Derivative Financial Instruments

6 Months Ended

Jun. 30, 2016

Derivative Instruments Not Designated as Hedging Instruments [Abstract]

Derivative Financial Instruments

Note 10 - Derivative Financial Instruments

Summary of Oil, Gas, and NGL Derivative Contracts in Place

The Company has entered into various commodity derivative contracts to mitigate a portion of its exposure to potentially adverse market changes in commodity prices and the associated impact on cash flows. All contracts are entered into for other-than-trading purposes. The Company’s derivative contracts consist of swap and collar arrangements for oil, gas, and NGLs. In a typical commodity swap agreement, if the agreed upon published third-party index price (“index price”) is lower than the swap fixed price, the Company receives the difference between the index price and the agreed upon swap fixed price. If the index price is higher than the swap fixed price, the Company pays the difference.  For collar arrangements, the Company receives the difference between an agreed upon index and the floor price if the index price is below the floor price. The Company pays the difference between the agreed upon ceiling price and the index price if the index price is above the ceiling price. No amounts are paid or received if the index price is between the floor and ceiling prices.

As of June 30, 2016, the Company had commodity derivative contracts outstanding through the second quarter of 2020 as summarized in the tables below. During the three months ended March 31, 2016, the Company restructured certain of its gas derivative contracts by buying fixed price volumes to offset existing 2018 and 2019 fixed price swap contracts totaling 55.0 million MMBtu. The Company then entered into new 2017 fixed price swap contracts totaling 38.6 million MMBtu with a contract price of $4.43 per MMBtu. No cash or other consideration was included as part of the restructuring.

Subsequent to June 30, 2016, the Company entered into derivative fixed price swap contracts through the first quarter of 2018 for a total of 15.6 million MMBtu of gas production at contract prices ranging from $2.90 to $3.24 per MMBtu, and derivative fixed price swap contracts through the fourth quarter of 2018 for 1.4 million Bbls of NGL production at contract prices ranging from $21.32 per Bbl to $21.79 per Bbl. Additionally, subsequent to June 30, 2016, the Company entered into a derivative collar contract through the fourth quarter of 2017 for a total of 1.4 million Bbls of crude oil production with a contract floor price of $45.00 per Bbl and a contract ceiling price of $56.25 per Bbl.

The following tables summarize the approximate volumes and average contract prices of contracts the Company had in place as of June 30, 2016:

Oil Swaps

Contract Period	NYMEX WTI Volumes	Weighted-Average  Contract Price
	(MBbls)	(per Bbl)
Third quarter 2016	1,840	$	71.80
Fourth quarter 2016	1,399	$	67.73
2017	3,053	$	45.61
All oil swaps	6,292

Oil Collars

Contract Period	NYMEX WTI  Volumes	Weighted- Average Floor  Price		Weighted- Average Ceiling  Price
	(MBbls)	(per Bbl)		(per Bbl)
Third quarter 2016	672	$	40.00	$	51.57
Fourth quarter 2016	881	$	40.00	$	51.52
2017	1,018	$	45.00	$	51.02
All oil collars	2,571

Natural Gas Swaps

Contract Period	Sold Volumes	Weighted-Average  Contract Price		Purchased Volumes		Weighted- Average Contract Price		Net Volumes
	(BBtu)	(per MMBtu)		(BBtu)		(per MMBtu)		(BBtu)
Third quarter 2016	25,724	$	3.13	—		$	—	25,724
Fourth quarter 2016	26,700	$	3.34	—		$	—	26,700
2017	88,894	$	4.04	—		$	—	88,894
2018	53,048	$	3.75	(30,606	)	$	4.27	22,442
2019	24,415	$	4.34	(24,415	)	$	4.34	—
All gas swaps*	218,781			(55,021	)			163,760

*Total net volumes of natural gas swaps are comprised of IF El Paso Permian (2%), IF HSC (97%), and IF NNG Ventura (1%).

NGL Swaps

	OPIS Purity Ethane Mont Belvieu			OPIS Propane Mont Belvieu Non-TET			OPIS Normal Butane Mont Belvieu Non-TET			OPS Isobutane Mont Belvieu Non-TET
Contract Period	Volumes	Weighted-Average  Contract Price		Volumes	Weighted-Average Contract Price		Volumes	Weighted-Average Contract Price		Volumes	Weighted-Average Contract Price
	(MBbls)	(per Bbl)		(MBbls)	(per Bbl)		(MBbls)	(per Bbl)		(MBbls)	(per Bbl)
Third quarter 2016	751	$	8.70	863	$	19.03	248	$	22.90	200	$	23.24
Fourth quarter 2016	687	$	8.71	792	$	18.53	226	$	22.91	182	$	23.25
2017	3,062	$	8.92	721	$	20.01	—	$	—	—	$	—
2018	2,435	$	10.18	—	$	—	—	$	—	—	$	—
2019	1,200	$	10.92	—	$	—	—	$	—	—	$	—
2020	539	$	11.13	—	$	—	—	$	—	—	$	—
Total NGL swaps	8,674			2,376			474			382

Derivative Assets and Liabilities Fair Value

The Company’s commodity derivatives are measured at fair value and are included in the accompanying balance sheets as derivative assets and liabilities. The fair value of the commodity derivative contracts was a net asset of $90.5 million as of June 30, 2016, and a net asset of $488.4 million as of December 31, 2015.

The following tables detail the fair value of derivatives recorded in the accompanying balance sheets, by category:

	As of June 30, 2016
	Derivative Assets			Derivative Liabilities
	Balance Sheet  Classification	Fair Value		Balance Sheet  Classification	Fair Value
	(in thousands)
Commodity contracts	Current assets	$	145,576	Current liabilities	$	63,492
Commodity contracts	Noncurrent assets	113,119		Noncurrent liabilities	104,660
Derivatives not designated as hedging instruments		$	258,695		$	168,152

	As of December 31, 2015
	Derivative Assets			Derivative Liabilities
	Balance Sheet  Classification	Fair Value		Balance Sheet  Classification	Fair Value
	(in thousands)
Commodity contracts	Current assets	$	367,710	Current liabilities	$	8
Commodity contracts	Noncurrent assets	120,701		Noncurrent liabilities	—
Derivatives not designated as hedging instruments		$	488,411		$	8

Offsetting of Derivative Assets and Liabilities

As of June 30, 2016, and December 31, 2015, all derivative instruments held by the Company were subject to master netting arrangements with various financial institutions. In general, the terms of the Company’s agreements provide for offsetting of amounts payable or receivable between it and the counterparty, at the election of both parties, for transactions that settle on the same date and in the same currency. The Company’s agreements also provide that in the event of an early termination, the counterparties have the right to offset amounts owed or owing under that and any other agreement with the same counterparty. The Company’s accounting policy is to not offset these positions in its accompanying balance sheets.  

The following table provides a reconciliation between the gross assets and liabilities reflected on the accompanying balance sheets and the potential effects of master netting arrangements on the fair value of the Company’s derivative contracts:

	Derivative Assets						Derivative Liabilities
	As of						As of
Offsetting of Derivative Assets and Liabilities	June 30, 2016			December 31, 2015			June 30, 2016			December 31, 2015
	(in thousands)
Gross amounts presented in the accompanying balance sheets	$	258,695		$	488,411		$	(168,152	)	$	(8	)
Amounts not offset in the accompanying balance sheets	(158,955		)	(8		)	158,955			8
Net amounts	$	99,740		$	488,403		$	(9,197	)	$	—

The following table summarizes the components of the derivative (gain) loss presented in the accompanying statements of operations:

	For the Three Months Ended June 30,						For the Six Months Ended June 30,
	2016			2015			2016			2015
	(in thousands)
Derivative settlement (gain) loss:
Oil contracts	$	(72,164	)	$	(73,915	)	$	(172,156	)	$	(180,129	)
Gas contracts (1)	(31,439		)	(38,880		)	(72,492		)	(73,112		)
NGL contracts	1,893			—			(4,090		)	(20,783		)
Total derivative settlement (gain) loss	$	(101,710	)	$	(112,795	)	$	(248,738	)	$	(274,024	)
Total derivative (gain) loss:
Oil contracts	$	60,773		$	66,749		$	50,341		$	(7,111	)
Gas contracts	62,489			6,070			38,466			(76,269		)
NGL contracts	40,089			8,110			60,316			10,142
Total derivative (gain) loss:	$	163,351		$	80,929		$	149,123		$	(73,238	)

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⁽¹⁾   Natural gas derivative settlements for the three and six months ended June 30, 2015, include a $15.3 million gain on the early settlement of future contracts as a result of divesting our Mid-Continent assets during the second quarter of 2015.

Credit Related Contingent Features

As of June 30, 2016, and through the filing date of this report, all of the Company’s derivative counterparties were members of the Company’s credit facility lender group. The Amended Credit Agreement, as discussed above, changed the required percentage of oil and gas properties subject to a mortgage to at least 90 percent of the total PV-9 of the Company’s proved oil and gas properties evaluated in the most recent reserve report.