Note 7 — Other Long-term Obligations

Other long-term obligations consisted of the following (in thousands):


	March 31, 2012			December 31, 2011
Net profits interests	$	298,944		$	336,669
Dollar-denominated overriding royalty interests		214,387			42,324
Gomez pipeline obligation		71,110			71,676
Vendor deferrals – Gulf of Mexico		15,071			17,493
Vendor deferrals – North Sea		103,579			94,710
Other		2,582			2,582

Total		705,673			565,454
Less current maturities		(111,246	)		(113,657	)

Other long-term obligations	$	594,427		$	451,797

Net Profits Interests – Beginning in 2009, we have granted dollar-denominated overriding royalty interests in the form of net profits interests ("NPIs") in certain of our proved oil and gas properties in and around the Telemark Hub, Gomez Hub and Clipper to certain of our vendors in exchange for oil and gas property development services and to certain investors in exchange for cash proceeds.

The interests granted are paid solely from the net profits, as defined, of the subject properties. As the net profits increase or decrease, primarily through higher or lower production levels and higher or lower prices of oil and natural gas, the payments due the holders of the net profits interests increase or decrease accordingly. If there is no production from a property or if the net profits are negative during a payment period, no payment is required. We also accrete the liability over the estimated term in which the NPI is expected to be settled using the effective interest method with related interest expense presented net of amounts capitalized on the Consolidated Statements of Operations. The term of the NPIs is dependent on the value of the services contributed by these vendors or the cash proceeds contributed by the investor coupled with the timing of production and future economic conditions, including commodity prices and operating costs. Upon recovery of the agreed rate of return, the NPIs terminate and our net interest increases accordingly. Because NPIs are granted on proved properties where production is reasonably assured, they are reflected as financing obligations on our Consolidated Balance Sheets. As such, the reserves and production revenues associated with the NPIs are retained by the Company. We expect approximately 63%, or $189.8 million of the NPIs to be repaid over the next 12 months based on anticipated production, commodity prices and operating costs.

Dollar-denominated Overriding Royalty Interests – During the first quarter of 2012, we sold, for an aggregate of $185.0 million, limited-term dollar-denominated overriding royalty interests ("Overrides") in our Gomez Hub and Clipper properties similar to Overrides sold previously. These Overrides obligate us to deliver proceeds from the future sale of hydrocarbons in the specified proved properties until the purchasers achieve a specified return. As the proceeds from the sale of hydrocarbons increase or decrease, primarily through changes in production levels and oil and natural gas prices, the payments due the holders of the Overrides will increase or decrease accordingly. If there is no production from a property during a payment period, no payment is required. The percentage of property revenues available to satisfy these obligations is dependent upon certain conditions specified in the agreement. Upon recovery of the agreed rate of return, the Overrides terminate and our interest increases accordingly. Because of the explicit rate of return, dollar-denomination and limited payment terms of the Overrides, they are reflected in the accompanying financial statements as financing obligations. As such, the reserves and production revenues are retained by the Company. Related interest expense is presented net of amounts capitalized on the Consolidated Statements of Operations. As of March 31, 2012, if there is sufficient production from a certain property, we will incur up to $5.8 million of contingent interest costs through the remaining life of the Override. We expect approximately 74%, or $159.8 million of the Overrides to be repaid over the next 12 months based on anticipated production and commodity prices.

Gomez Pipeline Obligation – In 2009, we sold to a third party for net proceeds of $74.5 million the oil and natural gas pipelines that service the Gomez Hub. In conjunction with the sale, we entered into agreements with the purchaser to transport our oil and natural gas production for the remaining production life of our fields serviced by the ATP Innovator production platform for a per-unit fee that is subject to a minimum monthly payment through December 31, 2016. Such minimum fees, if applicable, can be recovered by the Company in future periods within the same calendar year whenever fees owed during a month exceed the minimum due. We remain the operator of the pipeline and are responsible for all of the related operating costs. As a result of the retained asset retirement obligation and the purchaser's option to convey the pipeline to us at the end of the life of the fields in the Gomez Hub, the transaction has been accounted for as a financing obligation equal to the net proceeds received. This obligation is being amortized based on the estimated proved reserve life of the Gomez Hub properties using the effective interest method with related interest expense presented net of amounts capitalized on the Consolidated Statements of Operations. All payments made in excess of the minimum fee in future periods will be reflected as interest expense of the financing obligation.

Vendor Deferrals – In the Gulf of Mexico, in addition to the NPIs exchanged for development services described above, we have negotiated with certain other vendors involved in the development of the Telemark and Gomez Hubs to partially defer payments over a twelve-month period beginning with first production. We accrue the present value of the deferred payments and accrete the balance over the estimated term over which it is expected to be paid using the effective interest method with related interest expense presented net of amounts capitalized, on the Consolidated Statements of Operations.

In the North Sea, development of our interest in the Cheviot field continues. During February 2012, we entered into an amendment to one of our agreements for the construction and delivery of the Octabuoy hull and topside utility module to defer the final payments until April 2013. As of March 31, 2012 $103.6 million has been accrued and, as construction continues, we expect this amount to increase to $210.1 million of which $125.0 million is due in April 2013 and $85.1 million is due upon delivery of the topside utility module which is expected in the fourth quarter of 2013. As work is completed and amounts are earned under the amended agreement, we record obligations and related interest expense, net of amounts capitalized, on the Consolidated Financial Statements.

Effective Interest Rate – The weighted average effective interest rate on our other long-term obligations set forth above was 18.5% and 18.9% at March 31, 2012 and December 31, 2011, respectively.