company as of December 31, 2016 : Standard Description Expected Date of Adoption Effect on our Financial Statements or Other Significant Matters ASU 2014-09, Revenue from Contracts with Customers (Topic 606) , and subsequent amendments thereto This standard provides a single, comprehensive revenue recognition model which replaces and supersedes most existing revenue recognition guidance and requires an entity to recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. The standard requires that the costs to obtain and fulfill contracts with customers should be recognized as assets and amortized to match the pattern of transfer of goods or services to the customer if expected to be recoverable. The standard also requires enhanced disclosures. This guidance may be adopted either retrospectively to each prior reporting period presented subject to allowable practical expedients (“full retrospective approach”) or as a cumulative-effect adjustment as of the date of adoption (“modified retrospective approach”). January 1, 2018 We continue to evaluate the effect of this standard on our Financial Statements. Preliminarily, we plan to adopt this standard using the full retrospective approach and we do not currently anticipate that the adoption will have a material impact upon our revenues. The FASB has issued and may issue in the future amendments and interpretive guidance which may cause our evaluation to change. Furthermore, we routinely enter into new contracts and we cannot predict with certainty whether the accounting for any future contract under the new standard would result in a significant change from existing guidance. Because this assessment is preliminary and the accounting for revenue recognition is subject to significant judgment, this conclusion could change as we finalize our assessment. We have not yet determined the impact that recognizing fulfillment costs as assets will have on our Financial Statements. ASU 2015-11, Inventory (Topic 330): Simplifying the Measurement of Inventory This standard requires inventory to be measured at the lower of cost and net realizable value. Net realizable value is the estimated selling prices in the ordinary course of business, less reasonably predictable costs of completion, disposal and transportation. This guidance may be early adopted and must be adopted prospectively. January 1, 2017 The adoption of this guidance will not have a material impact on our Financial Statements or related disclosures. ASU 2016-02, Leases (Topic 842) This standard requires a lessee to recognize leases on its balance sheet by recording a lease liability representing the obligation to make future lease payments and a right-of-use asset representing the right to use the underlying asset for the lease term. A lessee is permitted to make an election not to recognize lease assets and liabilities for leases with a term of 12 months or less. The standard also modifies the definition of a lease and requires expanded disclosures. This guidance may be early adopted, and must be adopted using a modified retrospective approach with certain available practical expedients. January 1, 2019 We continue to evaluate the effect of this standard on our Financial Statements. Preliminarily, we expect that the requirement to recognize all leases will be a significant change from current practice but will not have a material impact upon our Balance Sheets. Because this assessment is preliminary and the accounting for leases is subject to significant judgment, this conclusion could change as we finalize our assessment. We have not yet determined the impact of the adoption of this standard upon our results of operations or cash flows, whether we will elect to early adopt this standard or which, if any, practical expedients we will elect upon transition. Standard Description Expected Date of Adoption Effect on our Financial Statements or Other Significant Matters ASU 2016-16, Income Taxes (Topic 740): Intra-Entity Transfers of Assets Other Than Inventory This standard requires the immediate recognition of the tax consequences of intercompany asset transfers other than inventory. This guidance may be early adopted, but only at the beginning of an annual period, and must be adopted using a modified retrospective approach. January 1, 2018 We are currently evaluating the impact of the provisions of this guidance on our Financial Statements and related disclosures.
Recent Accounting Standards, Adopted	Additionally, the following table provides a brief description of a recent accounting standard that was adopted by the Company during the reporting period: Standard Description Date of Adoption Effect on our Financial Statements or Other Significant Matters ASU 2015-11, Inventory (Topic 330): Simplifying the Measurement of Inventory This standard requires inventory to be measured at the lower of cost and net realizable value. Net realizable value is the estimated selling prices in the ordinary course of business, less reasonably predictable costs of completion, disposal and transportation. This guidance may be early adopted and must be adopted prospectively. January 1, 2017 The adoption of this guidance did not have a material impact on our Financial Statements or related disclosures.	Additionally, the following table provides a brief description of recent accounting standards that were adopted by the Company during the reporting period: Standard Description Date of Adoption Effect on our Financial Statements or Other Significant Matters ASU 2015-03, Interest - Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs and ASU 2015-15, Presentation and Subsequent Measurement of Debt Issuance Costs Associated with Line-of-Credit Arrangements These standards require debt issuance costs related to a recognized debt liability to be presented in the balance sheet as a direct deduction from the debt liability rather than as an asset. Debt issuance costs incurred in connection with line of credit arrangements may be presented as an asset and subsequently amortized ratably over the term of the line of credit arrangement. This guidance may be early adopted, and must be adopted retrospectively to each prior reporting period presented. January 1, 2016 Upon adoption of these standards, the balance of debt, net was reduced by the balance of debt issuance costs, net, except for the balance related to line of credit arrangements, on our Balance Sheets. See Note 10—Debt for additional disclosures. ASU 2014-15, Presentation of Financial Statements-Going Concern (Subtopic 205-40): Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern This standard requires an entity’s management to evaluate, for each reporting period, whether there are conditions and events that raise substantial doubt about the entity’s ability to continue as a going concern within one year after the financial statements are issued. Additional disclosures are required if management concludes that conditions or events raise substantial doubt about the entity’s ability to continue as a going concern. Early adoption is permitted. December 31, 2016 The adoption of this guidance did not have an impact on our Financial Statements or related disclosures. ASU 2016-18, Statement of Cash Flows (Topic 230): Restricted Cash (a consensus of the FASB Emerging Issues Task Force) This standard requires an entity to show the changes in the total of cash, cash equivalents, restricted cash and restricted cash equivalents in the statement of cash flows. This guidance may be early adopted, and must be adopted retrospectively to each prior reporting period presented. December 31, 2016 As a result of adopting this standard, our Statements of Cash Flows now reconciles the balance of total cash, cash equivalents and restricted cash from the beginning of the period to the end of the period. This resulted in changes to previously reported cash flows from operating, investing and financing activities. Standard Description Date of Adoption Effect on our Financial Statements or Other Significant Matters ASU 2017-01, Business Combinations (Topic 805): Clarifying the Definition of a Business This standard narrows the accounting definition of a business and clarifies that when substantially all of the fair value of an integrated set of assets and activities is concentrated in a single asset or a group of similar assets, the integrated set of assets and activities is not a business. The definition of a business affects many areas of accounting including acquisitions, disposals, goodwill and consolidation. This guidance may be early adopted and must be adopted prospectively. December 31, 2016 The adoption of this guidance did not have an impact on our Financial Statements or related disclosures.

Summarized Quarterly Financia39

Summarized Quarterly Financial Data (unaudited) (Tables)	12 Months Ended
	Dec. 31, 2016
Quarterly Financial Information Disclosure [Abstract]
Schedule of Quarterly Financial Information	Summarized Quarterly Financial Data—(in thousands) First Quarter Second Quarter Third Quarter Fourth Quarter Year ended December 31, 2016: Revenues $ 28 $ 85,326 $ 264,424 $ 483,633 Income (loss) from operations (30,061 ) (28,521 ) (15,375 ) 123,804 Net income (loss) (47,241 ) (86,690 ) (104,343 ) 44,809 Year ended December 31, 2015: Revenues $ — $ — $ — $ — Loss from operations (37,089 ) (29,532 ) (9,891 ) (15,120 ) Net loss (169,549 ) (48,101 ) (12,835 ) (35,132 )

Organization and Nature of Op40

Organization and Nature of Operations (Details)	3 Months Ended	12 Months Ended
	Mar. 31, 2017trains	Dec. 31, 2016itemmilliontonnes / yrbcf / dBcfetrainsm³
Organization and Nature of Operations [Line Items]
Limited Liability Company Number Of Members		1
Sabine Pass LNG Terminal [Member]
Organization and Nature of Operations [Line Items]
Number Of LNG Storage Tanks		5
Storage Capacity | Bcfe		16.9
Number Of Marine Berths		2
Volume Of Vessel | m³		266,000
Regasification Capacity | bcf / d		4
Number of Liquefaction LNG Trains | trains	6	6
Train Nominal Capacity | milliontonnes / yr		4.5
Cheniere Holdings [Member] | Cheniere Energy Partners, LP [Member]
Organization and Nature of Operations [Line Items]
Limited Partners ownership percentage		55.90%
Cheniere [Member] | Cheniere Holdings [Member]
Organization and Nature of Operations [Line Items]
Noncontrolling Interest, Ownership Percentage by Parent		82.60%

Nature of Operations and Basi41

Nature of Operations and Basis of Presentation (Details)	3 Months Ended	12 Months Ended
	Mar. 31, 2017USD ($)customertrains	Dec. 31, 2016USD ($)customertrains
Nature of Operations and Basis of Presentation [Line Items]
Income Tax Expense (Benefit) | $	$ 0	$ 0
Customer Concentration Risk [Member] | LNG Revenues [Member]
Nature of Operations and Basis of Presentation [Line Items]
Concentration Risk, Percentage	94.00%	77.00%
Customer Concentration Risk [Member] | LNG Revenues [Member] | SPA Customers [Member]
Nature of Operations and Basis of Presentation [Line Items]
Concentration Risk, Number Of Significant Customers | customer	2	1
Sabine Pass LNG Terminal [Member]
Nature of Operations and Basis of Presentation [Line Items]
Number of Liquefaction LNG Trains | trains	6	6

Summary of Significant Accoun42

Summary of Significant Accounting Policies (Details)	3 Months Ended	12 Months Ended
	Mar. 31, 2017USD ($)customer	Dec. 31, 2016USD ($)customeritem	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)
Basis of Presentation and Summary of Significant Accounting Policies [Line Items]
Bad debt expense		$ 0	$ 0	$ 0
Impairments related to property, plant and equipment		400,000	0	0
Derivative instruments designated as cash flow hedges		0	$ 0	$ 0
Income Tax Expense (Benefit)	$ 0	0
Taxes, Difference in Bases, Amount		$ 268,000,000
Payment terms for amount payable to affiliate for taxes paid on our behalf		30 days
Sabine Pass LNG Terminal [Member]
Basis of Presentation and Summary of Significant Accounting Policies [Line Items]
Asset Retirement Obligation		$ 0
Customer Concentration Risk [Member] | SPA Customers [Member]
Basis of Presentation and Summary of Significant Accounting Policies [Line Items]
Number Of Fixed Price Contracts | item		6
Sale And Purchase Agreement Term Of Agreement		20 years
Sale And Purchase Agreement Number Of Unaffiliated Counterparties | customer		6
Customer Concentration Risk [Member] | LNG Revenues [Member]
Basis of Presentation and Summary of Significant Accounting Policies [Line Items]
Concentration Risk, Percentage	94.00%	77.00%
Customer Concentration Risk [Member] | LNG Revenues [Member] | SPA Customers [Member]
Basis of Presentation and Summary of Significant Accounting Policies [Line Items]
Concentration Risk, Number Of Significant Customers | customer	2	1
Maximum [Member] | Sabine Pass LNG Terminal [Member]
Basis of Presentation and Summary of Significant Accounting Policies [Line Items]
Property Lease Term		90 years

Restricted Cash (Details)

Restricted Cash (Details) - USD ($) $ in Thousands	Mar. 31, 2017	Dec. 31, 2016	Mar. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Restricted Cash and Cash Equivalents Items [Line Items]
Current restricted cash	$ 531,000	$ 357,953	$ 178,000	$ 189,260	$ 155,810
Non-current restricted cash	1,000,000	0	$ 0	0	$ 457,053
Liquefaction Project [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Current restricted cash	531,000	357,953		$ 189,260
Non-current restricted cash	$ 1,000,000	$ 0

Accounts and Other Receivable44

Accounts and Other Receivables (Details) $ in Thousands	3 Months Ended	12 Months Ended
	Mar. 31, 2017USD ($)customer	Dec. 31, 2016USD ($)customer	Dec. 31, 2015USD ($)
Accounts and Other Receivables [Line Items]
Trade receivable	$ 92,000	$ 87,555	$ 0
Other accounts receivable	9,000	2,174	577
Total accounts and other receivables	$ 101,000	$ 89,729	$ 577
Customer Concentration Risk [Member] | Accounts Receivable [Member]
Accounts and Other Receivables [Line Items]
Concentration Risk, Percentage		99.00%
Customer Concentration Risk [Member] | SPA Customers [Member] | Accounts Receivable [Member]
Accounts and Other Receivables [Line Items]
Concentration Risk, Number Of Significant Customers | customer	2	2

Inventory (Details)

Inventory (Details) - USD ($) $ in Thousands	Mar. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Inventory [Line Items]
Inventory	$ 78,000	$ 88,521	$ 5,742
Natural gas [Member]
Inventory [Line Items]
Inventory	19,000	14,755	5,724
LNG [Member]
Inventory [Line Items]
Inventory	21,000	45,008	0
Materials and other [Member]
Inventory [Line Items]
Inventory	$ 38,000	$ 28,758	$ 18

Property, Plant and Equipment -

Property, Plant and Equipment - Schedule of Property Plant and Equipment (Details) - USD ($) $ in Thousands	3 Months Ended		12 Months Ended
	Mar. 31, 2017	Mar. 31, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Property, Plant and Equipment [Line Items]
Property, plant and equipment, net	$ 12,369,000		$ 11,874,843	$ 9,841,407
Depreciation expense	45,000	$ 1,000	76,800	1,900	$ 1,000
Property, plant and equipment, reduction for testing costs recovered	124,000	$ 14,000	201,000
LNG terminal costs [Member]
Property, Plant and Equipment [Line Items]
Accumulated depreciation	(121,000)		(75,662)	(789)
Property, plant and equipment, net	12,364,000		11,869,694	9,836,740
LNG terminal [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	7,696,000		5,270,039	42,220
LNG terminal construction-in-process [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	4,789,000		6,675,317	9,795,309
Fixed assets [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	10,000		9,000
Accumulated depreciation	(5,000)		(4,520)	(2,403)
Property, plant and equipment, net	$ 5,000		5,149	4,667
Furniture and fixtures [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross			1,446	1,154
Computer software
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross			4,373	3,782
Machinery and equipment [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross			405	339
Vehicles [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross			2,731	1,405
Other
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross			$ 714	$ 390

Property, Plant and Equipment47

Property, Plant and Equipment - Estimated Useful Lives (Details)	12 Months Ended
	Dec. 31, 2016
LNG terminal costs [Member] | Minimum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	6 years
LNG terminal costs [Member] | Maximum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	50 years
Water pipelines [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	30 years
Liquefaction processing equipment [Member] | Minimum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	6 years
Liquefaction processing equipment [Member] | Maximum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	50 years
Other [Member] | Minimum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	15 years
Other [Member] | Maximum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	30 years

Derivative Instruments - Narrat

Derivative Instruments - Narrative (Details) MMBTU in Millions, $ in Millions	1 Months Ended		12 Months Ended
	Mar. 31, 2017USD ($)MMBTU	Mar. 31, 2015USD ($)	Dec. 31, 2016MMBTU
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Energy Units Secured Through Long-Term Supply Contracts	2,051		1,993.9
Previous Credit Facilities [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Line of Credit Facility, Decrease | $		$ 1,800
2015 Credit Facilities [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Line of Credit Facility, Decrease | $	$ 1,600
Interest Rate Derivatives [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Loss, Net | $	$ 7	$ 34.7
Liquefaction Supply Derivatives [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, Notional Amount	1,214		1,117
Physical Liquefaction Supply Derivatives [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, Notional Amount			1,111.4
Financial Liquefaction Supply Derivatives [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, Notional Amount			5.6
Minimum [Member] | Physical Liquefaction Supply Derivatives [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, Term of Contract			1 year
Maximum [Member] | Physical Liquefaction Supply Derivatives [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, Term of Contract			7 years

Derivative Instruments - Fair V

Derivative Instruments - Fair Value of Derivative Assets and Liabilities (Details) - USD ($) $ in Thousands	Mar. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Interest Rate Derivatives [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	$ 0	$ (6,224)	$ (8,740)
Interest Rate Derivatives [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	0	0	0
Interest Rate Derivatives [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	0	(6,224)	(8,740)
Interest Rate Derivatives [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	0	0	0
Liquefaction Supply Derivatives [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	39,000	73,065	32,467
Liquefaction Supply Derivatives [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	(2,000)	(4,483)	0
Liquefaction Supply Derivatives [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	0	(1,474)	(25)
Liquefaction Supply Derivatives [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	$ 41,000	79,022	32,492
Natural Gas Derivative [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net		0	29
Natural Gas Derivative [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net		0	0
Natural Gas Derivative [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net		0	29
Natural Gas Derivative [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net		$ 0	$ 0

Derivative Instruments - Fair50

Derivative Instruments - Fair Value Inputs - Quantitative Information (Details) - Physical Liquefaction Supply Derivatives [Member] - Fair Value, Inputs, Level 3 [Member] - USD ($)	3 Months Ended	12 Months Ended
	Mar. 31, 2017	Dec. 31, 2016
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	$ 41,000,000	$ 79,022,000
Valuation Technique	Income Approach	Income Approach
Significant Unobservable Input	Basis Spread	Basis Spread
Minimum [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Significant Unobservable Input Range	$ (0.345)	$ (0.260)
Maximum [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Significant Unobservable Input Range	$ 0.081	$ (0.003)

Derivative Instruments - Schedu

Derivative Instruments - Schedule of Level 3 Activity (Details) - Physical Liquefaction Supply Derivatives [Member] - USD ($) $ in Thousands	3 Months Ended			12 Months Ended
	Mar. 31, 2017	Mar. 31, 2016		Dec. 31, 2016	Dec. 31, 2015
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Balance, beginning of period	$ 79,022	$ 32,492		$ 32,492	$ 342
Realized and mark-to-market gains:
Included in cost of sales	(41,000)	(2,000)	[1]	48,218	32,150
Purchases and settlements:
Purchases	4,000	0		538	0
Settlements	(1,000)	0	[1]	(2,226)	0
Transfers out of Level 3				0	0
Balance, end of period	41,000	30,000		79,022	32,492
Change in unrealized gains relating to instruments still held at end of period	$ (41,000)	(2,000)		48,938	$ 32,150
Decrease in Fair Value Realized and Capitalized During Period		$ 1,000		$ 700
[1]	Does not include the decrease in fair value of $1 million related to the realized gains capitalized during the three months ended March 31, 2016

Derivative Instruments - Sche52

Derivative Instruments - Schedule of Notional Amounts of Outstanding Derivative Positions (Details) - Interest Rate Derivatives [Member] $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)
Derivative [Line Items]
Notional Amount	$ 20
Inception Date	Aug. 14, 2012
Maturity Date	Jul. 31, 2019
Weighted Average Fixed Interest Rate Paid	1.98%
Variable Interest Rate Received	One-month LIBOR
Maximum [Member]
Derivative [Line Items]
Notional Amount	$ 628.8

Derivative Instruments - Fair53

Derivative Instruments - Fair Value of Derivative Instruments by Balance Sheet Location (Details) - USD ($) $ in Thousands	Mar. 31, 2017		Dec. 31, 2016		Dec. 31, 2015
Derivatives, Fair Value [Line Items]
Non-current derivative assets	$ 28,000		$ 66,788		$ 30,304
Derivative liabilities	(4,000)		(11,481)		(6,430)
Non-current derivative liabilities	(1,000)		(2,001)		(2,884)
Interest Rate Derivatives [Member] | Derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities	0		(4,223)		(5,940)
Interest Rate Derivatives [Member] | Non-current derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative liabilities	0		(2,001)		(2,800)
Commodity Contract [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset			80,323		33,070
Derivative Liability			(7,258)		(574)
Derivative, Fair Value, Net			73,065		32,496
Commodity Contract [Member] | Other current assets [Member]
Derivatives, Fair Value [Line Items]
Other current assets			13,535		2,766
Commodity Contract [Member] | Non-current derivative assets [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative assets			66,788		30,304
Commodity Contract [Member] | Derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities			(7,258)		(490)
Commodity Contract [Member] | Non-current derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative liabilities			0		(84)
Liquefaction Supply Derivatives [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset			80,323	[1]	33,041
Derivative Liability			(7,258)	[1]	(574)
Derivative, Fair Value, Net			73,065		32,467
Liquefaction Supply Derivatives [Member] | Other current assets [Member]
Derivatives, Fair Value [Line Items]
Other current assets	16,000	[1]	13,535		2,737
Derivative, Collateral, Right to Reclaim Cash	5,000		6,000
Liquefaction Supply Derivatives [Member] | Non-current derivative assets [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative assets	28,000	[1]	66,788		30,304
Liquefaction Supply Derivatives [Member] | Derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities	(4,000)	[1]	(7,258)		(490)
Liquefaction Supply Derivatives [Member] | Non-current derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative liabilities	$ (1,000)	[1]	0		(84)
Natural Gas Derivative [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset			0		29	[2]
Derivative Liability			0		0	[2]
Derivative, Fair Value, Net			0		29	[2]
Natural Gas Derivative [Member] | Other current assets [Member]
Derivatives, Fair Value [Line Items]
Other current assets			0		29
Derivative, Collateral, Right to Reclaim Cash					400
Natural Gas Derivative [Member] | Non-current derivative assets [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative assets			0		0
Natural Gas Derivative [Member] | Derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities			0		0
Natural Gas Derivative [Member] | Non-current derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative liabilities			$ 0		$ 0
[1]	Does not include collateral of $5 million and $6 million deposited for such contracts, which is included in other current assets in our Balance Sheets as of March 31, 2017 and December 31, 2016, respectively.
[2]	Does not include collateral of $0.4 million deposited for such contracts, which is included in other current assets in our Balance Sheet as of December 31, 2015.

Derivative Instruments - Deriva

Derivative Instruments - Derivative Gain (Loss) (Details) - USD ($) $ in Thousands	1 Months Ended		3 Months Ended				12 Months Ended
	Mar. 31, 2017	Mar. 31, 2015	Mar. 31, 2017		Mar. 31, 2016		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Interest Rate Derivatives [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative gain (loss), net	$ (7,000)	$ (34,700)
Interest Rate Derivatives [Member] | Derivative gain (loss), net [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative gain (loss), net			$ (2,000)		$ (11,000)		$ (5,934)	$ (41,722)	$ (119,401)
Liquefaction Supply Derivatives [Member] | LNG revenues [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative gain (loss), net							(8)	0	0
Liquefaction Supply Derivatives [Member] | Cost (cost recovery) of sales [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative gain (loss), net			$ (39,000)	[1]	$ (4,000)	[1]	42,172	32,503	342
Natural Gas Derivative [Member] | Operating and maintenance expense [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative gain (loss), net							$ 150	$ 1,842	$ 860
[1]	Does not include the realized value associated with derivative instruments that settle through physical delivery.

Derivative Instruments - Deri55

Derivative Instruments - Derivative Net Presentation on Balance Sheets (Details) - USD ($) $ in Thousands	Mar. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Interest Rate Derivative Liability [Member]
Derivative [Line Items]
Derivative Liability, Gross Amounts Recognized		$ (6,229)	$ (8,740)
Derivative Liability, Gross Amounts Offset in the Balance Sheets		5	0
Net Amounts Presented in our Balance Sheets		(6,224)	(8,740)
Liquefaction Supply Derivatives Asset [Member]
Derivative [Line Items]
Derivative Asset, Gross Amounts Recognized	$ 48,000	82,116	33,636
Derivative Asset, Gross Amounts Offset in the Balance Sheets	(4,000)	(1,793)	(595)
Net Amounts Presented in our Balance Sheets	44,000	80,323	33,041
Liquefaction Supply Derivatives Liability [Member]
Derivative [Line Items]
Derivative Liability, Gross Amounts Recognized	2,000	(11,078)	(574)
Derivative Liability, Gross Amounts Offset in the Balance Sheets	(7,000)	3,820	0
Net Amounts Presented in our Balance Sheets	$ (5,000)	$ (7,258)	(574)
Natural Gas Derivative Asset [Member]
Derivative [Line Items]
Derivative Asset, Gross Amounts Recognized			152
Derivative Asset, Gross Amounts Offset in the Balance Sheets			(123)
Net Amounts Presented in our Balance Sheets			$ 29

Other Non-Current Assets (Detai

Other Non-Current Assets (Details) - USD ($) $ in Thousands	Mar. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Other Assets, Noncurrent [Abstract]
Advances made under EPC and non-EPC contracts	$ 20,000	$ 22,809	$ 32,049
Advances made to municipalities for water system enhancements	95,000	95,495	89,953
Advances and other asset conveyances to third parties to support LNG terminals	30,000	30,707	28,850
Tax-related payments and receivables	0	3,248	5,535
Information technology service assets	21,000	22,145	24,166
Other	2,000	10,939	14,265
Other non-current assets, net	$ 168,000	$ 185,343	$ 194,818

Accrued Liabilities (Details)

Accrued Liabilities (Details) - USD ($) $ in Thousands	Mar. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Accrued Liabilities, Current [Abstract]
Interest costs and related debt fees	$ 147,000	$ 204,110	$ 135,336
Liquefaction Project costs	259,000	203,316	66,223
Other accrued liabilities		43	0
Total accrued liabilities	$ 406,000	$ 407,469	$ 201,559

Debt - Schedule of Debt Instrum

Debt - Schedule of Debt Instruments (Details) - USD ($)	Mar. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Long-term Debt, Net	$ 13,460,000,000	$ 11,649,229,000	$ 9,205,559,000
Unamortized Debt Issuance Costs, Noncurrent	(201,000,000)	(177,609,000)	(154,551,000)
Current Debt, Working Capital Facility	0	223,500,000	15,000,000
Total Debt, Net	13,460,000,000	11,872,729,000	9,220,559,000
2021 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Net	$ 2,007,000,000	$ 2,007,181,000	2,008,718,000
Debt Instrument, Interest Rate, Stated Percentage	5.625%	5.625%
Debt Instrument, Unamortized Premium	$ 7,000,000	$ 7,181,000	8,718,000
2022 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Net	$ 1,000,000,000	$ 1,000,000,000	1,000,000,000
Debt Instrument, Interest Rate, Stated Percentage	6.25%	6.25%
2023 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Net	$ 1,505,000,000	$ 1,505,657,000	1,506,392,000
Debt Instrument, Interest Rate, Stated Percentage	5.625%	5.625%
Debt Instrument, Unamortized Premium	$ 5,000,000	$ 5,657,000	6,392,000
2024 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Net	$ 2,000,000,000	$ 2,000,000,000	2,000,000,000
Debt Instrument, Interest Rate, Stated Percentage	5.75%	5.75%
2025 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Net	$ 2,000,000,000	$ 2,000,000,000	2,000,000,000
Debt Instrument, Interest Rate, Stated Percentage	5.625%	5.625%
2026 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Net	$ 1,500,000,000	$ 1,500,000,000	0
Debt Instrument, Interest Rate, Stated Percentage	5.875%	5.875%
2027 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Net	$ 1,500,000,000	$ 1,500,000,000	0
Debt Instrument, Interest Rate, Stated Percentage	5.00%	5.00%
2028 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Net	$ 1,349,000,000	$ 0
Debt Instrument, Interest Rate, Stated Percentage	4.20%
Debt Instrument, Unamortized Discount	$ 1,000,000	0
2037 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Net	$ 800,000,000	0
Debt Instrument, Interest Rate, Stated Percentage	5.00%
2015 Credit Facilities [Member]
Debt Instrument [Line Items]
Long-term Debt, Net	$ 0	314,000,000	845,000,000
Working Capital Facility [Member]
Debt Instrument [Line Items]
Current Debt, Working Capital Facility	0	223,500,000	15,000,000
Line of Credit Facility, Maximum Borrowing Capacity	$ 1,200,000,000	$ 1,200,000,000
Accounting Standards Update 2015-03 [Member] | Long-term Debt [Member]
Debt Instrument [Line Items]
Unamortized Debt Issuance Costs, Noncurrent			154,551,000
Accounting Standards Update 2015-03 [Member] | Debt Issuance Costs, Net [Member]
Debt Instrument [Line Items]
Unamortized Debt Issuance Costs, Noncurrent			$ (154,551,000)

Debt - Schedule of Maturities (

Debt - Schedule of Maturities (Details) $ in Thousands	Dec. 31, 2016USD ($)
Debt Disclosure [Abstract]
2,017	$ 223,500
2,018	0
2,019	0
2,020	314,000
2,021	2,000,000
Thereafter	9,500,000
Total	$ 12,037,500

Debt - Senior Notes (Details)

Debt - Senior Notes (Details) $ in Thousands	1 Months Ended		3 Months Ended		12 Months Ended
	Mar. 31, 2017USD ($)	Feb. 28, 2017USD ($)	Mar. 31, 2017USD ($)	Mar. 31, 2016USD ($)	Dec. 31, 2016USD ($)Rate	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)
Debt Instrument [Line Items]
Loss on early extinguishment of debt			$ 42,000	$ 0	$ 52,180	$ 96,273	$ 114,335
Senior Notes [Member]
Debt Instrument [Line Items]
Debt Instrument Fixed Charge Coverage Ratio Period					12 months
Debt Instrument, Fixed Charge, Coverage Ratio | Rate					1.25
Debt Instrument, Redemption Price, Percentage					100.00%
Sabine Pass Liquefaction Senior Notes, Excluding 2026 Sabine Pass Liquefaction and 2027 Sabine Pass Liquefaction [Member]
Debt Instrument [Line Items]
Debt Instrument, Redemption Period, Minimum Number of Months Prior to Maturity Date, Redemption Price Equals Make-Whole Price					3 months
Debt Instrument, Redemption Period, Maximum Number of Months Prior to Maturity Date, Redemption Price Equals Principal Amount					3 months
2026 Senior Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	5.875%		5.875%		5.875%
Debt Instrument, Redemption Period, Minimum Number of Months Prior to Maturity Date, Redemption Price Equals Make-Whole Price					6 months
Debt Instrument, Redemption Period, Maximum Number of Months Prior to Maturity Date, Redemption Price Equals Principal Amount					6 months
Debt Instrument Registration Period					360 days
2027 Senior Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	5.00%		5.00%		5.00%
Debt Instrument, Redemption Period, Minimum Number of Months Prior to Maturity Date, Redemption Price Equals Make-Whole Price					6 months
Debt Instrument, Redemption Period, Maximum Number of Months Prior to Maturity Date, Redemption Price Equals Principal Amount					6 months
Debt Instrument Registration Period					360 days
2037 Senior Notes [Member]
Debt Instrument [Line Items]
Aggregate principal amount		$ 800,000
Proceeds from issuances of long-term debt		$ 789,000
Debt Instrument, Interest Rate, Stated Percentage	5.00%		5.00%
Debt Instrument, Redemption Period, Minimum Number of Months Prior to Maturity Date, Redemption Price Equals Optional Redemption Price			6 months
Debt Instrument, Redemption Period, Maximum Number of Months Prior to Maturity Date, Redemption Price Equals Principal Amount			6 months
Debt Instrument, Redemption Price, Percentage			100.00%
2028 Senior Notes [Member]
Debt Instrument [Line Items]
Aggregate principal amount	$ 1,350,000		$ 1,350,000
Proceeds from issuances of long-term debt	$ 1,330,000
Debt Instrument, Interest Rate, Stated Percentage	4.20%		4.20%
Debt Instrument, Redemption Period, Minimum Number of Months Prior to Maturity Date, Redemption Price Equals Make-Whole Price			6 months
Debt Instrument, Redemption Period, Maximum Number of Months Prior to Maturity Date, Redemption Price Equals Principal Amount			6 months
Debt Instrument, Redemption Price, Percentage			100.00%
Debt Instrument Registration Period			360 days
2015 Credit Facilities [Member]
Debt Instrument [Line Items]
Debt Instrument, Fixed Charge, Coverage Ratio | Rate					1.25
Repayments of Long-term Debt	$ 369,000
Commitments prepaid or terminated	$ 1,600,000		$ 1,600,000		$ 2,643,867
Loss on early extinguishment of debt			$ 42,000		$ 52,200

Debt - Credit Facilities Table

Debt - Credit Facilities Table (Details) - USD ($) $ in Thousands	3 Months Ended	12 Months Ended
	Mar. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Jun. 30, 2015
Line of Credit Facility [Line Items]
Outstanding balance	$ 13,460,000	$ 11,649,229	$ 9,205,559
Outstanding balance, current	0	223,500	15,000
2015 Credit Facilities [Member]
Line of Credit Facility [Line Items]
Original facility size		4,600,000		$ 4,600,000
Outstanding balance	0	314,000	845,000
Commitments prepaid or terminated	1,600,000	2,643,867
Letters of credit issued		0
Available commitment		$ 1,642,133
Debt Instrument, Description of Variable Rate Basis		LIBOR or base rate
Debt Instrument, Maturity Date, Description		Earlier of December 31, 2020 or second anniversary of Trains 1 through 5 completion date
2015 Credit Facilities [Member] | Base Rate [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate		1.75%
2015 Credit Facilities [Member] | Minimum [Member] | London Interbank Offered Rate (LIBOR) [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate		1.30%
2015 Credit Facilities [Member] | Maximum [Member] | London Interbank Offered Rate (LIBOR) [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate		1.75%
Working Capital Facility [Member]
Line of Credit Facility [Line Items]
Original facility size	1,200,000	$ 1,200,000
Outstanding balance, current	0	223,500	$ 15,000
Commitments prepaid or terminated		0
Letters of credit issued	377,000	323,677
Available commitment	$ 823,000	$ 652,823
Debt Instrument, Description of Variable Rate Basis	LIBOR or base rate	LIBOR or base rate
Debt Instrument, Maturity Date, Description	December 31, 2020, with various terms for underlying loans	December 31, 2020, with various terms for underlying loans
Working Capital Facility [Member] | London Interbank Offered Rate (LIBOR) [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate	1.75%	1.75%
Working Capital Facility [Member] | Base Rate [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate	0.75%	0.75%

Debt - 2015 Credit Facilities (

Debt - 2015 Credit Facilities (Details) $ in Thousands	3 Months Ended		12 Months Ended
	Mar. 31, 2017USD ($)	Mar. 31, 2016USD ($)	Dec. 31, 2016USD ($)Rate	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Jun. 30, 2015USD ($)
Line of Credit Facility [Line Items]
Loss on early extinguishment of debt	$ 42,000	$ 0	$ 52,180	$ 96,273	$ 114,335
2015 Credit Facilities [Member]
Line of Credit Facility [Line Items]
Line Of Credit Facility, Original Borrowing Capacity			4,600,000			$ 4,600,000
Commitments prepaid or terminated	1,600,000		2,643,867
Loss on early extinguishment of debt	$ 42,000		$ 52,200
Debt Instrument, Description of Variable Rate Basis			LIBOR or base rate
Line Of Credit Facility Insurance Premium Percentage Of Drawn Amount			0.45%
Line Of Credit Facility Unused Capacity Commitment Fee Percentage Of Margin On Undrawn Commitment			40.00%
Line of Credit Facility, Unused Capacity, Commitment Fee Percentage			0.70%
Line Of Credit Facility Amortization Period			18 years
Debt Instrument, Fixed Charge, Coverage Ratio | Rate			1.25
2015 Credit Facilities [Member] | Base Rate [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate			1.75%
2015 Credit Facilities [Member] | Minimum [Member]
Line of Credit Facility [Line Items]
Percentage of Debt Hedged by Interest Rate Derivatives			65.00%
2015 Credit Facilities [Member] | Minimum [Member] | London Interbank Offered Rate (LIBOR) [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate			1.30%
2015 Credit Facilities [Member] | Maximum [Member] | London Interbank Offered Rate (LIBOR) [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate			1.75%

Debt - Working Capital Faciliti

Debt - Working Capital Facilities (Details) - USD ($)	3 Months Ended	12 Months Ended
	Mar. 31, 2017	Dec. 31, 2016
Working Capital Facility [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Description of Variable Rate Basis	LIBOR or base rate	LIBOR or base rate
Letter of Credit, Commitment Fee Percentage		0.70%
Line of Credit Facility, Number of Business Days Notice Required for Repayment of Debt Without Penalty		3 days
Working Capital Facility [Member] | London Interbank Offered Rate (LIBOR) [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate	1.75%	1.75%
Working Capital Facility [Member] | Base Rate [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate	0.75%	0.75%
Working Capital Facility [Member] | Base Rate Determination Federal Funds Rate [Member] | Base Rate [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate		0.50%
Working Capital Facility [Member] | Base Rate Determination LIBOR [Member] | Base Rate [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate		0.50%
Working Capital Facility [Member] | Maximum [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility Permitted Increase		$ 760,000,000
Working Capital Facility [Member] | Completion of Train Six Financing [Member] | Maximum [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility Permitted Increase		$ 390,000,000
Letter of Credit [Member] | Portion issued and not drawn [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Unused Capacity Commitment Fee, Percentage of Undrawn Commitment		1.75%
Letter of Credit [Member] | Drawn Portion [Member]
Line of Credit Facility [Line Items]
Long-term Line of Credit		$ 0
Letter of Credit [Member] | Base Rate [Member] | Drawn Portion [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate		2.00%
Working Capital Loan [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Annual Temporary Requirement, Balance, Outstanding Principal		$ 0
Line of Credit Facility, Annual Temporary Requirement, Period, Number of Consecutive Business Days		5 days
Swing Line Loan [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Minimum Period For Termination Date, Number of Business Days		3 days
Swing Line Loan [Member] | Maximum [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Term		15 days
LC Loan [Member] | Maximum [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Term		1 year

Debt - Interest Expense (Detail

Debt - Interest Expense (Details) - USD ($) $ in Thousands	3 Months Ended		12 Months Ended
	Mar. 31, 2017	Mar. 31, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Debt Disclosure [Abstract]
Total interest cost	$ 186,000	$ 147,000	$ 648,915	$ 531,495	$ 397,949
Capitalized interest	(81,000)	(141,000)	(463,090)	(495,165)	(374,040)
Total interest expense, net	$ 105,000	$ 6,000	$ 185,825	$ 36,330	$ 23,909

Debt - Schedule of Carrying Val

Debt - Schedule of Carrying Values and Estimated Fair Values of Debt Instruments (Details) - USD ($) $ in Thousands		Mar. 31, 2017		Dec. 31, 2016		Dec. 31, 2015
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt, Carrying Value		$ 13,460,000		$ 11,872,729		$ 9,220,559
Senior Notes, net of premium or discount [Member] | Carrying Amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt, Carrying Value		12,861,000	[1]	11,512,838	[1]	8,515,110
Senior Notes, net of premium or discount [Member] | Estimated Fair Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Senior Notes, Estimated Fair Value		13,807,000	[1]	12,308,736	[1]	7,469,718
2037 Senior Notes [Member] | Carrying Amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt, Carrying Value	[2]	800,000		0
2037 Senior Notes [Member] | Estimated Fair Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Senior Notes, Estimated Fair Value	[2]	826,000		0
Credit Facilities [Member] | Carrying Amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt, Carrying Value		0	[3]	537,500	[3]	860,000
Credit Facilities [Member] | Estimated Fair Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Credit Facilities, Estimated Fair Value		$ 0	[3]	$ 537,500	[3]	$ 860,000
[1]	Includes 2021 Senior Notes, 2022 Senior Notes, 2023 Senior Notes, 2024 Senior Notes, 2025 Senior Notes, 2026 Senior Notes, 2027 Senior Notes and 2028 Senior Notes. The Level 2 estimated fair value was based on quotes obtained from broker-dealers or market makers of these senior notes and other similar instruments.
[2]	The Level 3 estimated fair value was calculated based on inputs that are observable in the market or that could be derived from, or corroborated with, observable market data, including our stock price and interest rates based on debt issued by parties with comparable credit ratings to us and inputs that are not observable in the market.
[3]	Includes 2015 Credit Facilities and Working Capital Facility. The Level 3 estimated fair value approximates the principal amount because the interest rates are variable and reflective of market rates and the debt may be repaid, in full or in part, at any time without penalty.

Related Party Transactions - Sc

Related Party Transactions - Schedule of Related Party Transactions (Details) - USD ($) $ in Thousands	3 Months Ended		12 Months Ended
	Mar. 31, 2017	Mar. 31, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Related Party Transaction [Line Items]
LNG revenues—affiliate	$ 331,000	$ 0	$ 293,957	$ 0	$ 0
Cost of sales—affiliate	4,000	0	6,754	0	0
Operating and maintenance expense—affiliate	59,000	1,000	128,423	1,331	95
Terminal use agreement maintenance expense—affiliate			208	400	387
Development expense—affiliate			511	722	1,153
General and administrative expense—affiliate	17,000	17,000	68,070	87,681	71,065
Cheniere Marketing SPA and Cheniere Marketing Master SPA [Member]
Related Party Transaction [Line Items]
LNG revenues—affiliate	331,000	0	293,957	0	0
Cargo loading fees under the Terminal Use Rights Assignment and Agreement [Member]
Related Party Transaction [Line Items]
Cost of sales—affiliate	4,000	0	5,264	0	0
Fees under Pre-commercial LNG Marketing Agreement [Member]
Related Party Transaction [Line Items]
Cost of sales—affiliate			1,490	0	0
Terminal Use Agreement [Member]
Related Party Transaction [Line Items]
Operating and maintenance expense—affiliate	33,000	0	60,516	0	0
Terminal use agreement maintenance expense—affiliate			208	400	387
Natural Gas Transportation Agreement [Member]
Related Party Transaction [Line Items]
Operating and maintenance expense—affiliate	16,000	0	44,656	0	0
Service Agreements [Member]
Related Party Transaction [Line Items]
Operating and maintenance expense—affiliate	10,000	1,000	22,424	860	95
Development expense—affiliate			396	722	1,153
General and administrative expense—affiliate	$ 17,000	$ 17,000	68,070	87,425	70,553
LNG Site Sublease Agreement [Member]
Related Party Transaction [Line Items]
Operating and maintenance expense—affiliate			827	471	0
Development expense—affiliate			115	0	0
General and administrative expense—affiliate			0	241	482
Other agreements [Member]
Related Party Transaction [Line Items]
General and administrative expense—affiliate			$ 0	$ 15	$ 30

Related Party Transactions - 67

Related Party Transactions - Schedule of Percentage of TUA Fees Payable (Details) - Terminal Use Agreement [Member] - SPLNG [Member]	3 Months Ended
	Mar. 31, 2017
Prior to Substantial Completion of SPL Train 1 [Member]
Related Party Transaction [Line Items]
Percentage of TUA Fees Payable	0.00%
Between Substantial Completion of SPL Trains 1 and 2 [Member]
Related Party Transaction [Line Items]
Percentage of TUA Fees Payable	25.00%
Between Substantial Completion of SPL Trains 2 and 3 [Member]
Related Party Transaction [Line Items]
Percentage of TUA Fees Payable	50.00%
Between Substantial Completion of SPL Trains 3 and 4 [Member]
Related Party Transaction [Line Items]
Percentage of TUA Fees Payable	75.00%
After Substantial Completion of SPL Train 4 [Member]
Related Party Transaction [Line Items]
Percentage of TUA Fees Payable	100.00%
Cheniere Investments [Member] | Prior to Substantial Completion of SPL Train 1 [Member]
Related Party Transaction [Line Items]
Percentage of TUA Fees Payable	100.00%
Cheniere Investments [Member] | Between Substantial Completion of SPL Trains 1 and 2 [Member]
Related Party Transaction [Line Items]
Percentage of TUA Fees Payable	75.00%
Cheniere Investments [Member] | Between Substantial Completion of SPL Trains 2 and 3 [Member]
Related Party Transaction [Line Items]
Percentage of TUA Fees Payable	50.00%
Cheniere Investments [Member] | Between Substantial Completion of SPL Trains 3 and 4 [Member]
Related Party Transaction [Line Items]
Percentage of TUA Fees Payable	25.00%
Cheniere Investments [Member] | After Substantial Completion of SPL Train 4 [Member]
Related Party Transaction [Line Items]
Percentage of TUA Fees Payable	0.00%

Related Party Transactions - Na

Related Party Transactions - Narrative (Details)	Aug. 31, 2016	Apr. 30, 2016	Sep. 30, 2016	May 31, 2016	Mar. 31, 2017USD ($)bcf / dtrains$ / MMBTU	Mar. 31, 2016USD ($)	Sep. 30, 2015USD ($)	Dec. 31, 2016USD ($)bcf / dmitrains$ / MMBTU	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)
Related Party Transaction [Line Items]
Advances to affiliate					$ 51,000,000			$ 25,892,000	$ 28,312,000
Terminal Use Agreement [Member] | SPLNG [Member]
Related Party Transaction [Line Items]
Regasification Capacity | bcf / d					2			2
Related Party Transaction, Committed Annual Fee					$ 250,000,000			$ 250,000,000
Related Party Agreement Term					20 years			20 years
Related Party Transaction, Percentage Of Committed Monthly Payment	25.00%	0.00%	50.00%	25.00%
Portion of Storage Capacity Reserved					41.00%			41.00%
Terminal Use Agreement [Member] | SPLNG [Member] | Cheniere Investments [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Percentage Of Committed Monthly Payment	75.00%	100.00%	50.00%	75.00%
Terminal Use Agreement [Member] | SPLNG [Member] | Cheniere Investments [Member] | Maximum [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Percentage Of Committed Monthly Payment					100.00%			100.00%
Terminal Use Agreement [Member] | SPLNG [Member] | Cheniere Investments [Member] | Minimum [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Percentage Of Committed Monthly Payment					0.00%			0.00%
LNG Sale and Purchase Agreement [Member] | Cheniere Marketing [Member]
Related Party Transaction [Line Items]
LNG Volume, Purchase Price Percentage of Henry Hub					115.00%			115.00%
LNG Volume, Purchase Price | $ / MMBTU					3			3
Commissioning Agreement [Member] | Cheniere Marketing [Member]
Related Party Transaction [Line Items]
Number of Liquefaction LNG Trains Subject To Agreement | trains					4			4
Service Agreements [Member]
Related Party Transaction [Line Items]
Advances to affiliate					$ 51,000,000			$ 25,900,000	28,300,000
Operation and Maintenance Agreement [Member] | Cheniere Investments [Member]
Related Party Transaction [Line Items]
Monthly fee as a percentage of capital expenditures incurred in the previous month					0.60%			0.60%
Related Party Transaction, Committed Monthly Fee					$ 83,333			$ 83,333
Management Services Agreement [Member] | Cheniere Terminals [Member]
Related Party Transaction [Line Items]
Monthly fee as a percentage of capital expenditures incurred in the previous month					2.40%			2.40%
Related Party Transaction, Committed Monthly Fee					$ 541,667			$ 541,667
LNG Site Sublease Agreement [Member] | SPLNG [Member]
Related Party Transaction [Line Items]
Annual Sublease Payment					$ 1,000,000			$ 900,000	500,000
Term of available extension					10 years			10 years
Review Period for Inflation Adjustment					5 years			5 years
Cooperation Agreement [Member] | SPLNG [Member]
Related Party Transaction [Line Items]
Assets conveyed under the agreement					$ 0	$ 253,000,000		$ 252,800,000	$ 80,500,000	$ 700,000
Interconnect Agreement [Member] | CTPL [Member]
Related Party Transaction [Line Items]
Assets conveyed under the agreement							$ 10,100,000
Interconnect Agreement [Member] | CTPL [Member] | Creole Trail Pipeline [Member]
Related Party Transaction [Line Items]
Length Of Natural Gas Pipeline | mi								94
Tax Sharing Agreement [Member] | Cheniere [Member]
Related Party Transaction [Line Items]
Income Taxes Paid, Net					$ 0			$ 0

Leases (Details)

Leases (Details) - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Leases [Abstract]
Operating Leases, Rent Expense		$ 1,800	$ 1,200	$ 900
2017, Minimum Payment		396
2018, Minimum Payment		396
2019, Minimum Payment		396
2020, Minimum Payment		396
2021, Minimum Payment		373
Thereafter, Minimum Payment		5,137
Total, Minimum Payment	[1]	$ 7,094
[1]	Includes certain lease option renewals that are reasonably assured.

Commitments and Contingencies -

Commitments and Contingencies - Narrative (Details) MMBTU / yr in Millions, MMBTU in Millions, $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2017bcf / dMMBTU	Dec. 31, 2016USD ($)bcf / dMMBTU / yrMMBTUitem
Commitments and Contingencies [Line Items]
Energy Units Secured Through Long-Term Supply Contracts | MMBTU	2,051	1,993.9
Loss Contingency, Pending Claims, Number | item		0
SPLNG [Member] | Terminal Use Agreement [Member]
Commitments and Contingencies [Line Items]
Regasification Capacity | bcf / d	2	2
Supply Commitments, Trains 1 and 2 [Member]
Commitments and Contingencies [Line Items]
Contract Volumes | MMBTU / yr		401.5
Supply Commitments, Trains 3 through 5 [Member]
Commitments and Contingencies [Line Items]
Contract Volumes | MMBTU / yr		628.5
Bechtel EPC Contracts [Member] | Maximum [Member]
Commitments and Contingencies [Line Items]
Contract Termination Convenience Penalty		$ 30
Bechtel EPC Contract, Trains 3 and 4 [Member]
Commitments and Contingencies [Line Items]
Long-Term Purchase Commitment, Amount		3,900
Bechtel EPC Contract, Train 5 [Member]
Commitments and Contingencies [Line Items]
Long-Term Purchase Commitment, Amount		$ 3,000
Natural Gas Supply Agreement [Member] | Minimum [Member]
Commitments and Contingencies [Line Items]
Long-Term Purchase Commitment, Period		1 year
Natural Gas Supply Agreement [Member] | Maximum [Member]
Commitments and Contingencies [Line Items]
Long-Term Purchase Commitment, Period		6 years
Transportation Agreement [Member] | Minimum [Member]
Commitments and Contingencies [Line Items]
Long-Term Purchase Commitment, Period		10 years
Transportation Agreement [Member] | Maximum [Member]
Commitments and Contingencies [Line Items]
Long-Term Purchase Commitment, Period		20 years
Storage Service Agreement [Member] | Minimum [Member]
Commitments and Contingencies [Line Items]
Long-Term Purchase Commitment, Period		3 years
Storage Service Agreement [Member] | Maximum [Member]
Commitments and Contingencies [Line Items]
Long-Term Purchase Commitment, Period		10 years

Commitments and Contingencies71

Commitments and Contingencies - Purchase Obligations Table (Details) - Natural Gas Supply Transportation And Storage Service Agreements [Member] $ in Thousands	Dec. 31, 2016USD ($)
Long-term Purchase Commitment [Line Items]
2,017	$ 1,611,296
2,018	1,192,791
2,019	1,019,309
2,020	1,055,497
2,021	903,425
Thereafter	2,169,912
Total	$ 7,952,230	[1]
[1]	Pricing of natural gas supply contracts are variable based on market commodity basis prices adjusted for basis spread. Amounts included are based on prices and basis spreads as of December 31, 2016.

Supplemental Cash Flow Inform72

Supplemental Cash Flow Information (Details) - USD ($) $ in Thousands	3 Months Ended		12 Months Ended
	Mar. 31, 2017	Mar. 31, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Supplemental Cash Flow Information [Abstract]
Cash paid during the period for interest, net of amounts capitalized	$ 154,000	$ 27,000	$ 74,519	$ 0	$ 0
Non-cash distributions to affiliates for conveyance of assets	0	253,000	252,802	90,645	745
Other non-cash distribution to affiliates			0	149	0
Non-cash conveyance of assets to non-affiliate			0	13,169	0
Balance in property, plant and equipment, net funded with accounts payable and accrued liabilities (including affiliate)	$ 306,000	$ 303,000	$ 262,600	$ 228,200	$ 117,400

Subsequent Events (Details)

Subsequent Events (Details) - 2037 Senior Notes [Member] - USD ($)	Mar. 31, 2017	Feb. 28, 2017	Feb. 24, 2017
Subsequent Event [Line Items]
Aggregate principal amount		$ 800,000,000
Debt Instrument, Interest Rate, Stated Percentage	5.00%
Subsequent Event [Member]
Subsequent Event [Line Items]
Aggregate principal amount			$ 800,000,000
Debt Instrument, Interest Rate, Stated Percentage			5.00%

Summarized Quarterly Financia74

Summarized Quarterly Financial Data (unaudited) (Details) - USD ($) $ in Thousands	3 Months Ended									12 Months Ended
	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Quarterly Financial Information Disclosure [Abstract]
Revenues	$ 823,000	$ 483,633	$ 264,424	$ 85,326	$ 28	$ 0	$ 0	$ 0	$ 0	$ 833,411	$ 0	$ 0
Income (loss) from operations	145,000	123,804	(15,375)	(28,521)	(30,061)	(15,120)	(9,891)	(29,532)	(37,089)	49,847	(91,632)	(119,179)
Net income (loss)	$ (4,000)	$ 44,809	$ (104,343)	$ (86,690)	$ (47,241)	$ (35,132)	$ (12,835)	$ (48,101)	$ (169,549)	$ (193,465)	$ (265,617)	$ (376,853)