Niska Gas Storage Partners (NKA) 10-K 30 May 14 2014 FY Annual report Financial data

Document_and_Entity_Informatio

Document and Entity Information (USD $)	12 Months Ended
	Mar. 31, 2014	29-May-14	Sep. 30, 2013
Entity Registrant Name	'Niska Gas Storage Partners LLC	'	'
Entity Central Index Key	'0001483830	'	'
Document Type	'10-K	'	'
Document Period End Date	31-Mar-14	'	'
Amendment Flag	'false	'	'
Current Fiscal Year End Date	'--03-31	'	'
Entity Well-known Seasoned Issuer	'No	'	'
Entity Voluntary Filers	'No	'	'
Entity Current Reporting Status	'Yes	'	'
Entity Filer Category	'Accelerated Filer	'	'
Entity Public Float	'	'	$270,375,077
Entity Common Stock, Shares Outstanding	'	36,190,243	'
Document Fiscal Year Focus	'2014	'	'
Document Fiscal Period Focus	'FY	'	'

Consolidated_Statements_of_Ear

Consolidated Statements of Earnings (Loss) and Comprehensive Income (Loss) (USD $)	12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012
REVENUES	'	'	'
Fee-based revenue (Note 15)	$135,356	$163,325	$146,053
Optimization, net (Note 15)	72,040	-22,630	122,528
Total revenues	207,396	140,695	268,581
EXPENSES (INCOME)	'	'	'
Operating	40,834	32,535	43,978
General and administrative	39,937	38,562	28,582
Depreciation and amortization (Notes 4 and 5)	41,286	50,409	46,132
Interest (Notes 6 and 16)	66,315	67,010	74,630
Loss on extinguishment of debt (Notes 6, 7 and 17)	36,697	599	4,861
Impairment of goodwill (Note 5)	'	'	250,000
Loss on impairment and sale of assets (Note 4)	'	14,927	5,342
Foreign exchange losses (gains)	1,182	-694	682
Other expenses (income)	358	-110	-167
EARNINGS (LOSS) BEFORE INCOME TAXES	-19,213	-62,543	-185,459
Income tax expense (benefit) (Note 11)	'	'	'
Current	82	-1,414	412
Deferred	-10,338	-17,528	-20,099
Income tax (benefit) expense	-10,256	-18,942	-19,687
NET EARNINGS (LOSS) AND COMPREHENSIVE INCOME (LOSS)	-8,957	-43,601	-165,772
Net earnings (loss) allocated to:	'	'	'
Managing Member	-171	-863	-3,283
Common unitholders	-8,786	-21,584	-82,063
Subordinated unitholder (Notes 1 and 14)	'	($21,154)	($80,426)
Earnings (loss) per unit allocated to common unitholders	'	'	'
basic (in dollars per unit)	($0.25)	($0.63)	($2.39)
diluted (in dollars per unit)	($0.25)	($0.63)	($2.39)
Earnings (loss) per unit allocated to subordinated unitholders (Notes 1 and 14)	'	'	'
basic (in dollars per unit) (Notes 1 and 14)	'	($0.63)	($2.39)
diluted (in dollars per unit) (Notes 1 and 14)	'	($0.63)	($2.39)

Consolidated_Balance_Sheets

Consolidated Balance Sheets (USD $)	Mar. 31, 2014	Mar. 31, 2013
In Thousands, unless otherwise specified
Current Assets	'	'
Cash and cash equivalents	$7,704	$10,610
Margin deposits	32,626	18,474
Trade receivables - net	5,760	2,702
Accrued receivables	150,628	106,726
Natural gas inventory	75,140	83,416
Prepaid expenses and other current assets	4,330	4,688
Short-term risk management assets (Notes 12 and 13)	20,949	21,159
Total current assets	297,137	247,775
Long-term Assets	'	'
Property, plant and equipment, net of accumulated depreciation (Note 4)	908,274	918,061
Goodwill (Note 5)	245,604	245,604
Long-term natural gas inventory (Note 4)	'	15,264
Intangible assets, net of accumulated amortization (Note 5)	65,462	73,998
Deferred charges, net of accumulated amortization (Note 6)	14,640	14,420
Other Assets	3,268	2,677
Long-term risk management assets (Notes 12 and 13)	4,806	6,593
Total long-term assets	1,242,054	1,276,617
TOTAL	1,539,191	1,524,392
Current Liabilities	'	'
Revolving credit facility (Note 7)	119,500	65,000
Current portion of obligations under capital lease (Note 8)	1,299	1,259
Trade payables	1,023	1,048
Current portion of deferred taxes (Note 11)	5,678	14,303
Deferred revenue	6,036	568
Accrued liabilities (Note 9)	111,118	39,840
Short-term risk management liabilities (Notes 12 and 13)	19,105	20,005
Total current liabilities	263,759	142,023
Long-term Liabilities	'	'
Long-term risk management liabilities (Notes 12 and 13)	12,209	4,574
Asset retirement obligations (Note 10)	1,975	2,007
Other long-term liabilities	1,809	1,461
Deferred income taxes (Note 11)	119,373	120,935
Obligations under capital lease (Note 8)	10,926	12,225
Long-term debt (Note 7)	575,000	643,790
Total liabilities	721,292	784,992
MEMBERS' EQUITY	'	'
Common units	279,604	321,642
Subordinated units (Notes 1 and 14)	'	265,877
Managing Member's interest	274,536	9,858
Total members' equity	554,140	597,377
Commitments and contingencies (Notes 7, 14 and 19)	'	'
Subsequent events (Note 24)	'	'
TOTAL	$1,539,191	$1,524,392

Consolidated_Statements_of_Cas

Consolidated Statements of Cash Flows (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012
Operating Activities	'	'	'
Net earnings (loss)	($8,957)	($43,601)	($165,772)
Adjustments to reconcile net earnings (loss) to net cash provided by operating activities:	'	'	'
Unrealized foreign exchange losses (gains)	1,500	-252	391
Deferred income tax benefit (Note 11)	-10,338	-17,528	-20,648
Unrealized risk management losses (gains) (Notes 12 and 13)	8,732	89,851	-83,193
Depreciation and amortization (Notes 4 and 5)	41,286	50,409	46,132
Deferred charges amortization (Notes 6 and 16)	3,354	3,411	3,942
Loss on extinguishment of debt (Notes 6, 7 and 17)	36,697	599	4,861
Loss on impairment and sale of assets (Note 4)	'	14,927	5,342
Impairment of goodwill (Note 5)	'	'	250,000
Write-down of inventory	4,600	22,281	23,400
Changes in non-cash working capital (Note 20)	15,033	42,033	-56,420
Net cash provided by operating activities	91,907	162,130	8,035
Investing Activities	'	'	'
Property, plant and equipment expenditures	-3,159	-30,015	-52,820
Purchase of customer contracts	-2,007	'	'
Proceeds on disposal of assets	'	2,210	'
Net cash used in investing activities	-5,166	-27,805	-52,820
Financing Activities	'	'	'
Proceeds from debt issuance	575,000	'	'
Debt redemption / repurchase	-672,361	'	-158,012
Proceeds on revolver drawings	784,500	348,448	701,800
Revolver repayments	-730,000	-433,448	-551,800
Payments of financing costs	-10,855	-3,248	'
Payments of unit issuance costs	-218	'	'
Proceeds from obligations under capital lease	'	947	13,245
Repayments of obligations under capital lease	-1,259	-717	'
Distributions to partners (Notes 14 and 24)	-34,051	-48,811	-74,568
Net proceeds from issuance of common units	'	'	11,000
Acquisition of interest in parent company	'	'	-2,176
Acquisition of assets from parent company	'	'	428
Net cash used in financing activities	-89,244	-136,829	-60,083
Effect of translation on foreign currency cash and cash equivalents	-403	-228	468
Net decrease in cash and cash equivalents	-2,906	-2,732	-104,400
Cash and cash equivalents, beginning of the year	10,610	13,342	117,742
Cash and cash equivalents, end of the year	$7,704	$10,610	$13,342

Consolidated_Statements_of_Cha

Consolidated Statements of Changes in Members' Equity (USD $)	Total	Common Units	Subordinated Units	Managing Member's Interest
In Thousands, unless otherwise specified
Balance at Mar. 31, 2011	$916,973	$510,275	$390,283	$16,415
Increase (Decrease) in Stockholders' Equity	'	'	'	'
Net earnings (loss)	-165,772	-82,063	-80,426	-3,283
Distributions to unitholders	-74,568	-48,981	-24,101	-1,486
Acquisition of interest in parent company	-2,176	-1,066	-1,066	-44
Acquisition of assets from parent company	428	212	208	8
Issuance of common units	11,000	11,000	'	'
Tax benefit of offering costs	4,505	2,208	2,207	90
Balance at Mar. 31, 2012	690,390	391,585	287,105	11,700
Increase (Decrease) in Stockholders' Equity	'	'	'	'
Net earnings (loss)	-43,601	-21,584	-21,154	-863
Distributions to unitholders	-49,412	-48,359	-74	-979
Balance at Mar. 31, 2013	597,377	321,642	265,877	9,858
Increase (Decrease) in Stockholders' Equity	'	'	'	'
Cancellation of subordinated units	'	'	-265,877	265,877
Net earnings (loss)	-8,957	-8,786	'	-171
Distributions to unitholders	-52,321	-51,293	'	-1,028
Issuance of common units	18,041	18,041	'	'
Balance at Mar. 31, 2014	$554,140	$279,604	'	$274,536

Description_of_Business

Description of Business	12 Months Ended
	Mar. 31, 2014
Description of Business	'
Description of Business	'
	1. Description of Business
	Niska Gas Storage Partners LLC ("Niska Partners" or the "Company") is a publicly-traded Delaware limited liability company (NYSE:NKA) which independently owns and/or operates natural gas storage assets in North America. The Company operates the Countess and Suffield gas storage facilities (collectively, the AECO Hub™) in Alberta, Canada, and the Wild Goose and Salt Plains gas storage facilities in California and Oklahoma, respectively. Each of these facilities markets natural gas storage services in addition to optimizing storage capacity with its own proprietary gas purchases.
	On April 2, 2013, Niska Partners completed an equity restructuring with affiliates of Carlyle/Riverstone Global Energy and Power Fund II, L.P. and Carlyle/Riverstone Global Energy and Power Fund III, L.P. (collectively the "Carlyle/Riverstone Funds"). In the restructuring, all of the Company's 33.8 million subordinated units and previous incentive distribution rights (all of which were owned by the Carlyle/Riverstone Funds) were combined into and restructured as a new class of incentive distribution rights ("new IDRs"). The equity restructuring, which did not require any further consents or approvals, was effective as of the same day. The transaction was unanimously approved by the Company's Board of Directors on the unanimous approval and recommendation of its Conflicts Committee, which is composed solely of independent directors.
	The restructuring permanently eliminated all of the Company's subordinated units and previous incentive distribution rights in return for the new IDRs (see Note 14). Prior to completion of the restructuring, the Company would have been required to pay the full minimum quarterly distribution of $0.35 per unit on the subordinated units (requiring additional distributions of approximately $12 million per quarter) prior to increasing the quarterly distribution on common units. Quarterly distributions on the subordinated units had not been paid since the quarter ended September 30, 2011.
	The new IDRs entitle the Carlyle/Riverstone Funds to receive 48% of any quarterly cash distributions after Niska Partners' common unitholders have received the full minimum quarterly distribution ($0.35 per unit) for each quarter plus any arrearages from prior quarters (of which there are currently none). The previous incentive distribution rights entitled the Carlyle/Riverstone Funds to receive increasing percentages (ranging from 13% to 48%) of incremental cash distributions after the unitholders (both common and subordinated) exceeded quarterly distributions ranging from $0.4025 per unit to $0.5250 per unit. In addition, for a period of five years, and provided that the Carlyle/Riverstone Funds continue to own a majority of both the managing member and the new IDRs, the Carlyle/Riverstone Funds will be deemed to own 33.8 million "Notional Subordinated Units" in connection with votes to remove and replace the managing member. These Notional Subordinated Units are not entitled to distributions, but preserve the Carlyle/Riverstone Fund's voting rights with respect to removal of the managing member.
	At March 31, 2014, Niska Partners had 35,745,060 common units outstanding. Of these amounts, 18,245,055 common units were owned by the Carlyle/Riverstone Funds, along with a 1.91% Managing Member's interest in the Company and all of the new IDRs. Including all of the common units owned by the Carlyle/Riverstone Funds, along with the 1.91% Managing Member's interest, the Carlyle/Riverstone Funds had a 51.98% ownership interest in the Company, excluding the new IDRs. The remaining 17,500,005 common units, representing a 48.02% ownership interest excluding the IDRs, were owned by the public.

Significant_Accounting_Policie

Significant Accounting Policies	12 Months Ended
	Mar. 31, 2014
Significant Accounting Policies	'
Significant Accounting Policies	'
	2. Significant Accounting Policies
	Basis of presentation
	These consolidated financial statements have been prepared to reflect the consolidated financial position, results of operations and cash flows of Niska Partners and its subsidiaries and have been prepared in accordance with accounting principles generally accepted in the United States of America ("GAAP").
	These financial statements include the accounts of Niska Partners and its wholly-owned subsidiaries, including AECO Gas Storage Partnership, Wild Goose Storage LLC, Niska Gas Storage, LLC, Salt Plains Storage, LLC, Access Gas Services Inc., Access Gas Services (Ontario) Inc., EnerStream Agency Services Inc., and Niska Partners Management ULC. All material intercompany transactions have been eliminated.
	Use of estimates
	In preparing these financial statements, Niska Partners is required to make estimates and assumptions that affect both the amount and timing of recording assets, liabilities, revenues and expenses since the determination of these items may be dependent on future events. Management uses the most current information available and exercises careful judgment in making these estimates. Although management believes that these consolidated financial statements have been prepared within limits of materiality and within the framework of its significant accounting policies summarized below, actual results could differ from these estimates. Changes in estimates are accounted for on a prospective basis.
	Revenue recognition
	The Company's assessment of each of the four revenue recognition criteria as they relate to its revenue producing activities is as follows:
	Persuasive evidence of an arrangement exists.    The Company's customary practices are to enter into a written contract, executed by both the customer and the Company.
	Delivery.    Delivery is deemed to have occurred at the time the natural gas is delivered and title is transferred, or in the case of fee-based arrangements, when the services are rendered. To the extent the Company retains its inventory, delivery occurs when the inventory is subsequently sold and title is transferred to the third-party purchaser.
	The fee is fixed or determinable.    The Company negotiates the fee for its services at the outset of their fee-based arrangements. In these arrangements, the fees are nonrefundable. The fees are generally due on the 25th of the month following the delivery or services rendered. For other arrangements, the amount of revenue is determinable when the sale of the applicable product has been completed upon delivery and transfer of title.
	Collectability is reasonably assured.    Collectability is evaluated on a customer-by-customer basis. New and existing customers are subject to a credit review process, which evaluates the customers' financial position (e.g. cash position and credit rating) and their ability to pay. If collectability is not considered reasonably assured at the outset of an arrangement in accordance with the Company's credit review process, revenue is recognized when the fee is collected.
	Fee-based revenue consists of long-term contracts for storage fees that are generated when we lease storage capacity on a monthly basis and short-term fees associated with park and loan activities. Long-term contract revenue consists of monthly storage fees and fuel and commodity charges for injections and withdrawals. Long-term contract revenue is accrued on a monthly basis in accordance with the terms of the customer contracts. Customer charges for injections and withdrawals are recorded in the month of injection or withdrawal. Short-term contract revenue consists of fees for injections and withdrawals, where the customer pays a fixed fee to inject a specified quantity of natural gas on a specified date or dates and withdraw a specified quantity of natural gas on a specified date. The fee stipulated in a short-term contract for each performance obligation (injection and withdrawal) is recognized when the service occurs.
	Energy trading contracts resulting in the delivery of a commodity where Niska Partners is the principal in the transaction are recorded as optimization revenues at the time of physical delivery. Realized and unrealized gains and losses on financial energy trading contracts are included in optimization revenue (see Note 12—Risk Management Activities and Financial Instruments).
	Optimization revenue, net includes realized gains and losses and the net change in unrealized gains and losses on financial and physical energy trading contracts. Optimization revenue results from the purchase of inventory and its forward sale to future periods through financial and physical trading contracts. These derivative contracts are economic hedges that have been entered into to manage commodity price and currency risk associated with buying and selling natural gas across future time periods (see Note 12). The Company does not designate these instruments as hedges and therefore records the unrealized gains and losses on the changes in their fair value through net earnings. Contracts resulting in the delivery of a commodity where Niska Partners is the principal in the transaction are recorded as optimization revenues at the time of physical delivery.
	Sales taxes collected from customers and remitted to governmental authorities are excluded from revenues in the consolidated statements of earnings (loss) and comprehensive income (loss).
	Cash and cash equivalents
	Niska Partners considers all highly liquid investments purchased with an initial maturity of three months or less to be cash equivalents.
	Margin deposits
	Cash held in margin represents the right to receive or the obligation to pay cash collateral under a master netting arrangement that has not been offset against derivative positions. These derivatives are marked-to-market daily; the profit or loss on the daily position is then paid to, or received from, the account as appropriate under the terms of the Company's contract with its broker.
	Natural gas inventory
	The Company's inventory is natural gas injected into storage which is held for resale. Inventory is valued at the lower of weighted average cost or market. Adjustments to write down the costs of inventory to market are recorded as an offset to optimization revenues while costs to store the gas are recognized as operating expenses in the period the costs are incurred in the consolidated statements of earnings (loss) and comprehensive income (loss).
	Long-term inventory represents non-cycling working gas. Non-cycling working gas was injected by the Company to increase pressure within the reservoirs to allow it to market higher cycling contracts or previously un-saleable gas from an underutilized reservoir that can be sold into the market when the Company adds mechanical compression to the reservoir. This mechanical compression allows access to natural gas that was previously required to maintain pressure within the reservoir. Long-term inventory is carried at cost and is subject to an annual test for impairment.
	In March 2014, the Company reclassified the balance of its long-term natural gas inventory to cushion to reflect operational requirements.
	Property, plant and equipment
	Property, plant and equipment are recorded at cost when purchased. Depreciation is computed using the declining balance method for each category of asset using the following rates:
	Pipelines and measurement	5%
	Wells	5%
	Facilities	Between 5% and 22%
	Computer hardware and software	30%
	Office furniture and fixtures	20%
	Other	10%
	Property, plant and equipment under capital leases are depreciated using the declining balance method over the lesser of the useful lives of the assets or the lease term.
	Certain volumes of natural gas defined as cushion are required for maintaining a minimum field pressure. Cushion is considered a component of the facility and as such is not amortized. Cushion is monitored to ensure that it provides effective pressure support for the facility. In the event that gas moves to another area of the reservoir where it does not provide effective pressure support, a loss is recorded, within depreciation expense, equal to the estimated volumes that have migrated (see Note 4). Proceeds from sale of cushion are classified as operating activities in the Consolidated Statements of Cash Flows since the predominant source of cash flows for natural gas purchases and sales are operating in nature.
	Repairs, maintenance and renewals that do not extend the useful lives of the assets are expensed as incurred. Interest costs for the construction or development of long-lived assets held by operational entities are capitalized and amortized over the related asset's estimated useful life (see Note 4).
	Asset retirement obligations
	Niska Partners records a liability for an asset retirement obligation when the legal obligation to retire the asset has been incurred with an offsetting increase to the carrying value of the related tangible long-lived asset. The recognition of an asset retirement obligation requires that management make numerous estimates, assumptions and judgments regarding such factors as the estimated probabilities, amounts and timing of settlements; the credit-adjusted risk-free rate to be used; inflation rates, and future advances in technology. In periods subsequent to initial measurement of the liability, the Company must recognize changes in the liability resulting from the passage of time and revisions to either the timing or the amount of the original estimate of undiscounted cash flows. Over time, the liability is accreted to its future value, and the capitalized cost is depreciated over the useful life of the related asset. Accretion of the asset retirement obligations due to the passage of time is recorded as an expense in the statement of earnings. Upon settlement of the liability, the Company either settles the obligation for its recorded amount or incurs a gain or loss.
	Netting of certain balance sheet accounts
	Certain risk management assets and liabilities and certain accrued gas sales and purchases are presented on a net basis in the balance sheet when all of the following exist: (i) Niska Partners and the other party owe the other a determinable amount; (ii) the Company has the right to set off the amount owed with the amount owed by the other party; (iii) Niska Partners intends to set off; and (iv) the right of setoff is enforceable by law.
	Leases
	Niska Partners determines a lease to be an operating or capital lease based upon the terms of the lease, estimated fair value of the leased assets, estimated life of the leased assets, and the contractual minimum lease payments as defined within the lease agreements. If the Company concludes that it has substantively all of the risks of ownership of a leased property and therefore is deemed the owner of the property for accounting purposes, it records an asset and related obligations under capital lease at the lower of the present value of the minimum lease payments or the fair value of the asset.
	Impairment of long-lived assets
	Niska Partners evaluates whether events or circumstances have occurred that indicate that long-lived assets may not be recoverable or that the remaining useful life may warrant revision. When such events or circumstances are present, the Company assesses the recoverability of long-lived assets by determining whether the carrying value will be recovered through the expected undiscounted future cash flows. In the event that the sum of the expected future cash flows resulting from the use of the asset is less than the carrying value of the asset, an impairment loss equal to the excess of the asset's carrying value over its fair value is recorded.
	Goodwill and other intangible assets
	Niska Partners accounts for business acquisitions using the purchase method of accounting and, accordingly, the assets and liabilities of the acquired entities are recorded at their estimated fair values at the date of acquisition. The excess of the purchase price over the fair value of the net assets acquired is attributed to goodwill.
	Goodwill is not amortized and is re-evaluated on an annual basis or more frequently if events or changes in circumstances indicate that the asset might be impaired. Goodwill is tested for impairment between annual tests if an event occurs or circumstances change that would more likely than not reduce the fair value of a reporting unit below its carrying value. These events or circumstances could include a significant change in the business climate, legal factors, operating performance indicators, competition, sale or disposition of a significant portion of the business or other factors.
	To re-evaluate goodwill for impairment, the Company has the option to first assess qualitative factors to determine whether it is more likely than not that goodwill is impaired. The result of the qualitative assessment would be used as a basis in determining whether it is necessary to perform the quantitative impairment test. The performance of the quantitative impairment test involves a two-step process. The first step involves comparing the fair values of the applicable reporting units with their aggregate carrying values, including goodwill. If the carrying amount exceeds the fair value of the reporting unit, the Company performs the second step of the goodwill impairment test to determine the amount of impairment loss. The second step of the goodwill impairment test involves comparing the implied fair value of the affected reporting unit's goodwill with the carrying value of that goodwill.
	Other intangible assets represent contractual rights obtained in connection with a business combination that had favorable contractual terms relative to market as of the acquisition date.
	Intangible assets representing customer contracts are amortized over their useful lives. These assets are reviewed for impairment as impairment indicators arise. When such events or circumstances are present, the recoverability of long-lived assets is assessed by determining whether the carrying value will be recovered through the expected undiscounted future cash flows. In the event that the sum of the expected future cash flows resulting from the use of the asset is less than the carrying value of the asset, an impairment loss equal to the excess of the asset's carrying value over its fair value is recorded.
	Pipeline rights of way are formal agreements granting rights of way in perpetuity and are not subject to amortization but are subject to an annual impairment test.
	Risk management activities
	The Company uses natural gas derivatives and other financial instruments to manage its exposure to changes in natural gas prices, and foreign exchange rates. These financial assets and liabilities, which are recorded at fair value on a recurring basis, are included in one of three categories based on a fair value hierarchy with realized and unrealized gains (losses) recognized in earnings (see Note 13).
	The fair value of the Company's derivative risk management contracts are recorded as a component of risk management assets and liabilities, which are classified as current or non-current assets or liabilities based upon the anticipated settlement date of the contracts.
	Foreign currency translation
	The functional and reporting currency of the Company is the U.S. dollar. Non-U.S. dollar denominated monetary items are translated into U.S. dollars at the rate of exchange in effect at the balance sheet date. Non-U.S. dollar denominated non-monetary items are translated to U.S. dollars at the exchange rate in effect when the transaction occurred. Revenues and expenses denominated in foreign currencies are translated at the actual exchange rate or average exchange rate in effect during the period. Foreign exchange gains or losses on translation are included in income.
	Deferred charges
	Deferred charges relate to costs incurred on the issuance of debt and are amortized over the term of the related debt to interest expense using the effective interest method for cost related to the senior notes offering and straight-line for deferred charges incurred on the revolving credit facility. Any remaining unamortized deferred charges related to repurchased senior notes or modified revolving credit facility agreements are written off on the dates of redemption or modification.
	Income taxes
	The Company is not directly a taxable entity. Income taxes on its income are the responsibility of the individual unitholders and have accordingly not been recorded in the consolidated financial statements. However, Niska Partners does own corporate subsidiaries, which are taxable corporations subject to Canadian federal and provincial income taxes, which are included in the consolidated financial statements.
	Income taxes on the Canadian corporate subsidiaries are provided based on the asset and liability method, which results in deferred income tax assets and liabilities arising from temporary differences. Temporary differences are differences between the tax basis of assets and liabilities and their reported amounts in the financial statements that will result in taxable or deductible amounts in future years. This method requires the effect of tax rate changes on current and accumulated deferred income taxes to be reflected in the period in which the rate change was enacted. The asset and liability method also requires that deferred income tax assets be reduced by a valuation allowance unless it is more likely than not that the assets will be realized.
	The Company's policy is to recognize accrued interest and penalties on accrued tax balances as components of interest expense.
	The Canadian subsidiaries remain subject to examination by Canadian federal and provincial tax jurisdictions for all years filed after 2006. The Company's unitholders, relative to the Company, remain subject to examination by US federal and state tax jurisdictions for years from 2009 and beyond.
	Long term equity-based incentives
Niska Partners' compensation committee approves awards of phantom units with distribution equivalent rights to certain key employees. These awards include both time-based and performance-based components.
Unit award grants are classified as liabilities. The fair value of the units granted is determined on the date of grant and is re-measured at each reporting period until the settlement date. The fair value at each re-measurement date is equal to the settlement expected to be incurred based on the anticipated number of units vested adjusted for (1) the passage of time and (2) the payout threshold associated with the performance targets which the Company expects to achieve compared to its established peers. The pro-rata number of units vesting is calculated as the number of performance awards multiplied by the percentage of the requisite service period, plus additional units granted in lieu of the cash distributions paid on the vested units.
Compensation expense is calculated as the re-measured expected payout less previously-recognized compensation expense.

Recent_Accounting_Pronouncemen

Recent Accounting Pronouncements	12 Months Ended
	Mar. 31, 2014
Recent Accounting Pronouncements	'
Recent Accounting Pronouncements	'
	3. Recent Accounting Pronouncements
	In December 2011, the Financial Accounting Standards Board ("FASB") issued a guidance which requires disclosure of information to provide enhanced disclosures to enable users of its financial statements to evaluate the effect or potential effect of netting arrangements on an entity's assets and liabilities. In January 2013, the FASB issued an update to this guidance which limits the scope of the required balance sheet offsetting disclosures to derivative instruments accounted for in accordance with Accounting Standards Codification ("ASC") Topic 815, Derivative and Hedging, subject to an enforceable master netting arrangement or similar agreement. The Company adopted this guidance on April 1, 2013 and adoption resulted in an increase in disclosure regarding the Company's risk management assets and liabilities that had netting or right of offset arrangements.
	In July 2013, the FASB issued guidance which requires entities to present unrecognized tax benefit or portion of an unrecognized tax benefit, in the financial statements as a reduction to a deferred tax asset for a net operating loss carry forward, a similar tax loss, or a tax credit carry forward except when (1) a net operating loss carry forward, a similar loss, or a tax credit carry forward is not available as of the reporting date under the governing tax law to settle taxes that would result from the disallowance of the tax position; and (2) the entity does not intend to use the deferred tax asset for this purpose, provided that tax law permits a choice. If either of these conditions exists, entities should present an unrecognized tax benefit in the financial statements as a liability and should not net the unrecognized tax benefit with a deferred tax asset. The Company will adopt this guidance on April 1, 2014 and adoption will not have a material impact on the Company's financial position, result of operations or cash flows.

Property_Plant_and_Equipment

Property, Plant and Equipment	12 Months Ended
	Mar. 31, 2014
Property, Plant and Equipment	'
Property, Plant and Equipment	'
	4. Property, Plant and Equipment
	Property, plant and equipment are comprised of the following:
		As at March 31, 2014
		Cost		Accumulated			Net Book
				Depreciation			Value
	Cushion	$	421,404	$	—		$	421,404
	Pipelines and measurement		296,671		(92,687	)		203,984
	Wells		126,694		(40,700	)		85,994
	Facilities		272,645		(79,028	)		193,617
	Computer hardware and software		4,225		(3,087	)		1,138
	Construction in progress, including projects under development		1,063		—			1,063
	Office furniture, equipment and other		2,473		(1,399	)		1,074
		$	1,125,175	$	(216,901	)	$	908,274
		As at March 31, 2013
		Cost		Accumulated			Net Book
				Depreciation			Value
	Cushion	$	406,141	$	—		$	406,141
	Pipelines and measurement		296,661		(81,950	)		214,711
	Wells		126,519		(36,179	)		90,340
	Facilities		267,508		(64,238	)		203,270
	Computer hardware and software		4,095		(2,653	)		1,442
	Construction in progress, including projects under development		928		—			928
	Office furniture, equipment and other		2,473		(1,244	)		1,229
		$	1,104,325	$	(186,264	)	$	918,061
	Facilities include cost and accumulated depreciation of assets under capital lease of $14.2 million and $4.5 million as of March 31, 2014 and $14.2 million and $1.8 million as of March 31, 2013, respectively.
	In March 2014, the Company reclassified the balance of its long-term natural gas inventory to cushion to reflect operational requirements.
	During the year ended March 31, 2013, a loss of $9.5 million was recognized as depreciation and amortization on the consolidated statements of earnings (loss) and comprehensive income (loss) for the estimated amount of cushion that had migrated (March 31, 2014—$ nil; March 31, 2012—$6.7 million). In addition, the Company sold cushion from one of its Canadian facilities and from two of its U.S. facilities, which resulted in losses of $14.9 million and $2.8 million during the years ended March 31, 2013 and 2012, respectively.
	Certain steel pipe that was deemed no longer fit to transport natural gas was sold after March 31, 2012. These assets were valued as of March 31, 2012 using a combination of the present value of future cash flows method and the subsequently agreed selling price, resulting in an impairment charge of $2.5 million (March 31, 2014—$ nil; March 31, 2013—$ nil).

Goodwill_and_Other_Intangible_

Goodwill and Other Intangible Assets	12 Months Ended
	Mar. 31, 2014
Goodwill and Other Intangible Assets	'
Goodwill and Other Intangible Assets	'
	5. Goodwill and Other Intangible Assets
	Goodwill
	The goodwill impairment test is performed at a reporting unit level. Reporting units are identified and distinguished based on how the associated business is managed, taking into consideration the nature of services offered, the types of customer contracts entered into and the nature of the economic and regulatory environment. Niska Partners has four reporting units which are aggregated into one operating segment for financial reporting purposes.
	During the year ended March 31, 2014, the Company performed a qualitative assessment to determine whether its goodwill was impaired. Based on overall macroeconomic conditions as well as industry, market and company-specific considerations, the Company determined that it is more likely than not that its goodwill is not impaired. Therefore, a two-step, quantitative assessment was not required.
	During the year ended March 31, 2013, the Company performed a quantitative impairment test to each of its reporting units. Based on its calculations, it was determined that estimated fair values of each of its reporting unit exceeded its carrying amounts, including goodwill, therefore, no impairment was recorded.
	During the year ended March 31, 2012, following a period of continued narrow seasonal spreads, along with a significant reduction in natural gas price volatility, the Company determined the fair value of the AECO HubTM and NGPL reporting units using a combination of the present value of future cash flows method and the comparable transactions method. The present value of future cash flows was estimated using (i) discrete financial forecasts, which rely on management's estimates of revenue, expenses and volumes, (ii) long-term natural gas volatility and seasonal spreads (iii) long-term average exchange rate between the United States Dollar and the Canadian Dollar and (iv) appropriate discount rates. The comparable transactions method analyzed other purchases of similar assets and considered (i) the anticipated cash flows of the Company determined above, (ii) recent transaction multiples based on anticipated cash flows and (iii) the similarity of comparable transactions to the Company's facilities. Specifically, the Company used experience and budgeted amounts to estimate cycling volumes and expenses, the future summer to winter spreads which reflects its longer term outlook, extrinsic values consistent with those achieved in the business to estimate future revenue, and a discount rate of 8.875%. These values used to estimate future revenues are lower than the seasonal storage spread and extrinsic values used in the Company's most recent annual test. The Company also used a comparable transaction multiple consistent with transactions for depleted reservoir storage facility acquisitions (the type of facilities comparable to the Company's AECO HubTM facility) completed between 2006 and 2012. Both the AECO HubTM facility and the NGPL leased capacity failed step one of the goodwill impairment test; therefore, the second step of impairment test was performed.
	In step two, the Company compared the implied fair value of the reporting units' goodwill with the carrying amounts of that goodwill. Under step two of the impairment test, significant assumptions in measuring the fair value of the assets and liabilities include (1) the replacement cost, depreciation and obsolescence and useful lives of property, plant and equipment and (2) the present value of incremental cash flows attributable to certain intangible assets. Based on the step two analysis, the Company determined that an impairment charge of $250 million was required.
	The Company also considered the factors outlined above in determining the goodwill impairment to be an indicator of impairment related to the long-lived assets associated with the AECO HubTM facility and the NGPL leased capacity. Accordingly, these assets were evaluated for impairment prior to completing the goodwill valuation and management concluded that no impairment of other long-lived assets had occurred.
	Other intangible assets
	Information regarding the Company's intangible assets is included in the following table:
		As at March 31,
		2014			2013
	Customer contracts and relationships, beginning of the year	$	163,073		$	163,073
	Additions		2,007			—
	Less accumulated amortization		(117,888	)		(107,345	)
	Customer contracts and relationships, end of the year		47,192			55,728
	Pipeline rights of way		18,270			18,270
		$	65,462		$	73,998
	Customer contracts and relationships are amortized over the term of the respective contracts, being 1 to 15 years remaining at March 31, 2014. The following tables present actual amortization expense recognized during reported periods and an estimate of future amortization expense based upon the Company's intangible assets at March 31, 2014:
	Amortization expense for the fiscal year ended:
	March 31, 2014	$	10,543
	March 31, 2013		11,311
	March 31, 2012		13,675
	Future amortization expense estimated for the fiscal year ending:
	March 31, 2015	$	23,633
	March 31, 2016		5,977
	March 31, 2017		7,513
	March 31, 2018		3,558
	March 31, 2019 and thereafter		6,511
	On May 1, 2014, the Company and its largest volumetric customer executed a storage service agreement which replaced its pre-existing storage agreement which contained an option to terminate effective April 1, 2015. As a result of the execution of the new contract, the Company has revised the amortization schedule above to reflect the new pattern in which the cash flows from the intangible asset are generated. See "Note 24—Subsequent Events" for more information.

Deferred_Charges

Deferred Charges	12 Months Ended
	Mar. 31, 2014
Deferred Charges	'
Deferred Charges	'
	6. Deferred Charges
		As at March 31,
		2014			2013
	Deferred charges—cost, beginning of the year	$	25,377		$	23,566
	Additions		11,696			3,248
	Write-offs due to extinguishment of debt		(16,995	)		—
	Write-offs due to amendment and restatement of revolving credit facility		—			(1,437	)
	Deferred charges—cost, end of the year		20,078			25,377
	Accumulated amortization, beginning of the year		(10,957	)		(8,384	)
	Amortization during the year		(3,354	)		(3,411	)
	Write-offs due to extinguishment of debt		8,873			—
	Write-offs due to amendment and restatement of revolving credit facility		—			838
	Accumulated amortization, end of the year		(5,438	)		(10,957	)
	Net book value	$	14,640		$	14,420
	Life in years		5-Mar			5-Jan
	The following table presents the amortization recognized as interest expense during each period reported:
	Amortization expense by period:
	March 31, 2014	$	3,354
	March 31, 2013		3,411
	March 31, 2012		3,942

Debt

Debt	12 Months Ended
	Mar. 31, 2014
Debt	'
Debt	'
	7. Debt
	At March 31, 2014 and 2013 the Company's debt consisted of the following:
		As at March 31
		2014			2013
	8.875% Senior Notes due 2018	$	—		$	643,790
	6.50% Senior Notes due 2019		575,000			—
	Revolving credit facilities		119,500			65,000
			694,500			708,790
	Less: portion classified as current		(119,500	)		(65,000	)
		$	575,000		$	643,790
	Senior Notes due 2019
	On March 17, 2014, Niska Partners completed the private placement of senior unsecured notes due 2019 (the "6.50% Senior Notes"). The 6.50% Senior Notes were issued through Niska Gas Storage Finance Corp. and Niska Gas Storage Canada ULC (together, the "Issuers"). Net proceeds from the offering of approximately $563.3 million, after deducting underwriters' discounts and fees, along with borrowings under our asset-based revolving credit facility, were used to redeem the $643.8 million outstanding principal amount of the Company's 8.875% Senior Notes due 2018. Including a call premium of approximately $28.6 million and the write-off of unamortized deferred financing costs of $8.1 million, the Company recognized a loss of $36.7 million, which was recorded as a loss on extinguishment of debt. These losses were measured based on the amount paid as well as on the carrying value of the redeemed 8.875% Senior Notes, which included unamortized debt issue costs on the dates of redemption. The related accrued interest paid were recorded in interest expense. Costs directly related to the issuance of the new Notes were capitalized as deferred charges and are amortized to interest expense over the term of the debt.
	During the year ended March 31, 2012, Niska Partners paid $158.0 million to repurchase 8.875% Senior Notes with a principal amount of $156.2 million on which the Company recognized losses of $4.9 million.
	The 6.50% Senior Notes are senior unsecured obligations which are: (1) effectively junior to Niska Partners' secured obligations to the extent of the value of the collateral securing such debt; (2) equal in right of payment with all existing and future senior unsecured indebtedness of the Company; and (3) senior in right of payment to any future subordinated indebtedness of Niska Partners. The 6.50% Senior Notes are fully and unconditionally guaranteed by Niska Partners and its direct and indirect subsidiaries on a senior unsecured basis, and are: (1) effectively junior to each guarantor's secured obligations; (2) equal in right of payment with all existing and future senior unsecured indebtedness of each guarantor and (3) senior in right of payment to any future subordinated indebtedness of each guarantor.
	Interest on the 6.50% Senior Notes is payable semi-annually on October 1 and April 1, commencing on October 1, 2014, and will mature on April 1, 2019. As of March 31, 2014, the estimated fair market value of the Notes was $570.7 million.
	Prior to October 1, 2016, the Company has the option to redeem up to 35% of the aggregate principal amount of the 6.50% Senior Notes using net cash proceeds from certain equity offerings at a price of 106.5% plus accrued and unpaid interest. The Company may also redeem all or a part of the 6.50% Senior Notes at redemption prices (expressed as percentages of principal amount) equal to 103.25% during the twelve-month period beginning on October 1, 2016, 101.625% during the twelve-month period beginning on October 1, 2018 and at any time thereafter, plus accrued and unpaid interest, if any, to the applicable redemption date on the notes. The Company is not required to make mandatory redemptions or sinking fund payments with respect to the 6.50% Senior Notes.
	The indenture governing the 6.50% Senior Notes limits Niska Partners' ability to pay distributions in respect of, repurchasing or paying dividends on its membership interests (or other capital stock) or making other restricted payments. The limitation changes depending on a fixed charge coverage ratio, which is defined as the ratio of consolidated cash flow to fixed charges, each as defined in the indenture governing the 6.50% Senior Notes, and measured for the preceding four quarters.
	If the fixed charge coverage ratio is not less than 1.75 to 1.0, Niska Partners is permitted to make restricted payments if the aggregate restricted payments since the date of closing of our IPO, excluding certain types of permitted payments, are less than the sum of a number of items including, most importantly:
	•
	operating surplus (defined similarly to the definition in our Operating Agreement) calculated as of the end of our preceding fiscal quarter; and
	•
	the aggregate net cash proceeds received as a capital contribution or from the issuance of equity interests.
	If the fixed charge coverage ratio is less than 1.75 to 1.0, Niska Partners is permitted to make restricted payments if the aggregate restricted payments since the date of closing of its IPO, excluding certain types of permitted payments, are less than the sum of a number of items including, most importantly:
	•
	$75.0 million; and
	•
	the aggregate net cash proceeds received as a capital contribution or from the issuance of equity interests.
	As of March 31, 2014, the fixed charge coverage ratio was 2.8 to 1.0 and the indenture governing the Notes would have permitted the Company to distribute approximately $207.1 million. The fixed charge coverage ratio was calculated on a pro-forma basis, taking into account the redemption of the 8.875% Senior Notes due 2018 as if the redemption had occurred on April 1, 2013. The indenture does not prohibit certain types or amounts of restricted payments, including a general basket of $75.0 million of restricted payments.
	The indenture governing the Notes contains certain other covenants that, among other things, limit Niska Partners and certain of its subsidiaries' ability to:
	•
	incur additional debt or issue certain capital stock;
	•
	pay dividends on, repurchase or make distributions in respect of our capital stock or repurchase or retire subordinated indebtedness;
	•
	make certain investments;
	•
	sell assets;
	•
	create liens;
	•
	consolidate, merge, sell or otherwise dispose of all or substantially all of our assets;
	•
	enter into certain transactions with our affiliates; and
	•
	permit restrictions on the ability of our subsidiaries to make distributions.
	The occurrence of events involving the Company or certain of its subsidiaries may constitute an event of default under the indenture. Such events include failure to pay interest, principal, or the premium on the notes when due; failure to comply with the merger, asset sale or change of control covenants; certain defaults on other indebtedness; and certain insolvency proceedings. In the case of an event of default, the holders of the notes are entitled to remedies, including the acceleration of payment of the notes by request of the holders of at least 25% in aggregate principal amount of the notes, and any action by the trustee to collect payment of principal, interest or premium in arrears.
	Upon the occurrence of a change of control together with a decrease in the ratings of the 6.50% Senior Notes by either Moody's or S&P by one or more gradations within 90 days of the change of control event, Niska Partners must offer to repurchase the Notes at 101% of the principal amount of the notes to be repurchased, plus accrued and unpaid interest, if any, to the date of repurchase.
	The Niska Partners' ability to repurchase the 6.50% Senior Notes upon a change of control will be limited by the terms of its debt agreements, including its asset-based revolving credit facility. In addition, the Company cannot assure that it will have the financial resources to repurchase the Notes upon a change of control.
	Revolving credit facilities
	On June 29, 2012, Niska Partners, through its subsidiaries, Niska Gas Storage US, LLC and AECO Gas Storage Partnership, completed an amendment and restatement of its $400.0 million Credit Agreement (the "Credit Facilities"). These Credit Facilities provide for revolving loans and letters of credit in an aggregate principal amount of up to $200.0 million for each of a U.S. revolving credit facility and a Canadian revolving credit facility. Subject to certain conditions, each of the U.S. revolving credit facility and the Canadian revolving credit facility may be expanded up to a total of $100.0 million in additional commitments, and the commitments in each facility may be reallocated on terms and according to procedures to be determined. Loans under the U.S. revolving facility will be denominated in U.S. dollars and loans under the Canadian revolving facility may be denominated, at Niska Partners' option, in either U.S. or Canadian dollars. The revolving credit facilities mature on June 29, 2016. During the year ended March 31, 2013, a loss related to the amendment and restatement amounted to $0.6 million representing a portion of the deferred financing costs associated with the original agreement were written off.
	Borrowings under the Credit Facilities are limited to a borrowing base calculated as the sum of specified percentages of eligible cash and cash equivalents, eligible accounts receivable, the net liquidating value of hedge positions in broker accounts, eligible inventory, issued but unused letters of credit, and certain fixed assets minus the amount of any reserves and other priority claims. Borrowings will bear interest at prevailing market rates, which (1) in the case of U.S. dollar loans can be either fixed rate plus an applicable margin or, at the Company's option, a base rate plus an applicable margin, and (2) in the case of Canadian dollar loans can be either the bankers' acceptance rate plus an applicable margin or, at the Company's option, a prime rate plus an applicable margin. The credit agreement provides that Niska Partners may borrow only up to the lesser of the level of the then current borrowing base or the committed maximum borrowing capacity, which is currently $400.0 million. As of March 31, 2014, the borrowing base collateral totaled $396.4 million.
	Obligations under the $400.0 million Credit Agreement are guaranteed by the Niska Partners' and all of the Company's direct and indirect wholly owned subsidiaries (subject to certain exceptions) and secured by a lien on substantially all of the Company's and its direct and indirect subsidiaries' current and fixed assets (subject to certain exceptions). Certain fixed assets will only be required to be part of the collateral to the extent such fixed assets are included in the borrowing base under the Credit Facility. The aggregate borrowing base under the Credit Facilities includes $150.0 million (the "PP&E Amount") due to a first-priority lien on fixed assets granted to the lenders. The PP&E Amount will be reduced on a dollar-for-dollar basis upon the release of fixed assets having a value in excess of $50.0 million from such liens.
	The $400 million Credit Agreement contains limitations on Niska Partners' ability to incur additional debt or to pay distributions in respect of, repurchase or pay dividends on its membership interests (or other capital stock) or make other restricted payments. These limitations are similar to those contained in the indenture governing the 6.50% Senior Notes, but contain certain substantive differences. As a result of these differences, the limitations on restricted payments contained in the Credit Agreement should be less restrictive than the limitations contained in the indenture. As of March 31, 2014, Niska Partners was in compliance with all covenant requirements under the 6.50% Senior Notes and the $400 million Credit Agreement.
	The following fees are applicable under each revolving credit facility: (1) an unused line fee based on the unused portion of the respective revolving credit facility; (2) a letter of credit participation fee on the aggregate stated amount of each letter of credit equal to the applicable margin for LIBOR loans or bankers' acceptance loans, as applicable; and (3) certain other customary fees and expenses of the lenders and agents. The Company is required to make prepayments under the revolving credit facilities at any time when, and to the extent that, the aggregate amount of the outstanding loans and letters of credit under such revolving credit facility exceeds the lesser of the aggregate amount of commitments in respect of such revolving credit facility and the applicable borrowing base.
	The $400.0 million Credit Agreement contains customary covenants, including, but not limited to, restrictions on the Company's and its subsidiaries' ability to merge and consolidate with other companies, incur indebtedness, grant liens or security interests on assets subject to security interests under the credit agreement, make acquisitions, loans, advances or investments, pay distributions, sell or otherwise transfer assets, optionally prepay or modify terms of any subordinated indebtedness or enter into transactions with affiliates. The Credit Facilities require the maintenance of a fixed charge coverage ratio of 1.1 to 1.0 at the end of each fiscal quarter when excess availability under both the U.S. revolving credit facility and the Canadian revolving credit facility is less than 15% of the aggregate amount of availability under both revolving credit facilities. Such fixed charge coverage ratio will be tested at the end of each quarter until such time as average excess availability exceeds 15% for thirty consecutive days.
	The $400.0 million Credit Agreement provides that, upon the occurrence of certain events of default, the Company's obligations thereunder may be accelerated and the lending commitments terminated. Such events of default include payment defaults to the lenders, material inaccuracies of representations and warranties, covenant defaults, cross-defaults to other material indebtedness, including the notes, voluntary and involuntary bankruptcy proceedings, material money judgments, material events relating to pension plans, certain change of control events and other customary events of default.
	As of March 31, 2014, $119.5 million (March 31, 2013—$65.0 million) in borrowings, with a weighted average interest rate of 3.56% (March 31, 2013—3.69%), were outstanding under the Credit Facilities. Issued letters of credit amounted to $4.8 million and $3.3 million as of March 31, 2014 and 2013, respectively.
	Restrictions
	Niska Partners has no independent assets or operations other than its investments in its subsidiaries. Both the 6.50% Senior Notes and the $400.0 million Credit Agreement have been jointly and severally guaranteed by Niska Partners and substantially all of its subsidiaries. Niska Partners' subsidiaries have no significant restrictions on their ability to pay distributions or make loans to Niska Partners, which are prepared and measured on a consolidated basis, and have no restricted assets as of March 31, 2014.
	The Company's principal debt covenant is the fixed charge coverage ratio, which is included in both the Credit Facility and in the Indenture. When the fixed charge coverage ratio is less than 2.0 times, Niska Partners is restricted in its ability to issue new debt. When the fixed charge coverage ratio is below 1.75 to 1.0, the Company is restricted in its ability to pay distributions. At March 31, 2014, the fixed charge coverage ratio was 2.8 to 1.0.

Obligations_Under_Capital_Leas

Obligations Under Capital Lease	12 Months Ended
	Mar. 31, 2014
Obligations Under Capital Lease	'
Obligations Under Capital Lease	'
	8. Obligations Under Capital Lease
	The Company leases certain equipment under a lease arrangement for estimated future minimum lease payments of approximately $13.9 million. Niska Partners may purchase the assets after August 15, 2020 for an agreed portion of the acquisition cost. The present value of the minimum future lease payments is based on the total costs incurred by the lessor and has been reflected in the balance sheet as a current and a non-current obligation under capital lease. The underlying obligations are denominated in U.S. dollars, have an imputed interest rate of 3.08% and are owing through the lease maturity in August 2021.
	Following are the future principal and interest payments of obligations under capital lease as of March 31, 2014.
	For the fiscal year ending:
	March 31, 2015	$	1,657
	March 31, 2016		1,657
	March 31, 2017		1,657
	March 31, 2018		1,657
	March 31, 2019		1,657
	March 31, 2020 and thereafter		5,574
	Less: Amount representing interest		(1,634	)
		$	12,225

Accrued_Liabilities

Accrued Liabilities	12 Months Ended
	Mar. 31, 2014
Accrued Liabilities	'
Accrued Liabilities	'
	9. Accrued Liabilities
	Niska Partners' accrued liabilities consist of the following:
		As at March 31,
		2014		2013
	Accrued gas purchases	$	75,454	$	14,213
	Employee-related accruals		22,315		13,836
	Accrued interest		2,037		2,845
	Other accrued liabilities		11,312		8,946
		$	111,118	$	39,840

Asset_Retirement_Obligations

Asset Retirement Obligations	12 Months Ended
	Mar. 31, 2014
Asset Retirement Obligations	'
Asset Retirement Obligations	'
	10. Asset Retirement Obligations
	Niska Partners' asset retirement obligations relate to plugging and abandonment of the storage facilities at the end of their estimated useful economic lives. At March 31, 2014, the estimated undiscounted cash flows required to settle the asset retirement obligations were approximately $54.1 million, calculated using an inflation rate of 2% per annum. The estimated liability at March 31, 2014 was $2.0 million after discounting the estimated cash flows at a rate of 8% per annum. At March 31, 2014, the expected timing of payment for settlement of the obligations is 43 years.
		Year ended
		March 31,
		2014			2013
	Balance, beginning of the year	$	2,007		$	1,554
	Additions		—			210
	Accretion		107			197
	Effect of foreign exchange translation		(139	)		46
	Balance, end of the year	$	1,975		$	2,007

Income_Taxes

Income Taxes	12 Months Ended
	Mar. 31, 2014
Income Taxes	'
Income Taxes	'
	11. Income Taxes
	The components of the Company's earnings (loss) before income taxes (benefits) follow:
		Year ended March 31,
		2014			2013			2012
	Domestic	$	16,844		$	(493	)	$	72,270
	Foreign		(36,057	)		(62,050	)		(257,729	)
		$	(19,213	)	$	(62,543	)	$	(185,459	)
	Total income tax expense (benefit) differed from the amounts computed by applying the tax rate to earnings (loss) before income taxes as a result of the following:
		Year ended March 31,
		2014			2013			2012
	Net earnings (loss) before taxes	$	(19,213	)	$	(62,543	)	$	(185,459	)
	U.S. federal corporate statutory rate		35	%		35	%		35	%
	Expected tax		(6,725	)		(21,890	)		(64,911	)
	Earnings (loss) of non-taxable entities		(6,296	)		1,377			(25,295	)
	Canadian statutory tax rate differences		3,559			6,145			22,768
	Change in valuation allowance		(1,248	)		(452	)		(8,413	)
	Adjustments and assessments		(690	)		(4,796	)		(7,529	)
	Non-deductible expense related to asset impairment		—			—			59,304
	Taxable capital gains		—			—			3,895
	Non-deductible expenses and other		1,144			674			494
	Income tax benefit	$	(10,256	)	$	(18,942	)	$	(19,687	)
	The Company is not a taxable entity in the United States. Income taxes on its income are the responsibility of individual unitholders and have accordingly not been recorded in the consolidated financial statements. Niska Partners has Canadian corporate subsidiaries, which are taxable corporations subject to income taxes, which are included in the consolidated financial statements.
	As at March 31, 2014, Niska Partners' Canadian subsidiaries had accumulated non-capital losses of approximately $76.2 million (March 31, 2013—$34.9 million) that can be carried forward and applied against future taxable income. These non-capital losses have resulted in deferred income tax assets of $18.4 million (March 31, 2013—$8.5 million). Additionally, Niska Partners' Canadian subsidiaries had recognized deferred income tax assets related to capital losses of $18.9 million at March 31, 2014 (March 31, 2013—$20.6 million). The capital losses represent $2.4 million (March 31, 2013—$2.6 million) of deferred tax assets, of which $2.4 million (March 31, 2013—$2.3 million) have been offset by valuation allowances due to the uncertainty of their realization. Of the total tax assets related to losses, $0.1 million will begin to expire at the end of 2029.
	For the year ended March 31, 2014, Niska Partners recognized $ nil (March 31, 2013—$ nil; March 31, 2012—$0.3 million) of potential interest and penalties associated with uncertain tax positions. The Company files income tax returns in the U.S. federal jurisdiction, various state jurisdictions and other foreign jurisdictions. The Company is subject to income tax examinations for the fiscal years ended 2006 through 2014 in most jurisdictions.
	Deferred income tax assets and liabilities reflect the tax effect of differences between the basis of assets and liabilities for book and tax purposes. The tax effect of temporary differences that give rise to significant components of the deferred income tax liabilities and deferred income tax assets are presented below:
		As at March 31,
		2014			2013
	Deferred income tax assets:
	Risk management liabilities	$	33,386		$	8,904
	Non-capital loss carry forwards		18,434			8,451
	Deferred charges		6,890			1,166
	Capital losses		2,358			2,577
	Other		2,403			806
			63,471			21,904
	Valuation allowance		(4,004	)		(2,607	)
	Total deferred income tax assets	$	59,467		$	19,297
	Deferred income tax liabilities:
	Property, plant and equipment	$	114,298		$	114,148
	Intangible assets		15,137			17,636
	Partnership deferral income		37,499			11,007
	Risk management assets		17,049			11,477
	Other		535			267
	Total deferred income tax liabilities		184,518			154,535
	Net deferred income tax liabilities	$	125,051		$	135,238
	The classification of net deferred income tax liabilities recorded on the balance sheets is as follows:
		As at March 31,
		2014			2013
	Deferred income tax liabilities:
	Current	$	5,678		$	14,303
	Long-term		119,373			120,935
		$	125,051		$	135,238
	Uncertain Income Tax Positions
	When accounting for uncertainty in income taxes, a company recognizes a tax benefit in the financial statements for an uncertain tax position if management's assessment is that the position is "more likely than not" (i.e. a likelihood greater than fifty percent) to be allowed by the tax jurisdiction based solely on the technical merits of the position. The term "tax position" refers to a position in a previously filed tax return or a position expected to be taken in a future tax return that is reflected in measuring current or deferred income tax assets and liabilities for interim or annual periods.
	The following table indicates the changes to the Company's unrecognized tax benefits for the years ended March 31, 2014 and 2013. The term "unrecognized tax benefits" refers to the differences between a tax position taken or expected to be taken in a tax return and the benefit measured and recognized in the financial statements. Interest and penalties are not included.
		As at March 31,
		2014			2013
	Balance at April 1,	$	1,160		$	3,267
	Additions based on tax positions taken in the current year		375			—
	Additions (reductions) based on tax positions taken in a prior year		200			(1,411	)
	Settlements with taxing authorities in the current year		—			(696	)
	Balance at March 31,	$	1,735		$	1,160
	Substantially all of the $1.7 million of unrecognized tax benefits at March 31, 2014, would have an impact on the effective tax rate if subsequently recognized.
	The Company engages in ongoing discussions with tax authorities regarding the resolution of tax matters in various jurisdictions. Both the outcome of these tax matters and the timing of the resolution and/or closure of the tax audits are highly uncertain. It is management's assessment that no unrecognized tax benefits will be recognized within the next twelve months.

Risk_Management_Activities_and

Risk Management Activities and Financial Instruments	12 Months Ended
	Mar. 31, 2014
Risk Management Activities and Financial Instruments	'
Risk Management Activities and Financial Instruments	'
	12. Risk Management Activities and Financial Instruments
	Risk management overview
	The Company has exposure to commodity price, foreign currency, counterparty credit, interest rate, and liquidity risk. Risk management activities are tailored to the risk they are designed to mitigate.
	Commodity price risk
	As a result of its natural gas inventory, Niska Partners is exposed to risks associated with changes in price when buying and selling natural gas across future time periods. To manage this risk and reduce variability of cash flows, the Company utilizes a combination of financial and physical derivative contracts, including forwards, futures, swaps and option contracts. The use of these contracts is subject to the Company's risk management policies. Niska Partners has not elected hedge accounting treatment and therefore changes in fair value are recorded directly into earnings.
	Forwards and futures are contractual agreements to purchase or sell a specific financial instrument or natural gas at a specified price and date in the future. The Company enters into forwards and futures to mitigate the impact of price volatility. In addition to cash settlement, exchange traded futures may also be settled by physical delivery of natural gas.
	Swap contracts are agreements between two parties to exchange streams of payments over time according to specified terms. Swap contracts require receipt of payment for the notional quantity of the commodity based on the difference between a fixed price and the market price on the settlement date. The Company enters into commodity swaps to mitigate the impact of changes in natural gas prices.
	Option contracts are contractual agreements to convey the right, but not the obligation, for the purchaser of the option to buy or sell a specific physical or notional amount of a commodity at a fixed price, either at a fixed date or at any time within a specified period. Niska Partners enters into option agreements to mitigate the impact of changes in natural gas prices.
	To limit its exposure to changes in commodity prices, Niska Partners enters into purchases and sales of natural gas inventory and concurrently matches the volumes in these transactions with offsetting derivative contracts. To be in compliance with its risk policy, Niska Partners is required to limit its exposure of unmatched volumes of proprietary current natural gas inventory to an aggregate overall limit of 8.0 billion cubic feet ("Bcf"). As at March 31, 2014, 18.4 Bcf of natural gas inventory was offset, representing 97.2% of total current inventory. The volume of inventories as of March 31, 2014 and 2013 which were economically hedged using each type of contract were as follows:
		As at March 31,
		2014	2013
	Forwards	(1.4 Bcf)	1.6 Bcf
	Futures	20.1 Bcf	14.1 Bcf
	Swaps	(0.3 Bcf)	10.0 Bcf
	Options	—	—
		18.4 Bcf	25.7 Bcf
	Counterparty credit risk
	Niska Partners is exposed to counterparty credit risk on its trade and accrued accounts receivable and risk management assets. Counterparty credit risk is the risk of financial loss to the Company if a customer fails to perform its contractual obligations. Niska Partners engages in transactions for the purchase and sale of products and services with major companies in the energy industry and with industrial, commercial, residential and municipal energy consumers. Credit risk associated with trade accounts receivable is mitigated by the high percentage of investment grade customers, collateral support of receivables and the Company's ability to take ownership of customer-owned natural gas stored in its facilities in the event of non-payment. During the year ended March 31, 2014, doubtful accounts expense of $0.4 million was recognized as an offset to optimization revenue as a result of doubtful accounts on trade accounts receivable as of March 31, 2014 (March 31, 2013—$nil).
	The Company analyzes the financial condition of counterparties prior to entering into an agreement. Credit limits are established and monitored on an ongoing basis. Management believes based on its credit policies, that the Company's financial position, results of operations and cash flows will not be materially affected as a result of non-performance by any single counterparty. Although the Company relies on a few counterparties for a significant portion of its revenues (Note 23), one counterparty, making up 56%, 28% and 40% of total revenue during the years ended March 31, 2014, 2013 and 2012, is a physical natural gas clearing and settlement facility which requires counterparties to post margin deposits which reduces the risk of default.
	Exchange traded futures and options comprise approximately 68.6% of Niska Partners' commodity risk management assets at March 31, 2014. These exchange traded contracts have minimal credit exposure as the exchanges guarantee that every contract will be margined on a daily basis. In the event of any default, Niska Partners' account on the exchange would be absorbed by other clearing members. Because every member posts an initial margin, the exchange can protect the exchange members if or when a clearing member defaults.
	Included in the fair value of energy contracts at March 31, 2014 and 2013 are one to five year contracts to sell natural gas to customers in retail markets. Niska Partners has recorded reduction in the fair value of these contracts of $nil million at March 31, 2014 (March 31, 2013—$1.0 million), representing an estimate of the expected credit exposure from these counterparties over their contractual lives.
	Interest rate risk
	The Company assesses interest rate risk by continually identifying and monitoring changes in interest rate exposures that may adversely impact expected future cash flows. At March 31, 2014, the Company was exposed to interest rate risk resulting from its variable rate revolving credit facilities, which can be drawn up to $400.0 million. At March 31, 2014, $119.5 million was outstanding on the credit facilities and Niska Partners had exposure to interest rate fluctuations.
	Niska Partners had no interest rate swap or swaption agreements at March 31, 2014 and March 31, 2013.
	Liquidity risk
	Liquidity risk is the risk that Niska Partners will not be able to meet its financial obligations as they become due. The Company's approach to managing liquidity risk is to contract a substantial part of its facilities to generate constant cash flow and to ensure that it always has sufficient cash and credit facilities to meet its obligations when due, under both normal and stressed conditions, without incurring unacceptable losses or damage to its reputation. See Note 7 for details of the Company's debt.
	Foreign currency risk
	Foreign currency risk is created by fluctuations in foreign exchange rates. As Niska Partners' Canadian subsidiaries conduct a portion of their activities in Canadian dollars, earnings and cash flows are subject to currency fluctuations. The performance of the Canadian dollar relative to the U.S. dollar could positively or negatively affect earnings. Niska Partners is exposed to cash flow risk to the extent that Canadian currency outflows do not match inflows. Niska Partners enters into currency swaps to mitigate the impact of changes in foreign exchange rates. The notional value of currency swaps as at March 31, 2014 was $13.0 million (March 31, 2013—$84.0 million). These contracts expire on various dates between April 2014 and June 2016. Niska Partners did not elect hedge accounting treatment and therefore changes in fair value are recorded directly into earnings under the optimization revenue caption of the statements of earnings (loss) and comprehensive income (loss).

Fair_Value_Measurements

Fair Value Measurements	12 Months Ended
	Mar. 31, 2014
Fair Value Measurements	'
Fair Value Measurements	'
	13. Fair Value Measurements
	The following table shows the fair values of the Company's risk management assets and liabilities:
	As at March 31, 2014	Energy			Currency			Total
		Contracts			Contracts
	Short-term risk management assets	$	18,939		$	2,010		$	20,949
	Long-term risk management assets		4,260			546			4,806
	Short-term risk management liabilities		(18,945	)		(160	)		(19,105	)
	Long-term risk management liabilities		(12,209	)		—			(12,209	)
		$	(7,955	)	$	2,396		$	(5,559	)
	As at March 31, 2013	Energy			Currency			Total
		Contracts			Contracts
	Short-term risk management assets	$	20,383		$	776		$	21,159
	Long-term risk management assets		6,593			—			6,593
	Short-term risk management liabilities		(19,792	)		(213	)		(20,005	)
	Long-term risk management liabilities		(4,477	)		(97	)		(4,574	)
		$	2,707		$	466		$	3,173
	Information about the Company's risk management assets and liabilities that had netting or rights of offset arrangements are as follows:
	As at March 31, 2014	Gross Amounts			Gross Amounts			Net Amounts			Margin			Net Amounts
		Recognized			Offset in the			Presented in			Deposits not
					Balance Sheet			the Balance			Offset in the
								Sheet			Balance Sheet
	Assets
	Commodity derivatives	$	113,175		$	(89,976	)	$	23,199		$	(15,101	)	$	8,098
	Currency derivatives		2,851			(295	)		2,556			(2,556	)		—
	Total assets		116,026			(90,271	)		25,755			(17,657	)		8,098
	Liabilities
	Commodity derivatives		121,130			(89,976	)		31,154			(21,705	)		9,449
	Currency derivatives		455			(295	)		160			(160	)		—
	Total liabilities		121,585			(90,271	)		31,314			(21,865	)		9,449
	Net	$	(5,559	)	$	—		$	(5,559	)	$	4,208		$	(1,351	)
	As at March 31, 2013	Gross Amounts			Gross Amounts			Net Amounts			Margin			Net Amounts
		Recognized			Offset in the			Presented in			Deposits not
					Balance Sheet			the Balance			Offset in the
								Sheet			Balance Sheet
	Assets
	Commodity derivatives	$	88,682		$	(61,706	)	$	26,976		$	(15,030	)	$	11,946
	Currency derivatives		881			(105	)		776			(776	)		—
	Total assets		89,563			(61,811	)		27,752			(15,806	)		11,946
	Liabilities
	Commodity derivatives		85,975			(61,706	)		24,269			(16,861	)		7,408
	Currency derivatives		415			(105	)		310			(164	)		146
	Total liabilities		86,390			(61,811	)		24,579			(17,025	)		7,554
	Net	$	3,173		$	—		$	3,173		$	1,219		$	4,392
	The following amounts represent the Company's expected realization into earnings for derivative instruments, based upon the fair value of these derivatives as of March 31, 2014:
	Fiscal year ending March 31,	Energy			Currency			Total
		Contracts			Contracts
	2015	$	(6	)	$	1,850		$	1,844
	2016 and beyond		(7,949	)		546			(7,403	)
		$	(7,955	)	$	2,396		$	(5,559	)
	Net realized and unrealized optimization gains and losses from the settlement of risk management contracts are summarized as follows:
		Year ended March 31,
		2014			2013			2012			Classification
	Energy contracts
	Realized	$	(78,778	)	$	41,304		$	59,264		Optimization, net
	Unrealized		(10,662	)		(90,641	)		77,132		Optimization, net
	Currency contracts
	Realized		3,177			1,377			(6,064	)	Optimization, net
	Unrealized		1,930			790			6,027		Optimization, net
		$	(84,333	)	$	(47,170	)	$	136,359
	The carrying amount of cash and cash equivalents, margin deposits, trade receivables, accrued receivables, trade payables and accrued liabilities reported on the consolidated balance sheet approximate fair value.
	Fair values have been determined as follows for the Company's financial assets and liabilities that were accounted for or disclosed at fair value on a recurring basis as of March 31, 2014 and 2013:
	As at March 31, 2014	Level 1			Level 2			Level 3			Total
	Assets
Commodity derivatives	$	—		$	23,199		$	—		$	23,199
Currency derivatives		—			2,556			—			2,556
Total assets	$	—		$	25,755		$	—		$	25,755
Liabilities
Commodity derivatives	$	—		$	31,154		$	—		$	31,154
Currency derivatives		—			160			—			160
Long-term debt		—			570,700			—			570,700
Total liabilities	$	—		$	602,014		$	—		$	602,014
As at March 31, 2013	Level 1			Level 2			Level 3			Total
Assets
Commodity derivatives	$	—		$	26,976		$	—		$	26,976
Currency derivatives		—			776			—			776
Total assets	$	—		$	27,752		$	—		$	27,752
Liabilities
Commodity derivatives	$	—		$	24,269		$	—		$	24,269
Currency derivatives		—			310			—			310
Long-term debt		—			669,500			—			669,500
Total liabilities	$	—		$	694,079		$	—		$	694,079
The Company's financial assets and liabilities recorded at fair value on a recurring basis have been categorized as Level 2. The determination of the fair value of assets and liabilities for Level 2 valuations is generally based on a market approach. The key inputs used in Niska Partners' valuation models include transaction-specific details such as notional volumes, contract prices, and contract terms as well as forward market prices and basis differentials for natural gas obtained from third-party service providers (typically the New York Mercantile Exchange, or NYMEX). There were no changes in Niska Partners' approach to determining fair value and there were no transfers out of Level 2 during the three-year period ended March 31, 2014.
The fair value of debt is the estimated amount the Company would have to pay to transfer its debt, including any premium or discount attributable to the difference between the stated interest rate and market rate of interest at the balance sheet date. Fair values are supported by observable market transactions when available.
In accordance with authoritative guidance, non-financial assets and liabilities could be remeasured at fair value on a non-recurring basis. As of March 31, 2014 and 2013, there were no non-financial assets and liabilities recorded at fair value.

Members_Equity

Members' Equity	12 Months Ended
	Mar. 31, 2014
Members' Equity	'
Members' Equity	'
	14. Members' Equity
	Equity restructuring
	As described in Note 1, the Company completed an equity restructuring on April 2, 2013 to eliminate its subordinated units and previous IDRs in exchange for new IDRs. This was accounted for as an exchange of equity between the subordinated unitholder and the Managing Member.
	Distribution Reinvestment Plan
	Niska Partners filed a registration statement with the SEC to authorize the issuance of up to 7,500,000 common units in connection with a distribution reinvestment plan ("DRIP"). The DRIP provides unitholders of record and beneficial owners of common units a voluntary means by which unitholders can increase the number of common units owned by reinvesting the quarterly cash distributions unitholders would otherwise receive in the purchase of additional common units. This registration statement became effective on July 31, 2013. Common units purchased under the DRIP will come from the Company's authorized but unissued common units or from common units purchased on the open market.
	During the year ended March 31, 2014, Unitholders, substantially all of which were represented by the Carlyle/Riverstone Funds, elected to participate in the DRIP and were issued 1,252,815 common units in lieu of receiving cash distributions of $18.3 million.
	At-The-Market Program
	On October 30, 2013, Niska Partners filed a prospectus supplement with the SEC to authorize an At-The-Market program which allows the issuance of up to $75.0 million in additional common units. The units will be issued pursuant to the Company's Shelf Registration Statement on Form S-3. As of March 31, 2014, the Company had not yet issued any units under this registration statement.
	Limited Liability
	No member of Niska Partners will be obligated personally for any obligation of the Company solely by reason of being a member.
	Under certain circumstances, unitholders may have to repay amounts wrongfully returned or distributed to them. Under Section 18-607 of the Delaware Limited Liability Company Act, or the Delaware Act, Niska Partners may not make a distribution to unitholders if the distribution would cause our liabilities to exceed the fair value of our assets. Delaware law provides that for a period of three years from the date of an impermissible distribution, members who received the distribution and who knew at the time of the distribution that it violated Delaware law will be liable to the limited liability company for the distribution amount. A purchaser of common units will be liable for the obligations of the transferor to make contributions to us that are known to such purchaser at the time it became a member and for unknown obligations if the liabilities could be determined from the Company's Operating Agreement.
	Summary of changes in Managing Member, Common, and Subordinated units:
	The following is a reconciliation of units outstanding for the period indicated:
		Common			Subordinated			Total
		Unitholders			Unitholders
	Units outstanding at March 31, 2011		33,804,745			33,804,745			67,609,490
	Units issued August 24, 2011		687,500			—			687,500
	Units outstanding at March 31, 2012 and 2013		34,492,245			33,804,745			68,296,990
	Subordinated units cancelled April 2, 2013		—			(33,804,745	)		(33,804,745	)
	Units issued under the DRIP		1,252,815			—			1,252,815
	Units outstanding at March 31, 2014		35,745,060			—			35,745,060
	On August 24, 2011, the Company completed the issuance and sale 687,500 common units at a price of $16.00 per unit to Sponsor Holdings. Total proceeds of $11.0 million were used to reduce amounts owing under the 8.875% Senior Notes.
	Managing Member units
	The managing member units are held by Niska Gas Storage Management LLC, (the "Managing Member" or the "Manager"), which has a 1.91% managing member interest in Niska Partners. The operating agreement provides that the managing member interest entitles the manager the right to receive distributions of Available Cash (as defined in the operating agreement) each quarter.
	The Manager has sole responsibility for conducting the Company's business and for managing its operations. Pursuant to the operating agreement, the manager has delegated the power to conduct Niska Partners' business and manage its operations to the Company's board of directors, all of the members of which are appointed by the manager.
	The Manager has agreed not to withdraw voluntarily prior to March 31, 2020 subject to certain conditions outlined in the operating agreement. Prior to that time, the manager may not be removed unless that removal is approved by the vote of the holders of not less than 662/3% of the outstanding units, voting together as a single class, including units held by the manager and its affiliates. Any removal of the manager is also subject to the approval of a successor manager by the vote of the holders of a majority of the outstanding common units and notional subordinated units, voting as separate classes. The ownership of more than 331/3% of the outstanding units by the manager and its affiliates gives them the ability to prevent the manager's removal. At March 31, 2014, Sponsor Holdings, which is an affiliate of the manager, owned approximately 51.04% of the outstanding common and 100% of the notional subordinated units. At any time, the owners of the manager may sell or transfer all or part of their ownership interests in the manager to an affiliate or a third-party without the approval of the unitholders.
	Common units
	The common units are a class of non-managing membership interests in Niska Partners. The holders of the common units are entitled to participate in the Company's distributions and exercise the rights and privileges available to members under the Company's operating agreement. The operating agreement provides that, during the subordination period, the common unitholders have the right to receive distributions of Available Cash (as defined in the operating agreement) each quarter in an amount equal to $0.35 per common unit (the "Minimum Quarterly Distribution"), plus any arrearages in the payment of the Minimum Quarterly Distribution.
	Subordinated units
	All of the subordinated units were held by Sponsor Holdings.
	On April 2, 2013, the Company completed an equity restructuring which permanently eliminated Niska Partners' subordinated units and previous incentive distribution rights in return for the new IDRs. However, for a period of five years, and provided that the Carlyle/Riverstone Funds continue to own a majority of both the managing member and the new IDRs, the Carlyle/Riverstone Funds will be deemed to own 33.8 million "Notional Subordinated Units" in connection with votes to remove and replace the managing member. These Notional Subordinated Units are not entitled to distributions, but preserve the Carlyle/Riverstone Fund's voting rights with respect to removal of the managing member.
	Acquisition of Assets from Parent
	On December 20, 2011 Niska Partners purchased certain assets from companies that are all effectively owned by the same parent company as Niska Partners. As the transaction was completed between entities under common control the assets have been recorded at the parent's carrying value and the difference between the carrying value and the amount of proceeds transferred to the parent has been recognized in equity. Please refer to Note 18—Related Party Transactions for details.
	Acquisition of Interest in Parent
	Sponsor Holdings is wholly-owned, directly and indirectly, by Niska Holdings L.P ("Niska Holdings Canada"). Niska Holdings Canada's equity consists of Class A and Class B units. Niska Holdings Canada's Class A Units are owned principally by Carlyle/Riverstone Global Energy and Power Fund III, L.P. and Carlyle/Riverstone Global Energy and Power Fund II, L.P. and affiliated entities (together, the "Carlyle/Riverstone Funds") and certain current and former members of Niska Partners' management. The Class B units are owned by certain current and former members of Niska Partners' management and non-executive employees. The Class B units were originally issued by Niska Predecessor in conjunction with a long-term incentive plan and were subject to service and performance conditions, all of which were satisfied in May 2009. The Class B units were, therefore, fully vested. Niska Predecessor had previously recorded compensation expense with respect to the Class B units throughout the vesting period. Upon vesting and the holders of the units being exposed to the risks and rewards of ownership for a reasonable period of time, the compensation arrangement became equity classified.
	On June 24, 2011, certain Class B units of Niska Holdings Canada held by non-executive employees were purchased by Niska Partners at fair value. The aggregate purchase price of $2.2 million was recorded as a reduction of equity in the accompanying financial statements, with no gain or loss recognized.
	The Class B units represent profit interests in Niska Holdings Canada, and entitle the holders to share in distributions made by Niska Holdings Canada once the Class A units have received distributions equal to their contributed capital plus an 8% cumulative rate of return. The Class B units held by Niska Partners do not currently participate in the earnings of or distributions paid by Niska Partners.
	Phantom Unit Performance Plan (the "PUPP")
	Effective April 1, 2011, the Company implemented two compensatory PUPP plans to provide long-term incentive compensation for certain employees, consultants and directors and to align their economic interest with those of common unitholders.
	A Phantom Unit is a notional unit granted under the PUPP that represents the right to receive a cash payment equal to the fair market value of a unit of the Company's common units, following the satisfaction of certain time periods and/or certain performance criteria. Phantom Units are granted unvested and subject to both time and performance conditions. The default time period over which a Phantom Unit vests is three years from the date of grant. The performance measure is based upon distributed cash flow ("DCF") and total unitholder return ("TUR") metrics compared to such metrics of a select group of peer companies to the Company. The DCF and TUR metrics are calculated based on the Company's percentile ranking during the applicable performance period compared to a peer group. Provided that the Company has satisfied its minimum quarterly distribution targets for the underlying units, the Phantom Units will vest variably according to the Company's performance relative to its peer group.
	The plan was amended effective April 1, 2012. The performance measure for Phantom Units granted after that date is based on total unitholder return ("TUR") metrics compared to such metrics of a select group of peer companies to the Company. The TUR metrics are calculated based on the Company's percentile ranking during the applicable performance period compared to a peer group. Provided that the Company has satisfied its minimum quarterly distribution targets for the common units, the Phantom Units will vest variably according to the Company's performance relative to its peer group.
	The Plans are administered by the Compensation Committee of the Board of Directors. The Plans currently permit the grant of unit awards, restricted units, phantom units, unit options, unit appreciation rights, other unit-based awards, distribution equivalent rights and substitution awards covering an aggregate of 3,380,474 units. As of March 31, 2014, 1,483,708 units (March 31, 2013—2,045,693 units) were available for grant.
	The following tables summarize the Company's Phantom Units outstanding and nonvested Phantom Units as of March 31, 2014:
		Number of			Number of			Total Units
		Time-			Performance-
		Based Units			Based Units
	Phantom Units outstanding—March 31, 2013		624,518			307,489			932,007
	Granted		219,018			219,018			438,036
	Exercised		(61,498	)		(61,498	)		(122,996	)
	Forfeited		(24,718	)		(23,719	)		(48,437	)
	Distribution equivalent rights		78,040			45,910			123,950
	Phantom Units outstanding—March 31, 2014		835,360			487,200			1,322,560
		Number of			Number of			Total Units
		Time-			Performance-
		Based Units			Based Units
	Nonvested Phantom Units—March 31, 2013		563,020			245,991			809,011
	Granted		219,018			219,018			438,036
	Vested		(368,502	)		(174,436	)		(542,938	)
	Forfeited		(24,718	)		(23,719	)		(48,437	)
	Distribution equivalent rights		78,040			45,910			123,950
	Nonvested Phantom Units—March 31, 2014		466,858			312,764			779,622
	As of March 31, 2014, there was $5.9 million of total unrecognized compensation cost related to nonvested Phantom Units granted that were subject to both time and performance conditions. That cost was expected to be recognized of over the next two years.
	Information on weighted average unit price at grant date and number of Phantom Units granted follows:
	Year ended March 31,
	2014			2013			2012
Weighted average price per unit at grant date	$	12.68		$	9.99		$	21.95
Number of Phanton Units Granted		438,036			695,349			518,425
Unit-based compensation costs for the year ended March 31, 2014 were $11.2 million (March 31, 2013—$7.0 million; March 31, 2012—$0.5 million). Cash paid to employees who exercised their Phantom Units for the years ended March 31, 2014, 2013 and 2012 was $2.3 million, $ nil and $ nil, respectively.
Incentive distribution rights
IDRs are a separate interest and represent participating securities. The new IDRs entitle the Carlyle/Riverstone Funds to receive 48% of any quarterly cash distributions after Niska Partners' common unitholders have received the full minimum quarterly distribution ($0.35 per unit) for each quarter plus any arrearages from prior quarters (of which there are currently none). The previous incentive distribution rights entitled the Carlyle/Riverstone Funds to receive increasing percentages (ranging from 13% to 48%) of incremental cash distributions after the unitholders (both common and subordinated) exceeded quarterly distributions ranging from $0.4025 per unit to $0.5250 per unit. To date, the Company has not made any payments with respect to the previous incentive distribution rights or the new IDRs.
Within 45 days after the end of each quarter Niska Partners may make cash distributions to the members of record on the applicable record date. Niska Partners distributed $52.3 million and $51.3 million to the holders of common units and the Managing Member during the years ended March 31, 2014 and 2013, respectively.
Earnings per unit
Niska Partners uses the two-class method for allocating earnings per unit. The two-class method requires the determination of net income allocated to member interests as shown below. Net earnings (loss) for the year ended March 31, 2014, after the allocation to Managing Member's interest, was only attributable to common unitholders as a result of cancellation of the Company's subordinated units at the beginning of the current fiscal year. The cancellation of subordinated units has not impacted the prior-period calculation of earnings per unit.
	Year ended March 31,
	2014			2013			2012
Numerator:
Net earnings (loss) attributable to Niska Partners	$	(8,957	)	$	(43,601	)	$	(165,772	)
Less:
Managing Member's interest		171			863			3,283
Net earnings (loss) attributable to common and subordinated unitholders	$	(8,786	)	$	(42,738	)	$	(162,489	)
Denominator:
Basic:
Weighted average units outstanding		34,941,036			68,296,990			68,010,532
Diluted:
Weighted average units outstanding		34,941,036			68,296,990			68,010,532
Earnings (loss) per unit allocated to common unitholders—basic and diluted	$	(0.25	)	$	(0.63	)	$	(2.39	)
Earnings (loss) per unit allocated to subordinated unitholders—basic and diluted	$	—		$	(0.63	)	$	(2.39	)

Revenues

Revenues	12 Months Ended
	Mar. 31, 2014
Revenues	'
Revenues	'
	15. Revenues
	Niska Partners' fee-based revenue consists of the following:
		Year ended March 31
		2014			2013			2012
	Long-term contract revenue	$	83,940		$	108,615		$	116,244
	Short-term contract revenue		51,416			54,710			29,809
		$	135,356		$	163,325		$	146,053
	Optimization, net consists of the following:
		Year ended March 31,
		2014			2013			2012
	Realized optimization, net	$	85,372		$	89,525		$	62,735
	Unrealized risk management (loss)
	gains (Notes 12 and 13)		(8,732	)		(89,874	)		83,193
	Write-down of inventory		(4,600	)		(22,281	)		(23,400	)
		$	72,040		$	(22,630	)	$	122,528

Interest

Interest	12 Months Ended
	Mar. 31, 2014
Interest	'
Interest	'
	16. Interest
	The following table presents a reconciliation of interest expense:
		Year ended March 31,
		2014		2013			2012
	Gross interest	$	62,961	$	66,527		$	74,765
	Deferred charges amortization		3,354		3,411			3,942
	Capitalized interest		—		(2,928	)		(4,077	)
		$	66,315	$	67,010		$	74,630

Loss_on_extinguishment_of_debt

Loss on extinguishment of debt	12 Months Ended
	Mar. 31, 2014
Loss on extinguishment of debt	'
Loss on extinguishment of debt	'
	17. Loss on extinguishment of debt
	Loss on extinguishment of debt consists of the following:
		Year ended March 31,
		2014		2013		2012
	Premiums paid on redemption / repurchase of
	8.875% Senior Notes	$	28,572	$	—	$	1,770
	Deferred charges written off		8,125		599		3,091
		$	36,697	$	599	$	4,861

Related_Party_Transactions

Related Party Transactions	12 Months Ended
	Mar. 31, 2014
Related Party Transactions	'
Related Party Transactions	'
	18. Related Party Transactions
	There were no amounts owing to or from related parties as at March 31, 2014 and 2013.
	During the year ended March 31, 2014, Niska Partners recognized management fees amounting $0.2 million (March 31, 2013—$0.2 million; March 31, 2012—$0.9 million). Management fees are charged, on an arms-length basis, to affiliated entities for certain administrative services rendered and are recorded as a reduction of general and administrative costs.
	During the year ended March 31, 2014, the Carlyle/Riverstone Funds elected to participate in the DRIP and were issued 1,252,810 common units in lieu of receiving cash distributions of $18.3 million.
	During the year ended March 31, 2012, Niska Partners purchased the net assets of Starks Gas Storage LLC, Coastal Bend Gas Storage LLC, and Sundance Gas Storage ULC from Sponsor Holdings Cooperatief U.A. and from R/C Sundance Cooperatief U.A. for consideration of $5.0 million. Niska Partners, Sponsor Holdings Cooperatief U.A. and R/C Sundance Cooperatief U.A. are all effectively owned by the same parent company. As a result, the transactions between entities under common control have been recorded at the parent's carrying value and the difference between the carrying value and the amount of proceeds transferred to the parent has been recognized in equity.
	During the year ended March 31, 2012, a subsidiary of Niska Partners purchased certain Class B units of Niska Holdings Canada from certain non-executive officers and employees of Niska Partners for $2.2 million. The amount has been reflected as a reduction of members' equity.
	On August 24, 2011, the Company completed the issuance and sale of 687,500 common units at a price of $16.00 per unit to Sponsor Holdings. Total proceeds of $11.0 million were used to reduce amounts owing under the 8.875% Senior Notes.

Commitments_and_Contingencies

Commitments and Contingencies	12 Months Ended
	Mar. 31, 2014
Commitments and Contingencies	'
Commitments and Contingencies	'
	19. Commitments and Contingencies
	Contingencies
	The Company and its subsidiaries are subject to various legal proceedings and actions arising in the normal course of business. While the outcome of such legal proceedings and actions cannot be predicted with certainty, it is the opinion of Management that the resolution of such proceedings and actions will not have a material impact on the Company's consolidated financial position or results of operations.
	Commitments
	Niska Partners has entered into non-cancelable operating leases for office space, leases for land use rights at its operating facilities, storage capacity at other facilities, equipment, and vehicles used in its operations. The remaining lease terms expire between April 2014 and August 2056 and provide for the payment of taxes, insurance and maintenance by the lessee. A renewal option exists on the office space lease to extend the term for another five years, exercisable prior to the termination of the original lease.
	The related future minimum lease payments at March 31, 2014 were as follows:
	For the fiscal year ending:	Operating
		leases
	2015	$	11,837
	2016		8,937
	2017		8,483
	2018		6,142
	2019		5,512
	2020 and thereafter		183,151
	Total minimum lease payments	$	224,062
	The minimum lease payments disclosed in the above table have not been reduced by the total of minimum rentals to be received in the future under non-cancelable subleases as of March 31, 2014 of $2.6 million. Consolidated lease and rental expense, net of sublease recoveries of $0.9 million, amounted to $11.9 million for the year ended March 31, 2014 (March 31, 2013—$11.2 million; March 31, 2012—$14.9 million). During the year ended March 31, 2014, lease and rental expense included contingent rent amounting to $0.4 million (March 31, 2013—$0.3 million; March 31, 2012—$0.7 million). Where applicable, contingent rent is due whenever a certain percentage of revenue exceeds minimum lease costs.
	Purchase obligations arising as a result of forward purchase contracts in place at March 31, 2014 were as follows:
	For the fiscal year ending:	Unconditional
		purchase
		obligations
	2015	$	2,783,323
	2016		278,380
	2017		65,873
	2018		241,193
	2019		1,477
	2020 and thereafter		—
	Total future purchase commitments	$	3,370,246
	Purchase obligations consisted of forward physical and financial commitments related to future purchases of natural gas. As the Company economically hedges substantially all of its natural gas purchases, there are forward sales that offset these commitments that are not included in the above table. As at March 31, 2014, forward physical and financial sales for all future periods totaled $3,361.1 million.
	As at March 31, 2014, the Company had $4.8 million of issued and outstanding letters of credit to various counterparties to support natural gas purchase commitments.

Changes_in_NonCash_Working_Cap

Changes in Non-Cash Working Capital	12 Months Ended
	Mar. 31, 2014
Changes in Non-Cash Working Capital	'
Changes in Non-Cash Working Capital	'
	20. Changes in Non-Cash Working Capital
	Changes in non-cash working capital include:
		Year ended March 31,
		2014			2013			2012
	Margin deposits	$	(14,137	)	$	(39,174	)	$	99,804
	Trade receivables		(3,383	)		(286	)		(45	)
	Accrued receivables		(44,459	)		(40,203	)		9,938
	Natural gas inventory		3,676			125,042			(120,563	)
	Prepaid expenses and other current assets		358			(1,527	)		2,669
	Other assets		(807	)		(1,105	)		(1,637	)
	Trade payables		(149	)		645			(316	)
	Accrued liabilities		68,108			8,456			(53,036	)
	Income taxes		8			(693	)		(579	)
	Deferred revenue		5,468			(10,667	)		6,498
	Due from related party		(10	)		1,164			732
	Other long-term liabilities		360			381			115
	Net changes in non-cash working capital	$	15,033		$	42,033		$	(56,420	)
	During the year ended March 31, 2013, changes in non-cash working capital include the receipt of proceeds of $32.6 million (March 31, 2014—$ nil; March 31, 2012—$ nil) from sales of cushion. The Company included such proceeds in cash flows from operations since the predominant source of cash flows for natural gas purchases and sales are operating in nature.

Supplemental_Cash_Flow_Disclos

Supplemental Cash Flow Disclosures	12 Months Ended
	Mar. 31, 2014
Supplemental Cash Flow Disclosures	'
Supplemental Cash Flow Disclosures	'
	21. Supplemental Cash Flow Disclosures
		Year ended March 31,
		2014			2013			2012
	Interest paid	$	63,769		$	67,408		$	75,375
	Taxes paid (received)		73			(722	)		988
	Interest capitalized		—			2,928			4,077
	Non-cash investing activities:
	Non-cash (decrease) increase in working capital related to property, plant and equipment	$	(2,426	)	$	(8,605	)	$	11,296
	Non-cash transfer of natural gas inventory to property, plant and equipment		15,264			—			—
	Non-cash financing activities:
	Non-cash distributions and reinvestments		18,270			—			—

Segment_Disclosures

Segment Disclosures	12 Months Ended
	Mar. 31, 2014
Segment Disclosures	'
Segment Disclosures	'
	22. Segment Disclosures
	The Company's process for the identification of reportable segments involves examining the nature of services offered, the types of customer contracts entered into and the nature of the economic and regulatory environment.
	Niska Partners operates along functional lines in its commercial, engineering, and operations teams for operations in Alberta, Northern California, and the U.S. Midcontinent. All functional lines and facilities offer the same services: fee-based revenue, and optimization. The Company has a small marketing business which is an extension of the Company's proprietary optimization activities. Proprietary optimization activities occur when the Company purchases, stores and sells natural gas for its own account in order to utilize or optimize storage capacity that is not contracted or available to third party customers. All services are delivered using reservoir storage. The Company measures profitability consistently along all functional lines based on revenues and earnings before interest, taxes, depreciation and amortization, before unrealized risk management gains and losses. The Company has aggregated its operating segments into one reportable segment as at March 31, 2014 and 2013 and for each of the three years ended March 31, 2014.
	Information pertaining to the Company's short term and long term contract services and net optimization revenues is presented on the consolidated statements of earnings (loss) and comprehensive income (loss). All facilities have the same types of customers: major companies in the energy industry, industrial, commercial, and local distribution companies, and municipal energy consumers. Revenues are primarily attributed to the geographic area based on where services are provided or the natural gas is sold.
	The following tables summarize the net revenues and assets by geographic area:
		Year ended March 31,
		2014			2013			2012
	Net realized revenues
	U.S.	$	57,628		$	70,161		$	70,928
	Canada		158,500			160,408			114,460
	Net unrealized revenues
	U.S.		142			(37,139	)		30,489
	Canada		(8,874	)		(52,735	)		52,704
	Inter-entity
	U.S.		—			—			—
	Canada		—			—			—
		$	207,396		$	140,695		$	268,581
	Long-lived assets (at year-end)
	U.S.	$	397,331		$	411,420
	Canada		839,917			858,604
		$	1,237,248		$	1,270,024

Economic_Dependence

Economic Dependence	12 Months Ended
	Mar. 31, 2014
Economic Dependence	'
Economic Dependence	'
	23. Economic Dependence
	Niska Partners' exposure to the volume of business transacted with a natural gas clearing and settlement facility is described in Note 12. While the clearing and settlement facility is its direct counterparty, its risk exposure to dependence on this counterparty is mitigated through the large number of members of the clearing and settlement facility who create the demand for these transactions.
	During fiscal 2014, Niska Partners did not have any other customers comprise greater than 10% of total gross revenue (2013—none, 2012—none).

Subsequent_Events

Subsequent Events	12 Months Ended
	Mar. 31, 2014
Subsequent Events	'
Subsequent Events	'
	24. Subsequent Events
	Execution of new Storage Agreement
	On May 1, 2014, the Company and its largest volumetric customer, TransCanada Gas Storage Partnership ("TransCanada"), executed a storage service agreement which replaced its pre-existing storage agreement which contained an option to terminate effective April 1, 2015. The previous agreement provided TransCanada with approximately 40 Bcf of storage capacity at the Company's AECO facility and had a term that extended to 2030. Either party had an option to terminate at the end of every five-year interval. TransCanada elected to terminate this agreement and entered into a new agreement which extends until 2020. The new agreement provides for an initial capacity of 40 Bcf which will be reduced to 20 Bcf on April 1, 2017. By terminating the prior agreement, TransCanada became obligated to make an early termination payment.
	As a result of the execution of the new contract, Niska Partners has revised the amortization of its intangible assets to reflect the new pattern in which the cash flows from the intangible assets, which is substantially in excess of the carrying value, are generated.
	Distributions
	Subsequent to year-end Niska Partners declared and paid distributions to its common unitholders totaling $12.8 million. The Carlyle/Riverstone Funds reinvested all of their distributions and received an additional 445,144 common units through the DRIP in lieu of receiving cash distributions of $6.4 million.

Quarterly_Financial_Data

Quarterly Financial Data	12 Months Ended
	Mar. 31, 2014
Quarterly Financial Data	'
Quarterly Financial Data	'
	25. Quarterly Financial Data
	Quarterly results are influenced by the seasonal and other factors inherent in Niska Partners' business. The following table summarizes the quarterly financial data for the years ended March 31, 2014 and 2013:
		First			Second			Third			Fourth			Year ended
		Quarter			Quarter			Quarter			Quarter			March 31,
		(unaudited)			(unaudited)			(unaudited)			(unaudited)
	Fiscal 2014
	Revenue, net	$	57,189		$	36,863		$	25,847		$	87,497		$	207,396
	Earnings (loss) before income taxes	$	7,667		$	(7,797	)	$	(19,718	)	$	635		$	(19,213	)
	Net earnings (loss) and comprehensive income (loss)	$	7,967		$	(7,845	)	$	(13,409	)	$	4,330		$	(8,957	)
	Earnings (loss) per unit	$	0.23		$	(0.22	)	$	(0.37	)	$	0.12		$	(0.25	)
	Fiscal 2013
	Revenue, net	$	(2,787	)	$	24,545		$	73,831		$	45,106		$	140,695
	Earnings (loss) before income taxes	$	(49,287	)	$	(22,115	)	$	9,877		$	(1,018	)	$	(62,543	)
	Net earnings (loss) and comprehensive income (loss)	$	(37,346	)	$	(15,397	)	$	10,419		$	(1,277	)	$	(43,601	)
	Earnings (loss) per unit	$	(0.54	)	$	(0.22	)	$	0.15		$	(0.02	)	$	(0.63	)
	The Company recognized loss on extinguishment of debt of $36.7 million and wrote down proprietary inventories by $4.6 million in the fourth quarter of fiscal 2014. During the first quarter of fiscal 2013, the Company wrote down proprietary inventories by $22.3 million.

Significant_Accounting_Policie1

Significant Accounting Policies (Policies)	12 Months Ended
	Mar. 31, 2014
Significant Accounting Policies	'
Basis of presentation	'
	Basis of presentation
	These consolidated financial statements have been prepared to reflect the consolidated financial position, results of operations and cash flows of Niska Partners and its subsidiaries and have been prepared in accordance with accounting principles generally accepted in the United States of America ("GAAP").
	These financial statements include the accounts of Niska Partners and its wholly-owned subsidiaries, including AECO Gas Storage Partnership, Wild Goose Storage LLC, Niska Gas Storage, LLC, Salt Plains Storage, LLC, Access Gas Services Inc., Access Gas Services (Ontario) Inc., EnerStream Agency Services Inc., and Niska Partners Management ULC. All material intercompany transactions have been eliminated.
Use of estimates	'
	Use of estimates
	In preparing these financial statements, Niska Partners is required to make estimates and assumptions that affect both the amount and timing of recording assets, liabilities, revenues and expenses since the determination of these items may be dependent on future events. Management uses the most current information available and exercises careful judgment in making these estimates. Although management believes that these consolidated financial statements have been prepared within limits of materiality and within the framework of its significant accounting policies summarized below, actual results could differ from these estimates. Changes in estimates are accounted for on a prospective basis.
Revenue recognition	'
	Revenue recognition
	The Company's assessment of each of the four revenue recognition criteria as they relate to its revenue producing activities is as follows:
	Persuasive evidence of an arrangement exists.    The Company's customary practices are to enter into a written contract, executed by both the customer and the Company.
	Delivery.    Delivery is deemed to have occurred at the time the natural gas is delivered and title is transferred, or in the case of fee-based arrangements, when the services are rendered. To the extent the Company retains its inventory, delivery occurs when the inventory is subsequently sold and title is transferred to the third-party purchaser.
	The fee is fixed or determinable.    The Company negotiates the fee for its services at the outset of their fee-based arrangements. In these arrangements, the fees are nonrefundable. The fees are generally due on the 25th of the month following the delivery or services rendered. For other arrangements, the amount of revenue is determinable when the sale of the applicable product has been completed upon delivery and transfer of title.
	Collectability is reasonably assured.    Collectability is evaluated on a customer-by-customer basis. New and existing customers are subject to a credit review process, which evaluates the customers' financial position (e.g. cash position and credit rating) and their ability to pay. If collectability is not considered reasonably assured at the outset of an arrangement in accordance with the Company's credit review process, revenue is recognized when the fee is collected.
	Fee-based revenue consists of long-term contracts for storage fees that are generated when we lease storage capacity on a monthly basis and short-term fees associated with park and loan activities. Long-term contract revenue consists of monthly storage fees and fuel and commodity charges for injections and withdrawals. Long-term contract revenue is accrued on a monthly basis in accordance with the terms of the customer contracts. Customer charges for injections and withdrawals are recorded in the month of injection or withdrawal. Short-term contract revenue consists of fees for injections and withdrawals, where the customer pays a fixed fee to inject a specified quantity of natural gas on a specified date or dates and withdraw a specified quantity of natural gas on a specified date. The fee stipulated in a short-term contract for each performance obligation (injection and withdrawal) is recognized when the service occurs.
	Energy trading contracts resulting in the delivery of a commodity where Niska Partners is the principal in the transaction are recorded as optimization revenues at the time of physical delivery. Realized and unrealized gains and losses on financial energy trading contracts are included in optimization revenue (see Note 12—Risk Management Activities and Financial Instruments).
	Optimization revenue, net includes realized gains and losses and the net change in unrealized gains and losses on financial and physical energy trading contracts. Optimization revenue results from the purchase of inventory and its forward sale to future periods through financial and physical trading contracts. These derivative contracts are economic hedges that have been entered into to manage commodity price and currency risk associated with buying and selling natural gas across future time periods (see Note 12). The Company does not designate these instruments as hedges and therefore records the unrealized gains and losses on the changes in their fair value through net earnings. Contracts resulting in the delivery of a commodity where Niska Partners is the principal in the transaction are recorded as optimization revenues at the time of physical delivery.
	Sales taxes collected from customers and remitted to governmental authorities are excluded from revenues in the consolidated statements of earnings (loss) and comprehensive income (loss).
Cash and cash equivalents	'
	Cash and cash equivalents
	Niska Partners considers all highly liquid investments purchased with an initial maturity of three months or less to be cash equivalents.
Margin deposits	'
	Margin deposits
	Cash held in margin represents the right to receive or the obligation to pay cash collateral under a master netting arrangement that has not been offset against derivative positions. These derivatives are marked-to-market daily; the profit or loss on the daily position is then paid to, or received from, the account as appropriate under the terms of the Company's contract with its broker.
Natural gas inventory	'
	Natural gas inventory
	The Company's inventory is natural gas injected into storage which is held for resale. Inventory is valued at the lower of weighted average cost or market. Adjustments to write down the costs of inventory to market are recorded as an offset to optimization revenues while costs to store the gas are recognized as operating expenses in the period the costs are incurred in the consolidated statements of earnings (loss) and comprehensive income (loss).
	Long-term inventory represents non-cycling working gas. Non-cycling working gas was injected by the Company to increase pressure within the reservoirs to allow it to market higher cycling contracts or previously un-saleable gas from an underutilized reservoir that can be sold into the market when the Company adds mechanical compression to the reservoir. This mechanical compression allows access to natural gas that was previously required to maintain pressure within the reservoir. Long-term inventory is carried at cost and is subject to an annual test for impairment.
	In March 2014, the Company reclassified the balance of its long-term natural gas inventory to cushion to reflect operational requirements.
Property, plant and equipment	'
	Property, plant and equipment
	Property, plant and equipment are recorded at cost when purchased. Depreciation is computed using the declining balance method for each category of asset using the following rates:
	Pipelines and measurement	5%
	Wells	5%
	Facilities	Between 5% and 22%
	Computer hardware and software	30%
	Office furniture and fixtures	20%
	Other	10%
	Property, plant and equipment under capital leases are depreciated using the declining balance method over the lesser of the useful lives of the assets or the lease term.
	Certain volumes of natural gas defined as cushion are required for maintaining a minimum field pressure. Cushion is considered a component of the facility and as such is not amortized. Cushion is monitored to ensure that it provides effective pressure support for the facility. In the event that gas moves to another area of the reservoir where it does not provide effective pressure support, a loss is recorded, within depreciation expense, equal to the estimated volumes that have migrated (see Note 4). Proceeds from sale of cushion are classified as operating activities in the Consolidated Statements of Cash Flows since the predominant source of cash flows for natural gas purchases and sales are operating in nature.
	Repairs, maintenance and renewals that do not extend the useful lives of the assets are expensed as incurred. Interest costs for the construction or development of long-lived assets held by operational entities are capitalized and amortized over the related asset's estimated useful life (see Note 4).
Asset retirement obligations	'
	Asset retirement obligations
	Niska Partners records a liability for an asset retirement obligation when the legal obligation to retire the asset has been incurred with an offsetting increase to the carrying value of the related tangible long-lived asset. The recognition of an asset retirement obligation requires that management make numerous estimates, assumptions and judgments regarding such factors as the estimated probabilities, amounts and timing of settlements; the credit-adjusted risk-free rate to be used; inflation rates, and future advances in technology. In periods subsequent to initial measurement of the liability, the Company must recognize changes in the liability resulting from the passage of time and revisions to either the timing or the amount of the original estimate of undiscounted cash flows. Over time, the liability is accreted to its future value, and the capitalized cost is depreciated over the useful life of the related asset. Accretion of the asset retirement obligations due to the passage of time is recorded as an expense in the statement of earnings. Upon settlement of the liability, the Company either settles the obligation for its recorded amount or incurs a gain or loss.
Netting of certain balance sheet accounts	'
	Netting of certain balance sheet accounts
	Certain risk management assets and liabilities and certain accrued gas sales and purchases are presented on a net basis in the balance sheet when all of the following exist: (i) Niska Partners and the other party owe the other a determinable amount; (ii) the Company has the right to set off the amount owed with the amount owed by the other party; (iii) Niska Partners intends to set off; and (iv) the right of setoff is enforceable by law.
Leases	'
	Leases
	Niska Partners determines a lease to be an operating or capital lease based upon the terms of the lease, estimated fair value of the leased assets, estimated life of the leased assets, and the contractual minimum lease payments as defined within the lease agreements. If the Company concludes that it has substantively all of the risks of ownership of a leased property and therefore is deemed the owner of the property for accounting purposes, it records an asset and related obligations under capital lease at the lower of the present value of the minimum lease payments or the fair value of the asset.
Impairment of long-lived assets	'
	Impairment of long-lived assets
	Niska Partners evaluates whether events or circumstances have occurred that indicate that long-lived assets may not be recoverable or that the remaining useful life may warrant revision. When such events or circumstances are present, the Company assesses the recoverability of long-lived assets by determining whether the carrying value will be recovered through the expected undiscounted future cash flows. In the event that the sum of the expected future cash flows resulting from the use of the asset is less than the carrying value of the asset, an impairment loss equal to the excess of the asset's carrying value over its fair value is recorded.
Goodwill and other intangible assets	'
	Goodwill and other intangible assets
	Niska Partners accounts for business acquisitions using the purchase method of accounting and, accordingly, the assets and liabilities of the acquired entities are recorded at their estimated fair values at the date of acquisition. The excess of the purchase price over the fair value of the net assets acquired is attributed to goodwill.
	Goodwill is not amortized and is re-evaluated on an annual basis or more frequently if events or changes in circumstances indicate that the asset might be impaired. Goodwill is tested for impairment between annual tests if an event occurs or circumstances change that would more likely than not reduce the fair value of a reporting unit below its carrying value. These events or circumstances could include a significant change in the business climate, legal factors, operating performance indicators, competition, sale or disposition of a significant portion of the business or other factors.
	To re-evaluate goodwill for impairment, the Company has the option to first assess qualitative factors to determine whether it is more likely than not that goodwill is impaired. The result of the qualitative assessment would be used as a basis in determining whether it is necessary to perform the quantitative impairment test. The performance of the quantitative impairment test involves a two-step process. The first step involves comparing the fair values of the applicable reporting units with their aggregate carrying values, including goodwill. If the carrying amount exceeds the fair value of the reporting unit, the Company performs the second step of the goodwill impairment test to determine the amount of impairment loss. The second step of the goodwill impairment test involves comparing the implied fair value of the affected reporting unit's goodwill with the carrying value of that goodwill.
	Other intangible assets represent contractual rights obtained in connection with a business combination that had favorable contractual terms relative to market as of the acquisition date.
	Intangible assets representing customer contracts are amortized over their useful lives. These assets are reviewed for impairment as impairment indicators arise. When such events or circumstances are present, the recoverability of long-lived assets is assessed by determining whether the carrying value will be recovered through the expected undiscounted future cash flows. In the event that the sum of the expected future cash flows resulting from the use of the asset is less than the carrying value of the asset, an impairment loss equal to the excess of the asset's carrying value over its fair value is recorded.
	Pipeline rights of way are formal agreements granting rights of way in perpetuity and are not subject to amortization but are subject to an annual impairment test.
Risk management activities	'
	Risk management activities
	The Company uses natural gas derivatives and other financial instruments to manage its exposure to changes in natural gas prices, and foreign exchange rates. These financial assets and liabilities, which are recorded at fair value on a recurring basis, are included in one of three categories based on a fair value hierarchy with realized and unrealized gains (losses) recognized in earnings (see Note 13).
	The fair value of the Company's derivative risk management contracts are recorded as a component of risk management assets and liabilities, which are classified as current or non-current assets or liabilities based upon the anticipated settlement date of the contracts.
Foreign currency translation	'
	Foreign currency translation
	The functional and reporting currency of the Company is the U.S. dollar. Non-U.S. dollar denominated monetary items are translated into U.S. dollars at the rate of exchange in effect at the balance sheet date. Non-U.S. dollar denominated non-monetary items are translated to U.S. dollars at the exchange rate in effect when the transaction occurred. Revenues and expenses denominated in foreign currencies are translated at the actual exchange rate or average exchange rate in effect during the period. Foreign exchange gains or losses on translation are included in income.
Deferred charges	'
	Deferred charges
	Deferred charges relate to costs incurred on the issuance of debt and are amortized over the term of the related debt to interest expense using the effective interest method for cost related to the senior notes offering and straight-line for deferred charges incurred on the revolving credit facility. Any remaining unamortized deferred charges related to repurchased senior notes or modified revolving credit facility agreements are written off on the dates of redemption or modification.
Income taxes	'
	Income taxes
	The Company is not directly a taxable entity. Income taxes on its income are the responsibility of the individual unitholders and have accordingly not been recorded in the consolidated financial statements. However, Niska Partners does own corporate subsidiaries, which are taxable corporations subject to Canadian federal and provincial income taxes, which are included in the consolidated financial statements.
	Income taxes on the Canadian corporate subsidiaries are provided based on the asset and liability method, which results in deferred income tax assets and liabilities arising from temporary differences. Temporary differences are differences between the tax basis of assets and liabilities and their reported amounts in the financial statements that will result in taxable or deductible amounts in future years. This method requires the effect of tax rate changes on current and accumulated deferred income taxes to be reflected in the period in which the rate change was enacted. The asset and liability method also requires that deferred income tax assets be reduced by a valuation allowance unless it is more likely than not that the assets will be realized.
	The Company's policy is to recognize accrued interest and penalties on accrued tax balances as components of interest expense.
	The Canadian subsidiaries remain subject to examination by Canadian federal and provincial tax jurisdictions for all years filed after 2006. The Company's unitholders, relative to the Company, remain subject to examination by US federal and state tax jurisdictions for years from 2009 and beyond.
Long term equity-based incentives	'
	Long term equity-based incentives
	Niska Partners' compensation committee approves awards of phantom units with distribution equivalent rights to certain key employees. These awards include both time-based and performance-based components.
	Unit award grants are classified as liabilities. The fair value of the units granted is determined on the date of grant and is re-measured at each reporting period until the settlement date. The fair value at each re-measurement date is equal to the settlement expected to be incurred based on the anticipated number of units vested adjusted for (1) the passage of time and (2) the payout threshold associated with the performance targets which the Company expects to achieve compared to its established peers. The pro-rata number of units vesting is calculated as the number of performance awards multiplied by the percentage of the requisite service period, plus additional units granted in lieu of the cash distributions paid on the vested units.
	Compensation expense is calculated as the re-measured expected payout less previously-recognized compensation expense.

Significant_Accounting_Policie2

Significant Accounting Policies (Tables)	12 Months Ended
	Mar. 31, 2014
Significant Accounting Policies	'
Schedule of rates used in computation of depreciation using the declining balance method for each category of asset	'
	Pipelines and measurement	5%
	Wells	5%
	Facilities	Between 5% and 22%
	Computer hardware and software	30%
	Office furniture and fixtures	20%
	Other	10%

Property_Plant_and_Equipment_T

Property, Plant and Equipment (Tables)	12 Months Ended
	Mar. 31, 2014
Property, Plant and Equipment	'
Schedule of components of property, plant and equipment	'
		As at March 31, 2014
		Cost		Accumulated			Net Book
				Depreciation			Value
	Cushion	$	421,404	$	—		$	421,404
	Pipelines and measurement		296,671		(92,687	)		203,984
	Wells		126,694		(40,700	)		85,994
	Facilities		272,645		(79,028	)		193,617
	Computer hardware and software		4,225		(3,087	)		1,138
	Construction in progress, including projects under development		1,063		—			1,063
	Office furniture, equipment and other		2,473		(1,399	)		1,074
		$	1,125,175	$	(216,901	)	$	908,274
		As at March 31, 2013
		Cost		Accumulated			Net Book
				Depreciation			Value
	Cushion	$	406,141	$	—		$	406,141
	Pipelines and measurement		296,661		(81,950	)		214,711
	Wells		126,519		(36,179	)		90,340
	Facilities		267,508		(64,238	)		203,270
	Computer hardware and software		4,095		(2,653	)		1,442
	Construction in progress, including projects under development		928		—			928
	Office furniture, equipment and other		2,473		(1,244	)		1,229
		$	1,104,325	$	(186,264	)	$	918,061

Goodwill_and_Other_Intangible_1

Goodwill and Other Intangible Assets (Tables)	12 Months Ended
	Mar. 31, 2014
Goodwill and Other Intangible Assets	'
Schedule of other intangible assets	'
		As at March 31,
		2014			2013
	Customer contracts and relationships, beginning of the year	$	163,073		$	163,073
	Additions		2,007			—
	Less accumulated amortization		(117,888	)		(107,345	)
	Customer contracts and relationships, end of the year		47,192			55,728
	Pipeline rights of way		18,270			18,270
		$	65,462		$	73,998
Schedule of actual amortization expense	'
	Amortization expense for the fiscal year ended:
	March 31, 2014	$	10,543
	March 31, 2013		11,311
	March 31, 2012		13,675
Schedule of estimated future amortization expense	'
	Future amortization expense estimated for the fiscal year ending:
	March 31, 2015	$	23,633
	March 31, 2016		5,977
	March 31, 2017		7,513
	March 31, 2018		3,558
	March 31, 2019 and thereafter		6,511

Deferred_Charges_Tables

Deferred Charges (Tables)	12 Months Ended
	Mar. 31, 2014
Deferred Charges	'
Schedule of deferred charges	'
		As at March 31,
		2014			2013
	Deferred charges—cost, beginning of the year	$	25,377		$	23,566
	Additions		11,696			3,248
	Write-offs due to extinguishment of debt		(16,995	)		—
	Write-offs due to amendment and restatement of revolving credit facility		—			(1,437	)
	Deferred charges—cost, end of the year		20,078			25,377
	Accumulated amortization, beginning of the year		(10,957	)		(8,384	)
	Amortization during the year		(3,354	)		(3,411	)
	Write-offs due to extinguishment of debt		8,873			—
	Write-offs due to amendment and restatement of revolving credit facility		—			838
	Accumulated amortization, end of the year		(5,438	)		(10,957	)
	Net book value	$	14,640		$	14,420
	Life in years		5-Mar			5-Jan
Schedule of amortization recognized as interest expense	'
	Amortization expense by period:
	March 31, 2014	$	3,354
	March 31, 2013		3,411
	March 31, 2012		3,942

Debt_Tables

Debt (Tables)	12 Months Ended
	Mar. 31, 2014
Debt	'
Schedule of debt obligations	'
		As at March 31
		2014			2013
	8.875% Senior Notes due 2018	$	—		$	643,790
	6.50% Senior Notes due 2019		575,000			—
	Revolving credit facilities		119,500			65,000
			694,500			708,790
	Less: portion classified as current		(119,500	)		(65,000	)
		$	575,000		$	643,790

Obligations_Under_Capital_Leas1

Obligations Under Capital Lease (Tables)	12 Months Ended
	Mar. 31, 2014
Obligations Under Capital Lease	'
Schedule of future principal and interest payments of obligations under capital lease	'
	For the fiscal year ending:
	March 31, 2015	$	1,657
	March 31, 2016		1,657
	March 31, 2017		1,657
	March 31, 2018		1,657
	March 31, 2019		1,657
	March 31, 2020 and thereafter		5,574
	Less: Amount representing interest		(1,634	)
		$	12,225

Accrued_Liabilities_Tables

Accrued Liabilities (Tables)	12 Months Ended
	Mar. 31, 2014
Accrued Liabilities	'
Schedule of accrued liabilities	'
		As at March 31,
		2014		2013
	Accrued gas purchases	$	75,454	$	14,213
	Employee-related accruals		22,315		13,836
	Accrued interest		2,037		2,845
	Other accrued liabilities		11,312		8,946
		$	111,118	$	39,840

Asset_Retirement_Obligations_T

Asset Retirement Obligations (Tables)	12 Months Ended
	Mar. 31, 2014
Asset Retirement Obligations	'
Schedule of asset retirement obligations	'
		Year ended
		March 31,
		2014			2013
	Balance, beginning of the year	$	2,007		$	1,554
	Additions		—			210
	Accretion		107			197
	Effect of foreign exchange translation		(139	)		46
	Balance, end of the year	$	1,975		$	2,007

Income_Taxes_Tables

Income Taxes (Tables)	12 Months Ended
	Mar. 31, 2014
Income Taxes	'
Schedule of components of the Company's earnings (loss) before income taxes (benefits)	'
		Year ended March 31,
		2014			2013			2012
	Domestic	$	16,844		$	(493	)	$	72,270
	Foreign		(36,057	)		(62,050	)		(257,729	)
		$	(19,213	)	$	(62,543	)	$	(185,459	)
Schedule of total income tax expense (benefit) differed from the amounts computed by applying the tax rate to earnings (loss) before income taxes	'
		Year ended March 31,
		2014			2013			2012
	Net earnings (loss) before taxes	$	(19,213	)	$	(62,543	)	$	(185,459	)
	U.S. federal corporate statutory rate		35	%		35	%		35	%
	Expected tax		(6,725	)		(21,890	)		(64,911	)
	Earnings (loss) of non-taxable entities		(6,296	)		1,377			(25,295	)
	Canadian statutory tax rate differences		3,559			6,145			22,768
	Change in valuation allowance		(1,248	)		(452	)		(8,413	)
	Adjustments and assessments		(690	)		(4,796	)		(7,529	)
	Non-deductible expense related to asset impairment		—			—			59,304
	Taxable capital gains		—			—			3,895
	Non-deductible expenses and other		1,144			674			494
	Income tax benefit	$	(10,256	)	$	(18,942	)	$	(19,687	)
Schedule of significant components of the deferred income tax liabilities and deferred income tax assets	'
		As at March 31,
		2014			2013
	Deferred income tax assets:
	Risk management liabilities	$	33,386		$	8,904
	Non-capital loss carry forwards		18,434			8,451
	Deferred charges		6,890			1,166
	Capital losses		2,358			2,577
	Other		2,403			806
			63,471			21,904
	Valuation allowance		(4,004	)		(2,607	)
	Total deferred income tax assets	$	59,467		$	19,297
	Deferred income tax liabilities:
	Property, plant and equipment	$	114,298		$	114,148
	Intangible assets		15,137			17,636
	Partnership deferral income		37,499			11,007
	Risk management assets		17,049			11,477
	Other		535			267
	Total deferred income tax liabilities		184,518			154,535
	Net deferred income tax liabilities	$	125,051		$	135,238
Schedule of classification of net deferred income tax liabilities	'
		As at March 31,
		2014			2013
	Deferred income tax liabilities:
	Current	$	5,678		$	14,303
	Long-term		119,373			120,935
		$	125,051		$	135,238
Schedule of changes in unrecognized tax benefits	'
		As at March 31,
		2014			2013
	Balance at April 1,	$	1,160		$	3,267
	Additions based on tax positions taken in the current year		375			—
	Additions (reductions) based on tax positions taken in a prior year		200			(1,411	)
	Settlements with taxing authorities in the current year		—			(696	)
	Balance at March 31,	$	1,735		$	1,160

Risk_Management_Activities_and1

Risk Management Activities and Financial Instruments (Tables)	12 Months Ended
	Mar. 31, 2014
Risk Management Activities and Financial Instruments	'
Schedule of volumes of inventories which were economically hedged using each type of contract	'
		As at March 31,
		2014	2013
	Forwards	(1.4 Bcf)	1.6 Bcf
	Futures	20.1 Bcf	14.1 Bcf
	Swaps	(0.3 Bcf)	10.0 Bcf
	Options	—	—
		18.4 Bcf	25.7 Bcf

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	12 Months Ended
	Mar. 31, 2014
Fair Value Measurements	'
Schedule of fair values of risk management assets and liabilities	'
	As at March 31, 2014	Energy			Currency			Total
		Contracts			Contracts
	Short-term risk management assets	$	18,939		$	2,010		$	20,949
	Long-term risk management assets		4,260			546			4,806
	Short-term risk management liabilities		(18,945	)		(160	)		(19,105	)
	Long-term risk management liabilities		(12,209	)		—			(12,209	)
		$	(7,955	)	$	2,396		$	(5,559	)
	As at March 31, 2013	Energy			Currency			Total
		Contracts			Contracts
	Short-term risk management assets	$	20,383		$	776		$	21,159
	Long-term risk management assets		6,593			—			6,593
	Short-term risk management liabilities		(19,792	)		(213	)		(20,005	)
	Long-term risk management liabilities		(4,477	)		(97	)		(4,574	)
		$	2,707		$	466		$	3,173
Schedule of risk management assets and liabilities that had netting or rights of offset arrangements	'
	As at March 31, 2014	Gross Amounts			Gross Amounts			Net Amounts			Margin			Net Amounts
		Recognized			Offset in the			Presented in			Deposits not
					Balance Sheet			the Balance			Offset in the
								Sheet			Balance Sheet
	Assets
	Commodity derivatives	$	113,175		$	(89,976	)	$	23,199		$	(15,101	)	$	8,098
	Currency derivatives		2,851			(295	)		2,556			(2,556	)		—
	Total assets		116,026			(90,271	)		25,755			(17,657	)		8,098
	Liabilities
	Commodity derivatives		121,130			(89,976	)		31,154			(21,705	)		9,449
	Currency derivatives		455			(295	)		160			(160	)		—
	Total liabilities		121,585			(90,271	)		31,314			(21,865	)		9,449
	Net	$	(5,559	)	$	—		$	(5,559	)	$	4,208		$	(1,351	)
	As at March 31, 2013	Gross Amounts			Gross Amounts			Net Amounts			Margin			Net Amounts
		Recognized			Offset in the			Presented in			Deposits not
					Balance Sheet			the Balance			Offset in the
								Sheet			Balance Sheet
	Assets
	Commodity derivatives	$	88,682		$	(61,706	)	$	26,976		$	(15,030	)	$	11,946
	Currency derivatives		881			(105	)		776			(776	)		—
	Total assets		89,563			(61,811	)		27,752			(15,806	)		11,946
	Liabilities
	Commodity derivatives		85,975			(61,706	)		24,269			(16,861	)		7,408
	Currency derivatives		415			(105	)		310			(164	)		146
	Total liabilities		86,390			(61,811	)		24,579			(17,025	)		7,554
	Net	$	3,173		$	—		$	3,173		$	1,219		$	4,392
Schedule of risk management assets and liabilities outstanding expected to be realized into earnings in the fiscal periods	'
	Fiscal year ending March 31,	Energy			Currency			Total
		Contracts			Contracts
	2015	$	(6	)	$	1,850		$	1,844
	2016 and beyond		(7,949	)		546			(7,403	)
		$	(7,955	)	$	2,396		$	(5,559	)
Summary of net realized and unrealized optimization gains and losses from the settlement of risk management contracts	'
		Year ended March 31,
		2014			2013			2012			Classification
	Energy contracts
	Realized	$	(78,778	)	$	41,304		$	59,264		Optimization, net
	Unrealized		(10,662	)		(90,641	)		77,132		Optimization, net
	Currency contracts
	Realized		3,177			1,377			(6,064	)	Optimization, net
	Unrealized		1,930			790			6,027		Optimization, net
		$	(84,333	)	$	(47,170	)	$	136,359
Schedule of financial assets and liabilities that were accounted for or disclosed at fair value on a recurring basis	'
	As at March 31, 2014	Level 1			Level 2			Level 3			Total
	Assets
	Commodity derivatives	$	—		$	23,199		$	—		$	23,199
	Currency derivatives		—			2,556			—			2,556
	Total assets	$	—		$	25,755		$	—		$	25,755
	Liabilities
	Commodity derivatives	$	—		$	31,154		$	—		$	31,154
	Currency derivatives		—			160			—			160
	Long-term debt		—			570,700			—			570,700
	Total liabilities	$	—		$	602,014		$	—		$	602,014
	As at March 31, 2013	Level 1			Level 2			Level 3			Total
	Assets
	Commodity derivatives	$	—		$	26,976		$	—		$	26,976
	Currency derivatives		—			776			—			776
	Total assets	$	—		$	27,752		$	—		$	27,752
	Liabilities
	Commodity derivatives	$	—		$	24,269		$	—		$	24,269
	Currency derivatives		—			310			—			310
	Long-term debt		—			669,500			—			669,500
	Total liabilities	$	—		$	694,079		$	—		$	694,079

Members_Equity_Tables

Members' Equity (Tables)	12 Months Ended
	Mar. 31, 2014
Members' Equity	'
Schedule of reconciliation of units outstanding	'
		Common			Subordinated			Total
		Unitholders			Unitholders
	Units outstanding at March 31, 2011		33,804,745			33,804,745			67,609,490
	Units issued August 24, 2011		687,500			—			687,500
	Units outstanding at March 31, 2012 and 2013		34,492,245			33,804,745			68,296,990
	Subordinated units cancelled April 2, 2013		—			(33,804,745	)		(33,804,745	)
	Units issued under the DRIP		1,252,815			—			1,252,815
	Units outstanding at March 31, 2014		35,745,060			—			35,745,060
Unit-based compensation	'
Schedule of weighted average unit price at grant date and number of Phantom Units granted	'
		Year ended March 31,
		2014			2013			2012
	Weighted average price per unit at grant date	$	12.68		$	9.99		$	21.95
	Number of Phanton Units Granted		438,036			695,349			518,425
Schedule of net income (loss) allocation and income (loss) per unit calculation	'
		Year ended March 31,
		2014			2013			2012
	Numerator:
	Net earnings (loss) attributable to Niska Partners	$	(8,957	)	$	(43,601	)	$	(165,772	)
	Less:
	Managing Member's interest		171			863			3,283
	Net earnings (loss) attributable to common and subordinated unitholders	$	(8,786	)	$	(42,738	)	$	(162,489	)
	Denominator:
	Basic:
	Weighted average units outstanding		34,941,036			68,296,990			68,010,532
	Diluted:
	Weighted average units outstanding		34,941,036			68,296,990			68,010,532
	Earnings (loss) per unit allocated to common unitholders—basic and diluted	$	(0.25	)	$	(0.63	)	$	(2.39	)
	Earnings (loss) per unit allocated to subordinated unitholders—basic and diluted	$	—		$	(0.63	)	$	(2.39	)
Phantom Units Outstanding	'
Unit-based compensation	'
Schedule of reconciliation of phantom units outstanding and nonvested phantom units	'
		Number of			Number of			Total Units
		Time-			Performance-
		Based Units			Based Units
	Phantom Units outstanding—March 31, 2013		624,518			307,489			932,007
	Granted		219,018			219,018			438,036
	Exercised		(61,498	)		(61,498	)		(122,996	)
	Forfeited		(24,718	)		(23,719	)		(48,437	)
	Distribution equivalent rights		78,040			45,910			123,950
	Phantom Units outstanding—March 31, 2014		835,360			487,200			1,322,560
Nonvested Phantom Units	'
Unit-based compensation	'
Schedule of reconciliation of phantom units outstanding and nonvested phantom units	'
		Number of			Number of			Total Units
		Time-			Performance-
		Based Units			Based Units
	Nonvested Phantom Units—March 31, 2013		563,020			245,991			809,011
	Granted		219,018			219,018			438,036
	Vested		(368,502	)		(174,436	)		(542,938	)
	Forfeited		(24,718	)		(23,719	)		(48,437	)
	Distribution equivalent rights		78,040			45,910			123,950
	Nonvested Phantom Units—March 31, 2014		466,858			312,764			779,622

Revenues_Tables

Revenues (Tables)	12 Months Ended
	Mar. 31, 2014
Revenues	'
Schedule of components of fee-based revenue	'
		Year ended March 31
		2014			2013			2012
	Long-term contract revenue	$	83,940		$	108,615		$	116,244
	Short-term contract revenue		51,416			54,710			29,809
		$	135,356		$	163,325		$	146,053
Schedule of components of optimization, net	'
		Year ended March 31,
		2014			2013			2012
	Realized optimization, net	$	85,372		$	89,525		$	62,735
	Unrealized risk management (loss)
	gains (Notes 12 and 13)		(8,732	)		(89,874	)		83,193
	Write-down of inventory		(4,600	)		(22,281	)		(23,400	)
		$	72,040		$	(22,630	)	$	122,528

Interest_Tables

Interest (Tables)	12 Months Ended
	Mar. 31, 2014
Interest	'
Schedule of reconciliation of interest expense	'
		Year ended March 31,
		2014		2013			2012
	Gross interest	$	62,961	$	66,527		$	74,765
	Deferred charges amortization		3,354		3,411			3,942
	Capitalized interest		—		(2,928	)		(4,077	)
		$	66,315	$	67,010		$	74,630

Loss_on_extinguishment_of_debt1

Loss on extinguishment of debt (Tables)	12 Months Ended
	Mar. 31, 2014
Loss on extinguishment of debt	'
Schedule of loss on extinguishment of debt	'
		Year ended March 31,
		2014		2013		2012
	Premiums paid on redemption / repurchase of
	8.875% Senior Notes	$	28,572	$	—	$	1,770
	Deferred charges written off		8,125		599		3,091
		$	36,697	$	599	$	4,861

Commitments_and_Contingencies_

Commitments and Contingencies (Tables)	12 Months Ended
	Mar. 31, 2014
Commitments and Contingencies	'
Schedule of future minimum lease payments	'
	For the fiscal year ending:	Operating
		leases
	2015	$	11,837
	2016		8,937
	2017		8,483
	2018		6,142
	2019		5,512
	2020 and thereafter		183,151
	Total minimum lease payments	$	224,062
Schedule of purchase obligations arising as a result of forward purchase contracts in place	'
	For the fiscal year ending:	Unconditional
		purchase
		obligations
	2015	$	2,783,323
	2016		278,380
	2017		65,873
	2018		241,193
	2019		1,477
	2020 and thereafter		—
	Total future purchase commitments	$	3,370,246

Changes_in_NonCash_Working_Cap1

Changes in Non-Cash Working Capital (Tables)	12 Months Ended
	Mar. 31, 2014
Changes in Non-Cash Working Capital	'
Schedule of changes in non-cash working capital	'
		Year ended March 31,
		2014			2013			2012
	Margin deposits	$	(14,137	)	$	(39,174	)	$	99,804
	Trade receivables		(3,383	)		(286	)		(45	)
	Accrued receivables		(44,459	)		(40,203	)		9,938
	Natural gas inventory		3,676			125,042			(120,563	)
	Prepaid expenses and other current assets		358			(1,527	)		2,669
	Other assets		(807	)		(1,105	)		(1,637	)
	Trade payables		(149	)		645			(316	)
	Accrued liabilities		68,108			8,456			(53,036	)
	Income taxes		8			(693	)		(579	)
	Deferred revenue		5,468			(10,667	)		6,498
	Due from related party		(10	)		1,164			732
	Other long-term liabilities		360			381			115
	Net changes in non-cash working capital	$	15,033		$	42,033		$	(56,420	)

Supplemental_Cash_Flow_Disclos1

Supplemental Cash Flow Disclosures (Tables)	12 Months Ended
	Mar. 31, 2014
Supplemental Cash Flow Disclosures	'
Schedule of supplemental cash flow disclosures	'
		Year ended March 31,
		2014			2013			2012
	Interest paid	$	63,769		$	67,408		$	75,375
	Taxes paid (received)		73			(722	)		988
	Interest capitalized		—			2,928			4,077
	Non-cash investing activities:
	Non-cash (decrease) increase in working capital related to property, plant and equipment	$	(2,426	)	$	(8,605	)	$	11,296
	Non-cash transfer of natural gas inventory to property, plant and equipment		15,264			—			—
	Non-cash financing activities:
	Non-cash distributions and reinvestments		18,270			—			—

Segment_Disclosures_Tables

Segment Disclosures (Tables)	12 Months Ended
	Mar. 31, 2014
Segment Disclosures	'
Summary of net revenues and assets by geographic area	'
		Year ended March 31,
		2014			2013			2012
	Net realized revenues
	U.S.	$	57,628		$	70,161		$	70,928
	Canada		158,500			160,408			114,460
	Net unrealized revenues
	U.S.		142			(37,139	)		30,489
	Canada		(8,874	)		(52,735	)		52,704
	Inter-entity
	U.S.		—			—			—
	Canada		—			—			—
		$	207,396		$	140,695		$	268,581
	Long-lived assets (at year-end)
	U.S.	$	397,331		$	411,420
	Canada		839,917			858,604
		$	1,237,248		$	1,270,024

Quarterly_Financial_Data_Table

Quarterly Financial Data (Tables)	12 Months Ended
	Mar. 31, 2014
Quarterly Financial Data	'
Summary of quarterly financial data	'
		First			Second			Third			Fourth			Year ended
		Quarter			Quarter			Quarter			Quarter			March 31,
		(unaudited)			(unaudited)			(unaudited)			(unaudited)
	Fiscal 2014
	Revenue, net	$	57,189		$	36,863		$	25,847		$	87,497		$	207,396
	Earnings (loss) before income taxes	$	7,667		$	(7,797	)	$	(19,718	)	$	635		$	(19,213	)
	Net earnings (loss) and comprehensive income (loss)	$	7,967		$	(7,845	)	$	(13,409	)	$	4,330		$	(8,957	)
	Earnings (loss) per unit	$	0.23		$	(0.22	)	$	(0.37	)	$	0.12		$	(0.25	)
	Fiscal 2013
	Revenue, net	$	(2,787	)	$	24,545		$	73,831		$	45,106		$	140,695
	Earnings (loss) before income taxes	$	(49,287	)	$	(22,115	)	$	9,877		$	(1,018	)	$	(62,543	)
	Net earnings (loss) and comprehensive income (loss)	$	(37,346	)	$	(15,397	)	$	10,419		$	(1,277	)	$	(43,601	)
	Earnings (loss) per unit	$	(0.54	)	$	(0.22	)	$	0.15		$	(0.02	)	$	(0.63	)

Description_of_Business_Detail

Description of Business (Details) (USD $)	0 Months Ended	12 Months Ended
In Millions, except Share data, unless otherwise specified	Apr. 02, 2013	Mar. 31, 2014
Members' equity	'	'
Common units outstanding	'	35,745,060
Managing member's interest (as a percent)	'	1.91%
Carlyle/Riverstone Funds	'	'
Members' equity	'	'
Common units outstanding	'	18,245,055
Managing member's interest (as a percent)	'	1.91%
Ownership interest (as a percent)	'	51.98%
Previous structure | Subordinated Units	'	'
Members' equity	'	'
Additional distributions per quarter prior to increasing the quarterly distribution on Niska Partners' common units	12	'
Previous structure | Subordinated Units | Minimum Quarterly Distribution	'	'
Members' equity	'	'
Total Quarterly Distribution per Unit Target Amount (in dollars per unit)	0.35	'
Previous structure | Subordinated Units | Carlyle/Riverstone Funds	'	'
Members' equity	'	'
Subordinated units outstanding	33,800,000	'
New structure | Carlyle/Riverstone Funds	'	'
Members' equity	'	'
Period for which Carlyle Riverstone Funds will be deemed to own Notional Subordinated Units	'5 years	'
New structure | Notional Subordinated Units | Carlyle/Riverstone Funds	'	'
Members' equity	'	'
Notional Subordinated Units (in shares)	33,800,000	'
Unitholders | Minimum | Previous structure	'	'
Members' equity	'	'
Total Quarterly Distribution per Unit Target Amount (in dollars per unit)	0.4025	'
Unitholders | Maximum | Previous structure	'	'
Members' equity	'	'
Total Quarterly Distribution per Unit Target Amount (in dollars per unit)	0.525	'
Common unitholders | New structure | Minimum Quarterly Distribution	'	'
Members' equity	'	'
Total Quarterly Distribution per Unit Target Amount (in dollars per unit)	0.35	'
Distribution in arrears from prior quarters (in dollars per unit)	0	'
IDR Holder | New structure | Carlyle/Riverstone Funds	'	'
Members' equity	'	'
Marginal Percentage Interest in Cash Distributions	48.00%	48.00%
IDR Holder | Minimum | Previous structure | Carlyle/Riverstone Funds	'	'
Members' equity	'	'
Marginal Percentage Interest in Cash Distributions	13.00%	13.00%
IDR Holder | Maximum | Previous structure | Carlyle/Riverstone Funds	'	'
Members' equity	'	'
Marginal Percentage Interest in Cash Distributions	48.00%	48.00%
Public owners	'	'
Members' equity	'	'
Common units outstanding	'	17,500,005
Ownership interest (as a percent)	'	48.02%

Significant_Accounting_Policie3

Significant Accounting Policies (Details)	12 Months Ended
	Mar. 31, 2014
	item
Revenue recognition	'
Number of revenue recognition criteria	4
Pipelines and measurement	'
Property, plant and equipment	'
Depreciation rate declining balance method (as a percent)	5.00%
Wells	'
Property, plant and equipment	'
Depreciation rate declining balance method (as a percent)	5.00%
Facilities | Minimum	'
Property, plant and equipment	'
Depreciation rate declining balance method (as a percent)	5.00%
Facilities | Maximum	'
Property, plant and equipment	'
Depreciation rate declining balance method (as a percent)	22.00%
Computer hardware and software	'
Property, plant and equipment	'
Depreciation rate declining balance method (as a percent)	30.00%
Office furniture and fixtures	'
Property, plant and equipment	'
Depreciation rate declining balance method (as a percent)	20.00%
Other	'
Property, plant and equipment	'
Depreciation rate declining balance method (as a percent)	10.00%

Property_Plant_and_Equipment_D

Property, Plant and Equipment (Details) (USD $)	12 Months Ended
	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012
Property, plant and equipment	'	'	'
Cost	$1,125,175,000	$1,104,325,000	'
Accumulated Amortization	-216,901,000	-186,264,000	'
Net Book Value	908,274,000	918,061,000	'
Depreciation and amortization expense	41,286,000	50,409,000	46,132,000
U.S.	'	'	'
Property, plant and equipment	'	'	'
Number of facilities which sold cushion	2	'	'
Canada	'	'	'
Property, plant and equipment	'	'	'
Number of facilities which sold cushion	1	'	'
Cushion	'	'	'
Property, plant and equipment	'	'	'
Cost	421,404,000	406,141,000	'
Net Book Value	421,404,000	406,141,000	'
Depreciation and amortization expense	0	9,500,000	6,700,000
Loss on sale of cushion	'	14,900,000	2,800,000
Pipelines and measurement	'	'	'
Property, plant and equipment	'	'	'
Cost	296,671,000	296,661,000	'
Accumulated Amortization	-92,687,000	-81,950,000	'
Net Book Value	203,984,000	214,711,000	'
Wells	'	'	'
Property, plant and equipment	'	'	'
Cost	126,694,000	126,519,000	'
Accumulated Amortization	-40,700,000	-36,179,000	'
Net Book Value	85,994,000	90,340,000	'
Facilities	'	'	'
Property, plant and equipment	'	'	'
Cost	272,645,000	267,508,000	'
Accumulated Amortization	-79,028,000	-64,238,000	'
Net Book Value	193,617,000	203,270,000	'
Cost of assets under capital lease	14,200,000	14,200,000	'
Accumulated depreciation of assets under capital lease	4,500,000	1,800,000	'
Computer hardware and software	'	'	'
Property, plant and equipment	'	'	'
Cost	4,225,000	4,095,000	'
Accumulated Amortization	-3,087,000	-2,653,000	'
Net Book Value	1,138,000	1,442,000	'
Construction in progress, including projects under development	'	'	'
Property, plant and equipment	'	'	'
Cost	1,063,000	928,000	'
Net Book Value	1,063,000	928,000	'
Office furniture, equipment and other	'	'	'
Property, plant and equipment	'	'	'
Cost	2,473,000	2,473,000	'
Accumulated Amortization	-1,399,000	-1,244,000	'
Net Book Value	1,074,000	1,229,000	'
Steel pipe	'	'	'
Property, plant and equipment	'	'	'
Impairment charge	$0	$0	$2,500,000

Goodwill_and_Other_Intangible_2

Goodwill and Other Intangible Assets (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012
	item
Goodwill	'	'	'
Impairment	'	$0	'
Number of reporting units	4	'	'
Number of operating segments	1	'	'
Discount rate used to estimate cycling volumes and expenses (as a percent)	'	'	8.88%
Goodwill impairment	'	'	250,000
Intangible assets	'	'	'
Customer contracts and relationships, beginning of the year	163,073	163,073	'
Additions	2,007	'	'
Less accumulated amortization	-117,888	-107,345	'
Customer contracts and relationships, end of the year	47,192	55,728	'
Pipeline rights of way	18,270	18,270	'
Total	$65,462	$73,998	'

Goodwill_and_Other_Intangible_3

Goodwill and Other Intangible Assets (Details 2) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012
Customer contracts and relationships	'	'	'
Amortization expense	$10,543	$11,311	$13,675
Estimated future amortization expense	'	'	'
31-Mar-15	23,633	'	'
31-Mar-16	5,977	'	'
31-Mar-17	7,513	'	'
31-Mar-18	3,558	'	'
March 31, 2019 and thereafter	$6,511	'	'
Minimum	'	'	'
Customer contracts and relationships	'	'	'
Term of contracts	'1 year	'	'
Maximum	'	'	'
Customer contracts and relationships	'	'	'
Term of contracts	'15 years	'	'

Deferred_Charges_Details

Deferred Charges (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012
Deferred charges	'	'	'
Deferred charges-cost, beginning of the year	$25,377	$23,566	'
Additions	11,696	3,248	'
Write-offs due to extinguishment of debt	-16,995	'	'
Write-offs due to amendment and restatement of revolving credit facility	'	-1,437	'
Deferred charges-cost, end of the year	20,078	25,377	23,566
Accumulated amortization, beginning of the year	-10,957	-8,384	'
Amortization during the year	-3,354	-3,411	-3,942
Write-offs due to extinguishment of debt	8,873	'	'
Write-offs due to amendment and restatement of revolving credit facility	'	838	'
Accumulated amortization, end of the year	-5,438	-10,957	-8,384
Net book value	14,640	14,420	'
Life in years, minimum	'3 years	'1 year	'
Life in years, maximum	'5 years	'5 years	'
Amortization expense	'	'	'
Amortization expense	$3,354	$3,411	$3,942

Debt_Details

Debt (Details) (USD $)

3 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

12 Months Ended

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2013

Mar. 31, 2012

Mar. 31, 2014

Mar. 31, 2014

Mar. 17, 2014

Mar. 31, 2012

Mar. 31, 2013

Aug. 24, 2011

Mar. 17, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2013

Mar. 31, 2014

Jun. 29, 2013

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

item

item

Minimum

Maximum

8.875% Senior Notes due 2018

8.875% Senior Notes due 2018

8.875% Senior Notes due 2018

8.875% Senior Notes due 2018

6.50% Senior Notes due 2019

6.50% Senior Notes due 2019

6.50% Senior Notes due 2019

6.50% Senior Notes due 2019

6.50% Senior Notes due 2019

6.50% Senior Notes due 2019

Revolving credit facilities

Revolving credit facilities

Revolving credit facilities

U.S. revolving credit facility

U.S. revolving credit facility

Canadian revolving credit facility

Canadian revolving credit facility

item

Prior to October 1, 2016

Twelve-month period beginning on October 1, 2016

Twelve-month period beginning on October 1, 2018 and at any time thereafter

Maximum

Maximum

Maximum

Prior to October 1, 2016

Debt

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Long-term debt

$694,500,000

$694,500,000

$708,790,000

'

'

'

'

'

$643,790,000

'

'

$575,000,000

'

'

'

'

$65,000,000

$119,500,000

'

'

'

'

'

Less portion classified as current

-119,500,000

-119,500,000

-65,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Long-term debt, less current portion

575,000,000

575,000,000

643,790,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Proceeds from issuance of debt

'

575,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net proceeds from issuance of debt

'

'

'

'

'

'

'

'

'

'

563,300,000

'

'

'

'

'

'

'

'

'

'

'

'

Debt redemption / repurchase

'

672,361,000

'

158,012,000

'

'

643,800,000

158,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Interest rate (as a percent)

'

'

'

'

'

'

8.88%

'

'

8.88%

'

6.50%

'

'

'

'

'

'

'

'

'

'

'

Payment of call premium

'

'

'

'

'

'

28,600,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

write-off of unamortized deferred financing costs

'

8,125,000

599,000

3,091,000

'

'

8,100,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Loss on extinguishment of debt

36,697,000

36,697,000

599,000

4,861,000

'

'

36,700,000

4,900,000

'

'

'

'

'

'

'

'

600,000

'

'

'

'

'

'

Principal amount of notes repurchased

'

'

'

'

'

'

'

156,200,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Estimated fair market value of debt

'

'

'

'

'

'

'

'

'

'

'

570,700,000

'

'

'

'

'

'

'

'

'

'

'

Percentage of aggregate principal amount that may be redeemed

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

35.00%

'

'

'

'

'

'

'

Redemption price as a percentage of principal amount upon occurrence of change of control

'

'

'

'

'

'

'

'

'

'

'

101.00%

106.50%

103.25%

101.63%

'

'

'

'

'

'

'

'

Number of preceding quarters for which fixed charge coverage ratio is measured

'

'

'

'

'

'

'

'

'

'

'

4

'

'

'

'

'

'

'

'

'

'

'

Minimum fixed charge coverage ratio required to make restricted payments

'

'

'

'

'

'

'

'

'

'

'

1.75

'

'

'

'

'

'

'

'

'

'

'

Amount included in the general basket of restricted payments

'

'

'

'

'

'

'

'

'

'

'

75,000,000

'

'

'

'

'

'

'

'

'

'

'

Actual fixed charge coverage ratio

2.8

2.8

'

'

'

'

'

'

'

'

'

2.8

'

'

'

'

'

'

'

'

'

'

'

Amount of distribution permitted on achievement of condition related to fixed charge coverage ratio

'

'

'

'

'

'

'

'

'

'

'

207,100,000

'

'

'

'

'

'

'

'

'

'

'

Percentage of aggregate principal amount of notes that holders can request for accelerated payment in case of an event of default

'

'

'

'

'

'

'

'

'

'

'

25.00%

'

'

'

'

'

'

'

'

'

'

'

Period upon occurrence of change of control used to determine redemption of debt

'

'

'

'

'

'

'

'

'

'

'

'90 days

'

'

'

'

'

'

'

'

'

'

'

Maximum borrowing capacity

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

400,000,000

400,000,000

200,000,000

'

200,000,000

'

Amount by which maximum borrowing capacity may be expanded in additional commitments

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100,000,000

'

100,000,000

'

Borrowing base collateral

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

396,400,000

'

'

'

'

'

Amount included in aggregate borrowing base under the Credit Facilities due to a first-priority lien on fixed assets granted to the lenders

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

150,000,000

'

'

'

'

'

Minimum amount of release from the first-priority lien for reduction in fixed assets amount on a dollar-for-dollar basis

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50,000,000

'

'

'

'

'

Minimum fixed charge coverage ratio required to be maintained when excess availability under facility is less than 15% of the aggregate amount of availability

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1.1

'

1.1

'

Level of available Credit Facilities under both the U.S. revolving facility and the Canadian revolving credit facility at the end of each fiscal quarter before the maintenance of a fixed charge coverage ratio of 1.1 to 1.0 is not required

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

15.00%

'

15.00%

Period of consecutive time that excess availability exceeds 15% to release quarterly testing of the 1.1 to 1.0 fixed charge coverage ratio

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'30 days

'

'30 days

'

Borrowings outstanding

119,500,000

119,500,000

65,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

65,000,000

119,500,000

'

'

'

'

'

Weighted average interest rate (as a percent)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3.69%

3.56%

'

'

'

'

'

Letters of credit issued

4,800,000

4,800,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3,300,000

4,800,000

'

'

'

'

'

Number of independent assets or operations other than investments in subsidiaries

0

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Restricted assets

$0

$0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Fixed charge coverage ratio required to incur additional debt obligations

'

'

'

'

'

2

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Fixed charge coverage ratio permitted for making restricted payments

'

'

'

'

1.75

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Obligations_Under_Capital_Leas2

Obligations Under Capital Lease (Details) (USD $)	12 Months Ended
	Mar. 31, 2014
Obligations Under Capital Lease	'
Estimated future minimum lease payments	$13,900,000
Imputed interest rate (as a percent)	3.08%
Future principal and interest payments of obligations under capital lease	'
31-Mar-15	1,657,000
31-Mar-16	1,657,000
31-Mar-17	1,657,000
31-Mar-18	1,657,000
31-Mar-19	1,657,000
March 31, 2020 and thereafter	5,574,000
Less: Amount representing interest	-1,634,000
Total	$12,225,000

Accrued_Liabilities_Details

Accrued Liabilities (Details) (USD $)	Mar. 31, 2014	Mar. 31, 2013
In Thousands, unless otherwise specified
Accrued Liabilities	'	'
Accrued gas purchases	$75,454	$14,213
Employee-related accruals	22,315	13,836
Accrued interest	2,037	2,845
Other accrued liabilities	11,312	8,946
Total	$111,118	$39,840

Asset_Retirement_Obligations_D

Asset Retirement Obligations (Details) (USD $)	12 Months Ended
	Mar. 31, 2014	Mar. 31, 2013
Asset Retirement Obligations	'	'
Estimated undiscounted cash flows required to settle the asset retirement obligations	$54,100,000	'
Inflation rate used in calculation of undiscounted cash flows required to settle the asset retirement obligations (as a percent)	2.00%	'
Rate used to discount estimated cash flows (as a percent)	8.00%	'
Period for payment for settlement of the obligations	'43 years	'
Changes in asset retirement obligations	'	'
Balance, beginning of the year	2,007,000	1,554,000
Additions	'	210,000
Accretion	107,000	197,000
Effect of foreign exchange translation	-139,000	46,000
Balance, end of the year	$1,975,000	$2,007,000

Income_Taxes_Details

Income Taxes (Details) (USD $)	3 Months Ended								12 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012
Components of the company's earnings (loss) before income taxes (benefits)	'	'	'	'	'	'	'	'	'	'	'
Domestic	'	'	'	'	'	'	'	'	$16,844	($493)	$72,270
Foreign	'	'	'	'	'	'	'	'	-36,057	-62,050	-257,729
EARNINGS (LOSS) BEFORE INCOME TAXES	635	-19,718	-7,797	7,667	-1,018	9,877	-22,115	-49,287	-19,213	-62,543	-185,459
Total income tax expense (benefit) differed from the amounts computed by applying the tax rate to earnings before income taxes	'	'	'	'	'	'	'	'	'	'	'
Net earnings (loss) before taxes	635	-19,718	-7,797	7,667	-1,018	9,877	-22,115	-49,287	-19,213	-62,543	-185,459
U.S. federal corporate statutory rate (as a percent)	'	'	'	'	'	'	'	'	35.00%	35.00%	35.00%
Expected tax	'	'	'	'	'	'	'	'	-6,725	-21,890	-64,911
Earnings (loss) of non-taxable entities	'	'	'	'	'	'	'	'	-6,296	1,377	-25,295
Canadian statutory tax rate differences	'	'	'	'	'	'	'	'	3,559	6,145	22,768
Change in valuation allowance	'	'	'	'	'	'	'	'	-1,248	-452	-8,413
Adjustments and assessments	'	'	'	'	'	'	'	'	-690	-4,796	-7,529
Non-deductible expense related to asset impairment	'	'	'	'	'	'	'	'	'	'	59,304
Taxable capital gains	'	'	'	'	'	'	'	'	'	'	3,895
Non-deductible expenses and other	'	'	'	'	'	'	'	'	1,144	674	494
Income tax (benefit) expense	'	'	'	'	'	'	'	'	($10,256)	($18,942)	($19,687)

Income_Taxes_Details_2

Income Taxes (Details 2) (USD $)	12 Months Ended
	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012
Capital losses	'	'	'
Deferred tax asset resulted from capital losses	$2,358,000	$2,577,000	'
Deferred income tax assets resulting from non-capital loss carryforwards	18,434,000	8,451,000	'
Potential interest and penalties associated with uncertain tax positions	'	'	'
Potential interest and penalties associated with uncertain tax positions	0	0	300,000
Deferred income tax assets:	'	'	'
Risk management liabilities	33,386,000	8,904,000	'
Non-capital loss carry forwards	18,434,000	8,451,000	'
Deferred charges	6,890,000	1,166,000	'
Capital losses	2,358,000	2,577,000	'
Other	2,403,000	806,000	'
Total	63,471,000	21,904,000	'
Valuation allowance	-4,004,000	-2,607,000	'
Total deferred income tax assets	59,467,000	19,297,000	'
Deferred income tax liabilities:	'	'	'
Property, plant and equipment	114,298,000	114,148,000	'
Intangible assets	15,137,000	17,636,000	'
Partnership deferral income	37,499,000	11,007,000	'
Risk management assets	17,049,000	11,477,000	'
Other	535,000	267,000	'
Total deferred income tax liabilities	184,518,000	154,535,000	'
Net deferred income tax liabilities	125,051,000	135,238,000	'
Deferred income tax liabilities:	'	'	'
Current	5,678,000	14,303,000	'
Long-term	119,373,000	120,935,000	'
Net deferred income tax liabilities	125,051,000	135,238,000	'
Changes to the Company's unrecognized tax benefits	'	'	'
Balance at the beginning of period	1,160,000	3,267,000	'
Additions based on tax positions taken in the current year	375,000	'	'
Additions (reductions) based on tax positions taken in a prior year	200,000	-1,411,000	'
Settlements with taxing authorities in the current year	'	-696,000	'
Balance at the end of period	1,735,000	1,160,000	3,267,000
Unrecognized tax benefits that would have an impact on the effective tax rate if subsequently recognized	1,700,000	'	'
Canadian subsidiaries	'	'	'
Capital losses	'	'	'
Accumulated non-capital losses	76,200,000	34,900,000	'
Deferred income tax assets resulting from non-capital loss carryforwards	18,400,000	8,500,000	'
Deferred income tax assets:	'	'	'
Non-capital loss carry forwards	18,400,000	8,500,000	'
Canadian subsidiaries | Capital losses	'	'	'
Capital losses	'	'	'
Capital losses	18,900,000	20,600,000	'
Deferred tax asset resulted from capital losses	2,400,000	2,600,000	'
Amount of capital losses offset by valuation allowance	2,400,000	2,300,000	'
Amount of tax assets related to losses expiring at the end of 2029	100,000	'	'
Deferred income tax assets:	'	'	'
Capital losses	$2,400,000	$2,600,000	'

Risk_Management_Activities_and2

Risk Management Activities and Financial Instruments (Details) (USD $)

12 Months Ended

12 Months Ended

12 Months Ended

Mar. 31, 2014

Mar. 31, 2013

Mar. 31, 2012

Mar. 31, 2014

Jun. 29, 2013

Mar. 31, 2013

Mar. 31, 2014

Mar. 31, 2013

Mar. 31, 2014

Mar. 31, 2013

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2013

Mar. 31, 2014

Mar. 31, 2013

Mar. 31, 2014

Mar. 31, 2013

Mar. 31, 2014

Mar. 31, 2013

Mar. 31, 2014

Mar. 31, 2013

Mar. 31, 2014

Mar. 31, 2013

item

item

Revolving credit facility

Revolving credit facility

Revolving credit facility

Minimum

Minimum

Maximum

Maximum

Exchange traded futures and options

Commodity derivatives

Commodity derivatives

Commodity derivatives

Commodity derivatives

Commodity derivatives

Commodity derivatives

Commodity derivatives

Commodity derivatives

Commodity derivatives

Commodity derivatives

Currency contracts

Currency contracts

Natural gas retail contracts

Natural gas retail contracts

Natural gas retail contracts

Natural gas retail contracts

MMcf

MMcf

Natural gas retail contracts

Natural gas retail contracts

Forward contracts

Forward contracts

Futures

Futures

Swaps

Swaps

Currency swap

Currency swap

MMcf

MMcf

MMcf

MMcf

MMcf

MMcf

Risk management activities and financial instruments

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Aggregate overall exposure limit of unmatched volumes of proprietary current natural gas inventory (in million cubic feet)

'

'

'

'

'

'

'

'

'

'

'

8,000

'

'

'

'

'

'

'

'

'

'

'

Volume of current natural gas inventory offset with derivative contracts (in million cubic feet)

'

'

'

'

'

'

'

'

'

'

'

18,400

25,700

'

'

-1,400

1,600

20,100

14,100

-300

10,000

'

'

Percentage of the total current inventory of natural gas offset with derivative contracts

'

'

'

'

'

'

'

'

'

'

'

97.20%

'

'

'

'

'

'

'

'

'

'

'

Volume of natural gas inventory (in million cubic feet)

'

'

'

'

'

'

'

'

'

'

'

18,400

'

'

'

'

'

'

'

'

'

'

'

Doubtful accounts expense

$400,000

$0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of significant counterparties

1

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Percentage of total revenue from one counterparty

56.00%

28.00%

40.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Exchange-traded derivative instruments as percentage of commodity risk management assets

'

'

'

'

'

'

'

'

'

'

68.60%

'

'

'

'

'

'

'

'

'

'

'

'

Period of energy contracts to customers in retail markets

'

'

'

'

'

'

'1 year

'1 year

'5 years

'5 years

'

'

'

'

'

'

'

'

'

'

'

'

'

Reduction in value of energy contracts

'

'

'

'

'

'

'

'

'

'

'

'

'

0

1,000,000

'

'

'

'

'

'

'

'

Maximum borrowing capacity

'

'

'

400,000,000

400,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Borrowings outstanding

119,500,000

65,000,000

'

119,500,000

'

65,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of interest rate swap or swaption agreements

0

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Notional value of currency swaps

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$13,000,000

$84,000,000

Fair_Value_Measurements_Detail

Fair Value Measurements (Details) (USD $)	Mar. 31, 2014	Mar. 31, 2013
In Thousands, unless otherwise specified
Fair value of risk management assets and liabilities	'	'
Short-term risk management assets	$20,949	$21,159
Long-term risk management assets	4,806	6,593
Short-term risk management liabilities	-19,105	-20,005
Long-term risk management liabilities	-12,209	-4,574
Total	-5,559	3,173
Not designated as hedge	'	'
Fair value of risk management assets and liabilities	'	'
Short-term risk management assets	20,949	21,159
Long-term risk management assets	4,806	6,593
Short-term risk management liabilities	-19,105	-20,005
Long-term risk management liabilities	-12,209	-4,574
Total	-5,559	3,173
Energy Contracts	'	'
Fair value of risk management assets and liabilities	'	'
Total	-7,955	'
Energy Contracts | Not designated as hedge	'	'
Fair value of risk management assets and liabilities	'	'
Short-term risk management assets	18,939	20,383
Long-term risk management assets	4,260	6,593
Short-term risk management liabilities	-18,945	-19,792
Long-term risk management liabilities	-12,209	-4,477
Total	-7,955	2,707
Currency contracts	'	'
Fair value of risk management assets and liabilities	'	'
Total	2,396	'
Currency contracts | Not designated as hedge	'	'
Fair value of risk management assets and liabilities	'	'
Short-term risk management assets	2,010	776
Long-term risk management assets	546	'
Short-term risk management liabilities	-160	-213
Long-term risk management liabilities	'	-97
Total	$2,396	$466

Fair_Value_Measurements_Detail1

Fair Value Measurements (Details 2) (USD $)	Mar. 31, 2014	Mar. 31, 2013
In Thousands, unless otherwise specified
Assets	'	'
Gross Amounts Recognized	$116,026	$89,563
Gross Amounts Offset in the Balance Sheet	-90,271	-61,811
Net Amounts Presented in the Balance Sheet	25,755	27,752
Margin Deposits not Offset in the Balance Sheet	-17,657	-15,806
Net Amounts	8,098	11,946
Liabilities	'	'
Gross Amounts Recognized	121,585	86,390
Gross Amounts Offset in the Balance Sheets	-90,271	-61,811
Net Amounts Presented in the Balance Sheets	31,314	24,579
Margin Deposits not Offset in the Balance Sheets	-21,865	-17,025
Net Amounts	9,449	7,554
Net - Amounts Presented in the Balance Sheets	-5,559	3,173
Net - Margin Deposits not Offset in the Balance Sheets	4,208	1,219
Net	-1,351	4,392
Commodity derivatives	'	'
Assets	'	'
Gross Amounts Recognized	113,175	88,682
Gross Amounts Offset in the Balance Sheet	-89,976	-61,706
Net Amounts Presented in the Balance Sheet	23,199	26,976
Margin Deposits not Offset in the Balance Sheet	-15,101	-15,030
Net Amounts	8,098	11,946
Liabilities	'	'
Gross Amounts Recognized	121,130	85,975
Gross Amounts Offset in the Balance Sheets	-89,976	-61,706
Net Amounts Presented in the Balance Sheets	31,154	24,269
Margin Deposits not Offset in the Balance Sheets	-21,705	-16,861
Net Amounts	9,449	7,408
Net - Amounts Presented in the Balance Sheets	-7,955	'
Currency derivatives	'	'
Assets	'	'
Gross Amounts Recognized	2,851	881
Gross Amounts Offset in the Balance Sheet	-295	-105
Net Amounts Presented in the Balance Sheet	2,556	776
Margin Deposits not Offset in the Balance Sheet	-2,556	-776
Liabilities	'	'
Gross Amounts Recognized	455	415
Gross Amounts Offset in the Balance Sheets	-295	-105
Net Amounts Presented in the Balance Sheets	160	310
Margin Deposits not Offset in the Balance Sheets	-160	-164
Net Amounts	'	146
Net - Amounts Presented in the Balance Sheets	$2,396	'

Fair_Value_Measurements_Detail2

Fair Value Measurements (Details 3) (USD $)	Mar. 31, 2014	Mar. 31, 2013
In Thousands, unless otherwise specified
Expected realization of derivative instruments into earnings	'	'
Fiscal year ending March 31, 2015	$1,844	'
Fiscal year ending March 31, 2016 and beyond	-7,403	'
Total	-5,559	3,173
Energy Contracts	'	'
Expected realization of derivative instruments into earnings	'	'
Fiscal year ending March 31, 2015	-6	'
Fiscal year ending March 31, 2016 and beyond	-7,949	'
Total	-7,955	'
Currency contracts	'	'
Expected realization of derivative instruments into earnings	'	'
Fiscal year ending March 31, 2015	1,850	'
Fiscal year ending March 31, 2016 and beyond	546	'
Total	$2,396	'

Fair_Value_Measurements_Detail3

Fair Value Measurements (Details 4) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012
Net realized and unrealized optimization gains and losses from the settlement of risk management contracts	'	'	'
Unrealized	($8,732)	($89,851)	$83,193
Not designated as hedge	'	'	'
Net realized and unrealized optimization gains and losses from the settlement of risk management contracts	'	'	'
Total	-84,333	-47,170	136,359
Energy Contracts | Not designated as hedge	'	'	'
Net realized and unrealized optimization gains and losses from the settlement of risk management contracts	'	'	'
Realized	-78,778	41,304	59,264
Unrealized	-10,662	-90,641	77,132
Currency contracts | Not designated as hedge	'	'	'
Net realized and unrealized optimization gains and losses from the settlement of risk management contracts	'	'	'
Realized	3,177	1,377	-6,064
Unrealized	$1,930	$790	$6,027

Fair_Value_Measurements_Detail4

Fair Value Measurements (Details 5) (USD $)	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012
In Thousands, unless otherwise specified
Assets	'	'	'
Total assets	$25,755	$27,752	'
Liabilities	'	'	'
Transfer out of Level 2	0	0	0
Transfer out of Level 2	0	0	0
Non-financial assets	0	0	'
Non-financial liabilities	0	0	'
Commodity derivatives	'	'	'
Assets	'	'	'
Total assets	23,199	26,976	'
Currency derivatives	'	'	'
Assets	'	'	'
Total assets	2,556	776	'
Recurring | Level 2	'	'	'
Assets	'	'	'
Total assets	25,755	27,752	'
Liabilities	'	'	'
Long-term debt	570,700	669,500	'
Total liabilities	602,014	694,079	'
Recurring | Level 2 | Commodity derivatives	'	'	'
Assets	'	'	'
Total assets	23,199	26,976	'
Liabilities	'	'	'
Total liabilities	31,154	24,269	'
Recurring | Level 2 | Currency derivatives	'	'	'
Assets	'	'	'
Total assets	2,556	776	'
Liabilities	'	'	'
Total liabilities	160	310	'
Recurring | Total	'	'	'
Assets	'	'	'
Total assets	25,755	27,752	'
Liabilities	'	'	'
Long-term debt	570,700	669,500	'
Total liabilities	602,014	694,079	'
Recurring | Total | Commodity derivatives	'	'	'
Assets	'	'	'
Total assets	23,199	26,976	'
Liabilities	'	'	'
Total liabilities	31,154	24,269	'
Recurring | Total | Currency derivatives	'	'	'
Assets	'	'	'
Total assets	2,556	776	'
Liabilities	'	'	'
Total liabilities	$160	$310	'

Members_Equity_Details

Members' Equity (Details) (USD $)

0 Months Ended

12 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

Oct. 30, 2013

Mar. 31, 2014

Mar. 31, 2012

Apr. 02, 2013

Mar. 31, 2013

Aug. 24, 2011

Mar. 31, 2011

Mar. 31, 2014

Apr. 02, 2013

Apr. 02, 2013

Apr. 02, 2013

Mar. 31, 2014

Mar. 31, 2014

Jul. 31, 2013

Aug. 24, 2011

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 17, 2014

Aug. 24, 2011

Jun. 24, 2011

Carlyle/Riverstone Funds

Carlyle/Riverstone Funds

Carlyle/Riverstone Funds

Carlyle/Riverstone Funds

Carlyle/Riverstone Funds

Minimum

Maximum

Sponsor Holdings

Sponsor Holdings

Sponsor Holdings

Sponsor Holdings

Senior Notes due 2018

Senior Notes due 2018

Niska Holdings Canada

Previous structure

New structure

New structure

Subsequent events

Common Units

Notional Subordinated Units

Subordinated Units

Notional Subordinated Units

Members' equity

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common units authorized under DRIP

'

'

'

'

'

'

'

'

'

'

'

'

'

7,500,000

'

'

'

'

'

'

'

Common units issued under DRIP

'

1,252,815

'

'

'

'

'

1,252,810

'

'

'

'

'

'

'

'

'

'

'

'

'

Non cash earnings distribution and reinvestments

'

$18,270,000

'

'

'

'

'

$18,300,000

'

'

'

$6,400,000

'

'

'

'

'

'

'

'

'

Additional value of common units allowed to be issued

75,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common units issued under At-The-Market program

'

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Period a member who received impermissible distribution will be liable

'

'3 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common units issued

'

'

34,492,245

'

34,492,245

687,500

33,804,745

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Subordinated units issued

'

'

33,804,745

'

33,804,745

'

33,804,745

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Subordinated units cancelled

'

'

'

-33,804,745

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total units issued

'

1,252,815

68,296,990

-33,804,745

68,296,990

687,500

67,609,490

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common units outstanding

'

35,745,060

'

'

'

'

'

18,245,055

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of shares issued

'

'

'

'

'

'

'

'

'

'

'

'

'

'

687,500

'

'

'

'

'

'

Offering price (in dollars per unit)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$16

'

'

'

'

'

'

Total proceeds from issuance and sale of common units

'

'

11,000,000

'

'

'

'

'

'

'

'

'

'

'

11,000,000

'

'

'

'

'

'

Interest rate (as a percent)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

8.88%

8.88%

'

Subordinated units outstanding

'

'

'

'

'

'

'

'

33,800,000

'

'

'

'

'

'

'

'

'

'

'

'

Total Units outstanding

'

35,745,060

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Managing member's interest (as a percent)

'

1.91%

'

'

'

'

'

1.91%

'

'

'

'

'

'

'

1.91%

'

'

'

'

'

Voting interest required for removal of manager prior to March 31, 2020 (as a percent)

'

'

'

'

'

'

'

'

'

'

'

'

66.67%

'

'

'

'

'

'

'

'

Ownership interest of manager and its affiliates that gives them ability to prevent the manager's removal (as a percent)

'

'

'

'

'

'

'

'

'

'

'

'

33.33%

'

'

'

'

'

'

'

'

Ownership of common and subordinated units (as a percent)

'

'

'

'

'

'

'

51.98%

'

'

'

'

'

'

'

'

'

'

'

'

'

Ownership of common and notional subordinated units, excluding managing member interest (as a percent)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

51.04%

100.00%

'

'

'

Minimum quarterly distribution to common unitholders (in dollars per unit)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$0.35

'

'

'

'

'

Period for which Carlyle Riverstone Funds will be deemed to own Notional Subordinated Units

'

'

'

'

'

'

'

'

'

'5 years

'

'

'

'

'

'

'

'

'

'

'

Notional Subordinated Units (in shares)

'

'

'

'

'

'

'

'

'

'

33,800,000

'

'

'

'

'

'

'

'

'

'

Acquisition of Interest in Parent

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Aggregate purchase price recorded as a reduction of equity

'

'

-2,176,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,200,000

Gain (loss) recognized for purchase of Class B units from non-executive employees

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$0

Cumulative rate of return on Class A units of Niska Holdings Canada (as a percent)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

8.00%

Members_Equity_Details_2

Members' Equity (Details 2) (USD $)

0 Months Ended

12 Months Ended

12 Months Ended

In Millions, except Share data, unless otherwise specified

Apr. 02, 2011

Mar. 31, 2014

Mar. 31, 2013

Mar. 31, 2012

Mar. 31, 2014

Mar. 31, 2013

Mar. 31, 2012

Apr. 02, 2013

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

item

Phantom Units

Phantom Units

Phantom Units

Phantom Units

Phantom Units

Phantom Units

Time-based phantom units

Time-based phantom units

Performance-Based phantom units

Performance-Based phantom units

Phantom Units Outstanding

Nonvested Phantom Units

Phantom Units Outstanding

Nonvested Phantom Units

Phantom Units Outstanding

Nonvested Phantom Units

Members Equity

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Period over which phantom units vest

'

'

'

'

'3 years

'

'

'

'

'

'

'

'

'

Number of compensatory PUPP plans

2

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of units authorized under the PUPP (in shares)

'

'

'

'

3,380,474

'

'

'

'

'

'

'

'

'

Weighted average price of granted units (in dollars per share)

'

'

'

'

$12.68

$9.99

$21.95

'

'

'

'

'

'

'

Number of units available for grant (in shares)

'

'

'

'

1,483,708

2,045,693

'

2,045,693

'

'

'

'

'

'

Reconciliation of Phantom Units Outstanding

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Balance at the beginning of the period (in shares)

'

'

'

'

'

'

'

'

932,007

809,011

624,518

563,020

307,489

245,991

Granted (in shares)

'

'

'

'

438,036

695,349

518,425

'

438,036

438,036

219,018

219,018

219,018

219,018

Vested (in shares)

'

'

'

'

'

'

'

'

'

-542,938

'

-368,502

'

-174,436

Exercised (in shares)

'

'

'

'

'

'

'

'

-122,996

'

-61,498

'

-61,498

'

Forfeited (in shares)

'

'

'

'

'

'

'

'

-48,437

-48,437

-24,718

-24,718

-23,719

-23,719

Distribution equivalent rights (in shares)

'

'

'

'

'

'

'

'

123,950

123,950

78,040

78,040

45,910

45,910

Balance at the end of the period (in shares)

'

'

'

'

'

'

'

'

1,322,560

779,622

835,360

466,858

487,200

312,764

Additional disclosures

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total unrecognized compensation cost

'

'

'

'

'

'

'

'

'

$5.90

'

'

'

'

Period for expected unrecognized compensation cost to be recognized

'

'

'

'

'

'

'

'

'

'2 years

'

'

'

'

Unit-based compensation costs

'

11.2

7

0.5

'

'

'

'

'

'

'

'

'

'

Cash paid to employees who exercised Phantom Units

'

'

'

'

$2.30

$0

$0

'

'

'

'

'

'

'

Members_Equity_Details_3

Members' Equity (Details 3) (USD $)

3 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

Mar. 31, 2014

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2014

Mar. 31, 2013

Mar. 31, 2012

Apr. 02, 2013

Mar. 31, 2014

Apr. 02, 2013

Mar. 31, 2014

Apr. 02, 2013

Mar. 31, 2014

Apr. 02, 2013

Apr. 02, 2013

Mar. 31, 2014

IDR Holder

IDR Holder

IDR Holder

IDR Holder

IDR Holder

IDR Holder

Unitholders

Unitholders

Minimum Quarterly Distribution

Carlyle/Riverstone Funds

Carlyle/Riverstone Funds

Minimum

Minimum

Maximum

Maximum

Minimum

Maximum

New structure

New structure

New structure

Carlyle/Riverstone Funds

Carlyle/Riverstone Funds

Carlyle/Riverstone Funds

Carlyle/Riverstone Funds

Previous structure

Previous structure

Common Units

Previous structure

Previous structure

Previous structure

Previous structure

Incentive distribution rights

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Marginal Percentage Interest in Cash Distributions

'

'

'

'

'

'

'

'

'

'

'

48.00%

48.00%

13.00%

13.00%

48.00%

48.00%

'

'

'

Total Quarterly Distribution per Unit Target Amount (in dollars per unit)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$0.40

$0.53

$0.35

Period after the end of each quarter within which available cash is distributed to unitholders

'

'

'

'

'

'

'

'

'45 days

'

'

'

'

'

'

'

'

'

'

'

Gross distribution made to the holders of common units and the Managing Member

'

'

'

'

'

'

'

'

$52,300,000

$51,300,000

'

'

'

'

'

'

'

'

'

'

Numerator:

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net earnings (loss) Attributable to Niska Partners

4,330,000

-13,409,000

-7,845,000

7,967,000

-1,277,000

10,419,000

-15,397,000

-37,346,000

-8,957,000

-43,601,000

-165,772,000

'

'

'

'

'

'

'

'

'

Less: Managing Member's interest

'

'

'

'

'

'

'

'

-171,000

-863,000

-3,283,000

'

'

'

'

'

'

'

'

'

Net earnings (loss) attributable to common and subordinated unit holders

'

'

'

'

'

'

'

'

($8,786,000)

($42,738,000)

($162,489,000)

'

'

'

'

'

'

'

'

'

Basic:

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Weighted average units outstanding (in shares)

'

'

'

'

'

'

'

'

34,941,036

68,296,990

68,010,532

'

'

'

'

'

'

'

'

'

Diluted:

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Weighted average units outstanding (in shares)

'

'

'

'

'

'

'

'

34,941,036

68,296,990

68,010,532

'

'

'

'

'

'

'

'

'

Earnings (loss) per unit attributable to the period subsequent to the initial public offering:

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Earnings (loss) per unit allocated to common unitholders - basic and diluted (in dollars per unit)

'

'

'

'

'

'

'

'

($0.25)

($0.63)

($2.39)

'

'

'

'

'

'

'

'

'

Earnings (loss) per unit allocated to subordinated unitholders - basic and diluted (in dollars per unit)

'

'

'

'

'

'

'

'

'

($0.63)

($2.39)

'

'

'

'

'

'

'

'

'

Revenues_Details

Revenues (Details) (USD $)	3 Months Ended		12 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Jun. 30, 2012	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012
Fee-based Revenue	'	'	'	'	'
Long-term contract revenue	'	'	$83,940	$108,615	$116,244
Short-term contract revenue	'	'	51,416	54,710	29,809
Total	'	'	135,356	163,325	146,053
Optimization Revenue	'	'	'	'	'
Realized optimization, net	'	'	85,372	89,525	62,735
Unrealized risk management (loss) gains	'	'	-8,732	-89,874	83,193
Write-down of inventory	-4,600	-22,281	-4,600	-22,281	-23,400
Total	'	'	$72,040	($22,630)	$122,528

Interest_Details

Interest (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012
Interest	'	'	'
Gross interest	$62,961	$66,527	$74,765
Deferred charges amortization	3,354	3,411	3,942
Capitalized interest	'	-2,928	-4,077
Total	$66,315	$67,010	$74,630

Loss_on_extinguishment_of_debt2

Loss on extinguishment of debt (Details) (USD $)	3 Months Ended	12 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012
Loss on extinguishment of debt	'	'	'	'
Premiums paid on redemption / repurchase of 8.875% Senior Notes	'	$28,572	'	$1,770
Deferred charges written off	'	8,125	599	3,091
Total	$36,697	$36,697	$599	$4,861

Related_Party_Transactions_Det

Related Party Transactions (Details) (USD $)	12 Months Ended					0 Months Ended	12 Months Ended
	Mar. 31, 2014	Mar. 31, 2012	Mar. 31, 2013	Mar. 17, 2014	Aug. 24, 2011	Aug. 24, 2011	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012	Mar. 31, 2012	Mar. 31, 2014
				Senior Notes	Senior Notes	Sponsor Holdings	Affiliated entities	Affiliated entities	Affiliated entities	Sponsor Holdings Cooperatief U.A. and R/C Sundance Cooperatief U.A.	Carlyle/Riverstone Funds
										Starks Gas Storage LLC, Coastal Bend Gas Storage LLC, and Sundance Gas Storage ULC
Related Party Transactions	'	'	'	'	'	'	'	'	'	'	'
Amount owing to related parties	$0	'	$0	'	'	'	'	'	'	'	'
Amount owing from related parties	0	'	0	'	'	'	'	'	'	'	'
Management fees charged for administrative services rendered	'	'	'	'	'	'	200,000	200,000	900,000	'	'
Common units issued under DRIP	1,252,815	'	'	'	'	'	'	'	'	'	1,252,810
Non cash earnings distribution and reinvestments	18,270,000	'	'	'	'	'	'	'	'	'	18,300,000
Consideration for purchased net assets	'	'	'	'	'	'	'	'	'	5,000,000	'
Aggregate purchase price recorded as a reduction of equity	'	-2,176,000	'	'	'	'	'	'	2,176,000	'	'
Number of shares issued	'	'	'	'	'	687,500	'	'	'	'	'
Offering price (in dollars per unit)	'	'	'	'	'	$16	'	'	'	'	'
Total proceeds from issuance and sale of common units	'	$11,000,000	'	'	'	$11,000,000	'	'	'	'	'
Interest rate (as a percent)	'	'	'	8.88%	8.88%	'	'	'	'	'	'

Commitments_and_Contingencies_1

Commitments and Contingencies (Details) (USD $)	12 Months Ended
	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012
Commitments and Contingencies	'	'	'
Term for which office lease can be extended	'5 years	'	'
Future minimum lease payments	'	'	'
2015	$11,837,000	'	'
2016	8,937,000	'	'
2017	8,483,000	'	'
2018	6,142,000	'	'
2019	5,512,000	'	'
2020 and thereafter	183,151,000	'	'
Total minimum lease payments	224,062,000	'	'
Total minimum rentals to be received in the future under non-cancelable subleases	2,600,000	'	'
Sublease recoveries	900,000	'	'
Lease and rental expense, net of sublease recoveries	11,900,000	11,200,000	14,900,000
Contingent rent included in lease and rental expense	400,000	300,000	700,000
Unconditional purchase obligations	'	'	'
2015	2,783,323,000	'	'
2016	278,380,000	'	'
2017	65,873,000	'	'
2018	241,193,000	'	'
2019	1,477,000	'	'
Total future purchase commitments	3,370,246,000	'	'
Forward physical and financial sales for all future periods	3,361,100,000	'	'
Issued and outstanding letter of credit to counterparties to support natural gas purchase commitments	$4,800,000	'	'

Changes_in_NonCash_Working_Cap2

Changes in Non-Cash Working Capital (Details) (USD $)	12 Months Ended
	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012
Changes in Non-Cash Working Capital	'	'	'
Margin deposits	($14,137,000)	($39,174,000)	$99,804,000
Trade receivables	-3,383,000	-286,000	-45,000
Accrued receivables	-44,459,000	-40,203,000	9,938,000
Natural gas inventory	3,676,000	125,042,000	-120,563,000
Prepaid expenses and other current assets	358,000	-1,527,000	2,669,000
Other assets	-807,000	-1,105,000	-1,637,000
Trade payables	-149,000	645,000	-316,000
Accrued liabilities	68,108,000	8,456,000	-53,036,000
Income taxes	8,000	-693,000	-579,000
Deferred revenue	5,468,000	-10,667,000	6,498,000
Due from related party	-10,000	1,164,000	732,000
Other long-term liabilities	360,000	381,000	115,000
Net changes in non-cash working capital	15,033,000	42,033,000	-56,420,000
Proceeds from sales of cushion	$0	$32,600,000	$0

Supplemental_Cash_Flow_Disclos2

Supplemental Cash Flow Disclosures (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012
Supplemental Cash Flow Disclosures	'	'	'
Interest paid	$63,769	$67,408	$75,375
Taxes paid (received)	73	-722	988
Interest capitalized	'	2,928	4,077
Non-cash investing activities:	'	'	'
Non-cash (decrease) increase in working capital related to property, plant and equipment	-2,426	-8,605	11,296
Non-cash transfer of natural gas inventory to property, plant and equipment	15,264	'	'
Non-cash financing activities:	'	'	'
Non cash earnings distribution and reinvestments	$18,270	'	'

Segment_Disclosures_Details

Segment Disclosures (Details) (USD $)	3 Months Ended								12 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012
									item	item	item
Segment Disclosures	'	'	'	'	'	'	'	'	'	'	'
Number of reportable segment	'	'	'	'	'	'	'	'	1	1	1
Segment disclosures	'	'	'	'	'	'	'	'	'	'	'
Total revenues	$87,497	$25,847	$36,863	$57,189	$45,106	$73,831	$24,545	($2,787)	$207,396	$140,695	$268,581
Long-lived assets	1,237,248	'	'	'	1,270,024	'	'	'	1,237,248	1,270,024	'
U.S.	'	'	'	'	'	'	'	'	'	'	'
Segment disclosures	'	'	'	'	'	'	'	'	'	'	'
Net realized revenues	'	'	'	'	'	'	'	'	57,628	70,161	70,928
Net unrealized revenues	'	'	'	'	'	'	'	'	142	-37,139	30,489
Long-lived assets	397,331	'	'	'	411,420	'	'	'	397,331	411,420	'
Canada	'	'	'	'	'	'	'	'	'	'	'
Segment disclosures	'	'	'	'	'	'	'	'	'	'	'
Net realized revenues	'	'	'	'	'	'	'	'	158,500	160,408	114,460
Net unrealized revenues	'	'	'	'	'	'	'	'	-8,874	-52,735	52,704
Long-lived assets	$839,917	'	'	'	$858,604	'	'	'	$839,917	$858,604	'

Economic_Dependence_Details

Economic Dependence (Details) (Total gross revenue, Other customers)	12 Months Ended
	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012
	Total gross revenue	Total gross revenue	Total gross revenue
	item	item	item
Total gross revenue | Other customers	'	'	'
Economic Dependence	'	'	'
Number of customers that comprise greater than 10% of total gross revenue, other than the clearing and settlement facility	0	0	0
Concentration risk percentage	10.00%	10.00%	10.00%

Subsequent_Events_Details

Subsequent Events (Details) (USD $)	12 Months Ended		0 Months Ended	12 Months Ended	0 Months Ended
	Mar. 31, 2014	Mar. 31, 2014	Mar. 31, 2014	Mar. 31, 2014	1-May-14	1-May-14
		Carlyle/Riverstone Funds	Subsequent events	Subsequent events	Subsequent events	Subsequent events
				Carlyle/Riverstone Funds	Old agreement with TransCanada	New agreement with TransCanada
					MMcf	MMcf
Subsequent events	'	'	'	'	'	'
Volume of storage capacity (in million cubic feet)	'	'	'	'	40,000	40,000
Interval option period after which agreement can be terminated	'	'	'	'	'5 years	'
Reduced volume of storage capacity after three years (in billion cubic feet)	'	'	'	'	'	20,000
Distribution declared and paid to common unitholders	'	'	$12,800,000	'	'	'
Additional common units issued under DRIP	'	'	'	445,144	'	'
Non cash earnings distribution and reinvestments	$18,270,000	$18,300,000	'	$6,400,000	'	'

Quarterly_Financial_Data_Detai

Quarterly Financial Data (Details) (USD $)	3 Months Ended								12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012
Quarterly Financial Data	'	'	'	'	'	'	'	'	'	'	'
Revenue, net	$87,497	$25,847	$36,863	$57,189	$45,106	$73,831	$24,545	($2,787)	$207,396	$140,695	$268,581
Earnings (loss) before income taxes	635	-19,718	-7,797	7,667	-1,018	9,877	-22,115	-49,287	-19,213	-62,543	-185,459
Net earnings (loss) and comprehensive income (loss)	4,330	-13,409	-7,845	7,967	-1,277	10,419	-15,397	-37,346	-8,957	-43,601	-165,772
Earnings (loss) per unit	$0.12	($0.37)	($0.22)	$0.23	($0.02)	$0.15	($0.22)	($0.54)	($0.25)	($0.63)	($2.39)
Loss on extinguishment of debt	-36,697	'	'	'	'	'	'	'	-36,697	-599	-4,861
Write-down of inventory	$4,600	'	'	'	'	'	'	$22,281	$4,600	$22,281	$23,400