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Derivative and Hedging Activities (Note)
 6 Months Ended
Jun. 30, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]  
Derivative and Hedging Activities Disclosure
Derivative and Hedging Activities
Chesapeake uses commodity derivative instruments to secure attractive pricing and margins on its share of expected production, to reduce its exposure to fluctuations in future commodity prices and to protect its expected operating cash flow against significant market movements or volatility. Chesapeake also uses derivative instruments to mitigate a portion of its exposure to interest rate and foreign currency exchange rate fluctuations. All of our commodity derivative instruments are net settled based on the difference between the fixed-price payment and the floating-price payment, resulting in a net amount due to or from the counterparty.
Oil and Natural Gas Derivatives
As of June 30, 2015 and December 31, 2014, our oil and natural gas derivative instruments consisted of the following types of instruments:
•
Swaps: Chesapeake receives a fixed price and pays a floating market price to the counterparty for the hedged commodity.
•
Collars: These instruments contain a fixed floor price (put) and ceiling price (call). If the market price exceeds the call strike price or falls below the put strike price, Chesapeake receives the fixed price and pays the market price. If the market price is between the put and the call strike prices, no payments are due from either party. Three-way collars include an additional put option in exchange for a more favorable strike price on the call option. This eliminates the counterparty’s downside exposure below the second put option strike price.
•
Options: Chesapeake sells, and occasionally buys, call options in exchange for a premium. At the time of settlement, if the market price exceeds the fixed price of the call option, Chesapeake pays the counterparty the excess on sold call options, and Chesapeake receives the excess on bought call options. If the market price settles below the fixed price of the call option, no payment is due from either party.
•
Basis Protection Swaps: These instruments are arrangements that guarantee a fixed price differential to NYMEX from a specified delivery point. Chesapeake receives the fixed price differential and pays the floating market price differential to the counterparty for the hedged commodity.
The estimated fair values of our oil and natural gas derivative instrument assets (liabilities) as of June 30, 2015 and December 31, 2014 are provided below. 
 
 
June 30, 2015
 
December 31, 2014
 
 
Volume
 
Fair Value
 
Volume
 
Fair Value
 
 
 
 
($ in millions)  
 
 
 
($ in millions)  
Oil (mmbbl):
 
 
 
 
 
 
 
 
Fixed-price swaps
 
7.4

 
$
196

 
12.5

 
$
471

Three-way collars
 
2.2

 
21

 
4.4

 
40

Call options
 
27.9

 
(26
)
 
35.8

 
(89
)
Basis protection swaps
 
4.5

 
4

 
—

 
—

Total oil
 
42.0

 
$
195

 
52.7

 
$
422

 
 
 
 
 
 
 
 
 
Natural gas (tbtu):
 
 
 
 
 
 
 
 
Fixed-price swaps
 
260

 
$
135

 
275

 
$
281

Three-way collars
 
71

 
51

 
207

 
165

Call options
 
193

 
(128
)
 
193

 
(170
)
Basis protection swaps
 
80

 
5

 
60

 
23

Total natural gas
 
604

 
$
63

 
735

 
$
299

Total estimated fair value
 
 
 
$
258

 
 
 
$
721


 We have terminated certain commodity derivative contracts that were previously designated as cash flow hedges for which the hedged production is still expected to occur. See further discussion below under Effect of Derivative Instruments – Accumulated Other Comprehensive Income (Loss).
Interest Rate Derivatives
As of June 30, 2015 and December 31, 2014, our interest rate derivative instruments consisted of swaps. We enter into fixed-to-floating interest rate swaps (we receive a fixed interest rate and pay a floating market rate) to mitigate our exposure to changes in the fair value of our senior notes. We enter into floating-to-fixed interest rate swaps (we receive a floating market rate and pay a fixed interest rate) to manage our interest rate exposure related to our bank credit facility borrowings.
The notional amount of our interest rate derivatives associated with our long-term debt as of June 30, 2015 and December 31, 2014 was $400 million and $850 million, respectively. The estimated fair value of our interest rate derivative liabilities as of June 30, 2015 and December 31, 2014 was a nominal amount and $17 million, respectively.
We have terminated certain fair value hedges related to senior notes. Gains and losses related to these terminated hedges will be amortized as an adjustment to interest expense over the remaining term of the related senior notes. Over the next six years, we will recognize $8 million in net gains related to these transactions.
Foreign Currency Derivatives
We are party to cross currency swaps to mitigate our exposure to foreign currency exchange rate fluctuations that may result from the €344 million principal amount of our euro-denominated senior notes. The terms of the cross currency swaps were based on the dollar/euro exchange rate on the issuance date of $1.3325 to €1.00. Under the terms of the cross currency swaps we currently hold, on each semi-annual interest payment date, the counterparties pay us €11 million and we pay the counterparties $17 million, which yields an annual dollar-equivalent interest rate of 7.491%. Upon maturity of the notes, the counterparties will pay us €344 million and we will pay the counterparties $459 million. The swaps are designated as cash flow hedges and, because they are entirely effective in having eliminated any potential variability in our expected cash flows related to changes in foreign exchange rates, changes in their fair value do not impact earnings. The fair values of the cross currency swaps are recorded on the condensed consolidated balance sheets as liabilities of $88 million and $53 million as of June 30, 2015 and December 31, 2014, respectively. The euro-denominated debt in long-term debt has been adjusted to $384 million as of June 30, 2015, using an exchange rate of $1.1147 to €1.00.
Supply Contract Derivatives

From time to time and in the normal course of business, our marketing subsidiary enters into supply contracts under which we commit to deliver a predetermined quantity of natural gas to certain counterparties in an attempt to earn attractive margins. Under certain contracts, we receive a sales price that is based on the price of a product other than natural gas thereby creating an embedded derivative requiring bifurcation. As of June 30, 2015, two supply contracts comprise our supply contract derivatives.
 
In the Current Quarter, we were required to bifurcate a derivative embedded within one of our supply contracts. Under this contract, we are committed to supply approximately 90,000 mmbtu per day of natural gas through March 2025. In the Current Quarter and the Current Period, we recorded revenues of approximately $27 million for settlements of this embedded derivative. As of June 30, 2015, the bifurcated derivative was measured to fair value, which resulted in a $221 million unrealized gain. Both settlements and mark-to market gains (losses) are included in marketing, gathering and compression revenues in our condensed consolidated statements of operations.
Effect of Derivative Instruments – Condensed Consolidated Balance Sheets
The following table presents the fair value and location of each classification of derivative instrument included in the condensed consolidated balance sheets as of June 30, 2015 and December 31, 2014 on a gross basis and after same-counterparty netting: 
Balance Sheet Classification
 
Gross
Fair Value
 
Amounts Netted
in Condensed Consolidated
Balance Sheet
 
Net Fair Value Presented
in Condensed Consolidated
Balance Sheet
 
 
($ in millions)
As of June 30, 2015
 
 
 
 
 
 
Commodity Contracts:
 
 
 
 
 
 
Short-term derivative asset
 
$
426

 
$
(74
)
 
$
352

Short-term derivative liability
 
(101
)
 
74

 
(27
)
Long-term derivative liability
 
(67
)
 
—

 
(67
)
Total commodity contracts
 
258

 
—

 
258

 
 
 
 
 
 
 
Interest Rate Contracts:
 
 
 
 
 
 
Short-term derivative liability
 
—

 
—

 
—

Total interest rate contracts
 
—

 
—

 
—

 
 
 
 
 
 
 
Foreign Currency Contracts:(a)
 
 
 
 
 
 
Long-term derivative liability
 
(88
)
 
—

 
(88
)
Total foreign currency contracts
 
(88
)
 
—

 
(88
)
 
 
 
 
 
 
 
Supply Contracts:
 
 
 
 
 
 
Short-term derivative asset
 
35

 
—

 
35

Long-term derivative asset
 
186

 
—

 
186

Total supply contracts
 
221

 
—

 
221

 
 
 
 
 
 
 
Total derivatives
 
$
391

 
$
—

 
$
391

 
 
 
 
 
 
 
 
 
 
 
 
 
 
Balance Sheet Classification
 
Gross
Fair Value
 
Amounts Netted
in Condensed Consolidated
Balance Sheet
 
Net Fair Value Presented
in Condensed Consolidated
Balance Sheet
As of December 31, 2014
 
 
 
 
 
 
Commodity Contracts:
 
 
 
 
 
 
Short-term derivative asset
 
$
974

 
$
(95
)
 
$
879

Long-term derivative asset
 
16

 
(10
)
 
6

Short-term derivative liability
 
(105
)
 
95

 
(10
)
Long-term derivative liability
 
(163
)
 
10

 
(153
)
Total commodity contracts
 
722

 
—

 
722

 
 
 
 
 
 
 
Interest Rate Contracts:
 
 
 
 
 
 
Short-term derivative liability
 
(5
)
 
—

 
(5
)
Long-term derivative liability
 
(12
)
 
—

 
(12
)
Total interest rate contracts
 
(17
)
 
—

 
(17
)
 
 
 
 
 
 
 
Foreign Currency Contracts:(a)
 
 
 
 
 
 
Long-term derivative liability
 
(53
)
 
—

 
(53
)
Total foreign currency contracts
 
(53
)
 
—

 
(53
)
 
 
 
 
 
 
 
Total derivatives
 
$
652

 
$
—

 
$
652

____________________________________________
(a)
Designated as cash flow hedging instruments.
As of June 30, 2015 and December 31, 2014, we did not have any cash collateral balances for these derivatives.
Effect of Derivative Instruments – Condensed Consolidated Statements of Operations
The components of oil, natural gas and NGL sales for the Current Quarter, the Prior Quarter, the Current Period and the Prior Period are presented below. 
 
 
Three Months Ended
June 30,
 
Six Months Ended
June 30,
 
 
2015
 
2014
 
2015
 
2014
 
 
($ in millions)
Oil, natural gas and NGL sales
 
$
776

 
$
1,917

 
$
1,700

 
$
4,065

Gains (losses) on undesignated oil and natural gas derivatives
 
(43
)
 
(210
)
 
135

 
(574
)
Losses on terminated cash flow hedges
 
(5
)
 
(3
)
 
(22
)
 
(20
)
Total oil, natural gas and NGL sales
 
$
728

 
$
1,704

 
$
1,813

 
$
3,471

The components of marketing, gathering and compression sales for the Current Quarter, the Prior Quarter, the Current Period and the Prior Period are presented below.
 
 
Three Months Ended
June 30,
 
Six Months Ended
June 30,
 
 
2015
 
2014
 
2015
 
2014
 
 
($ in millions)
Marketing, gathering and compression sales(a)
 
$
2,085

 
$
3,167

 
$
3,760

 
$
6,182

Gains on undesignated supply contract derivatives
 
220

 
—

 
220

 
—

Total marketing, gathering and compression sales
 
$
2,305

 
$
3,167

 
$
3,980

 
$
6,182

____________________________________________
(a)
Current Quarter and Current Period settlements of $27 million on supply contracts accounted for as derivatives are reflected in marketing, gathering and compression revenues.
The components of interest expense for the Current Quarter, the Prior Quarter, the Current Period and the Prior Period are presented below. 
 
 
Three Months Ended
June 30,
 
Six Months Ended
June 30,
 
 
2015
 
2014
 
2015
 
2014
 
 
($ in millions)
Interest expense on senior notes
 
$
171

 
$
184

 
$
342

 
$
364

Interest expense on term loan
 
—

 
7

 
—

 
36

Amortization of loan discount, issuance costs and other
 
12

 
16

 
23

 
35

Interest expense on credit facilities
 
3

 
9

 
6

 
17

Gains on terminated fair value hedges
 
(1
)
 
(1
)
 
(2
)
 
(2
)
Gains on undesignated interest rate derivatives
 
—

 
(33
)
 
(10
)
 
(51
)
Capitalized interest
 
(114
)
 
(155
)
 
(237
)
 
(333
)
Total interest expense
 
$
71

 
$
27

 
$
122

 
$
66


Effect of Derivative Instruments – Accumulated Other Comprehensive Income (Loss)
A reconciliation of the changes in accumulated other comprehensive income (loss) in our condensed consolidated statements of stockholders’ equity related to our cash flow hedges is presented below. 
 
 
Three Months Ended June 30,
 
 
2015
 
2014
 
 
Before 
Tax  
 
After 
Tax  
 
Before 
Tax  
 
After 
Tax  
 
 
($ in millions)
Balance, beginning of period
 
$
(216
)
 
$
(134
)
 
$
(247
)
 
$
(153
)
Net change in fair value
 
—

 
—

 
1

 
—

(Gains) losses reclassified to income
 
5

 
3

 
3

 
(1
)
Balance, end of period
 
$
(211
)
 
$
(131
)
 
$
(243
)
 
$
(154
)
 
 
 
 
 
 
 
 
 
 
 
Six Months Ended June 30,
 
 
2015
 
2014
 
 
Before 
Tax  
 
After 
Tax  
 
Before 
Tax  
 
After 
Tax  
 
 
($ in millions)
Balance, beginning of period
 
$
(231
)
 
$
(143
)
 
$
(269
)
 
$
(167
)
Net change in fair value
 
(2
)
 
(1
)
 
6

 
3

Losses reclassified to income
 
22

 
13

 
20

 
10

Balance, end of period
 
$
(211
)
 
$
(131
)
 
$
(243
)
 
$
(154
)
Approximately $123 million of the $131 million of accumulated other comprehensive loss as of June 30, 2015 represented the net deferred loss associated with commodity derivative contracts that were previously designated as cash flow hedges for which the hedged production is still expected to occur. Deferred gain or loss amounts will be recognized in earnings in the month in which the originally forecasted hedged production occurs. As of June 30, 2015, we expect to transfer approximately $20 million of net loss included in accumulated other comprehensive income to net income (loss) during the next 12 months. The remaining amounts will be transferred by December 31, 2022.
Credit Risk Considerations
Over-the-counter traded derivative instruments and our supply contracts expose us to our counterparties’ credit risk. To mitigate this risk, we enter into derivative contracts only with counterparties that are rated investment grade and deemed by management to be competent and competitive market makers, and we attempt to limit our exposure to non-performance by any single counterparty. As of June 30, 2015, our oil, natural gas, interest rate and supply contract derivative instruments were spread among 17 counterparties.
Hedging Arrangements
As of June 30, 2015, our secured commodity hedging facility with 11 counterparties provided approximately 465 mmboe of hedging capacity for oil, natural gas and NGL price derivatives and 465 mmboe for basis derivatives with an aggregate mark-to-market capacity of $7.4 billion. The facility is secured by proved reserves, the value of which must cover the fair value of the transactions outstanding under the facility by at least 1.65 times at semi-annual collateral redetermination dates and 1.30 times in between those dates, and guarantees by certain subsidiaries that also guarantee our revolving credit facility and indentures. Chesapeake has significant flexibility with regard to releases and/or substitutions of pledged reserves, provided that certain requirements are met including maintaining specified collateral coverage ratios as well as maintaining credit ratings with either of the designated rating agencies at or above current levels. The counterparties’ obligations under the facility must be secured by cash or short-term U.S. treasury instruments to the extent that any mark-to-market amounts they owe Chesapeake exceed defined thresholds. As of June 30, 2015, we had hedged under the facility 40.5 mmboe of our future production with price derivatives and 2.3 mmboe with basis derivatives.
In April 2015, we also began entering into bilateral hedging agreements with the intention of replacing and terminating the respective counterparties’ positions in the secured hedging facility. In the Current Quarter, we entered into bilateral arrangements that reduced the aggregate mark-to-market capacity under the secured hedging facility from $16.5 billion to $7.4 billion. The counterparties’ obligations under the bilateral hedging agreements must be secured by cash or letters of credit to the extent that any mark-to-market amounts they owe Chesapeake exceed defined thresholds. As of June 30, 2015, we had hedged under bilateral agreements 84.2 mmboe of our future production with price derivatives and 15.6 mmboe with basis derivatives.
Fair Value
The fair value of our derivatives is based on third-party pricing models which utilize inputs that are either readily available in the public market, such as oil and natural gas forward curves and discount rates, or can be corroborated from active markets or broker quotes. These values are compared to the values given by our counterparties for reasonableness. Since oil, natural gas, interest rate and cross currency swaps do not include optionality and therefore generally have no unobservable inputs, they are classified as Level 2. All other derivatives have some level of unobservable input, such as volatility curves, and are therefore classified as Level 3. Derivatives are also subject to the risk that either party to a contract will be unable to meet its obligations. We factor non-performance risk into the valuation of our derivatives using current published credit default swap rates. To date, this has not had a material impact on the values of our derivatives.
The following table provides information for financial assets (liabilities) measured at fair value on a recurring basis as of June 30, 2015 and December 31, 2014: 
 
 
Quoted
Prices in
Active
Markets
(Level 1)
 
Significant
Other
Observable
Inputs
(Level 2) 
 
Significant
Unobservable
Inputs
(Level 3)
 
Total
Fair Value
 
 
 
 
($ in millions)
 
 
As of June 30, 2015
 
 
 
 
 
 
 
 
Derivative Assets (Liabilities):
 
 
 
 
 
 
 
 
Commodity assets
 
$
—

 
$
353

 
$
73

 
$
426

Commodity liabilities
 
—

 
(13
)
 
(155
)
 
(168
)
Interest rate liabilities
 
—

 
—

 
—

 
—

Foreign currency liabilities
 
—


(88
)
 
—

 
(88
)
Supply contract assets
 
—

 
—

 
221

 
221

Total derivatives
 
$
—

 
$
252

 
$
139

 
$
391

 
 
 
 
 
 
 
 
 
As of December 31, 2014
 
 
 
 
 
 
 
 
Derivative Assets (Liabilities):
 
 
 
 
 
 
 
 
Commodity assets
 
$
—

 
$
784

 
$
205

 
$
989

Commodity liabilities
 
—

 
(9
)
 
(259
)
 
(268
)
Interest rate liabilities
 
—

 
(17
)
 
—

 
(17
)
Foreign currency liabilities
 
—

 
(53
)
 
—

 
(53
)
Supply contract assets
 
—

 
—

 
1

 
1

Total derivatives
 
$
—

 
$
705

 
$
(53
)
 
$
652


A summary of the changes in the fair values of Chesapeake’s financial assets (liabilities) classified as Level 3 during the Current Period and the Prior Period is presented below. 
 
 
Commodity
Derivatives
 
Supply
Contracts
 
 
($ in millions)
Beginning balance as of January 1, 2015
 
$
(54
)
 
$
1

Total gains (losses) (realized/unrealized):
 
 
 
 
Included in earnings(a)
 
80

 
220

Total purchases, issuances, sales and settlements:
 
 
 
 
Settlements
 
(108
)
 
—

Ending balance as of June 30, 2015
 
$
(82
)
 
$
221

 
 
 
 
 
Beginning balance as of January 1, 2014
 
$
(478
)
 
$
—

Total gains (losses) (realized/unrealized):
 
 
 
 
Included in earnings(a)
 
(173
)
 
—

Total purchases, issuances, sales and settlements:
 
 
 
 
Settlements
 
105

 
—

Transfers(b)
 
(4
)
 
—

Ending balance as of June 30, 2014
 
$
(550
)
 
$
—

___________________________________________
(a)
 
Oil, Natural Gas
and NGL
Sales
 
Marketing, Gathering and Compression Revenue
 
 
 
2015
 
2014
 
2015
 
2014
 
 
($ in millions)
Total gains (losses) included in earnings for the period
 
$
80

 
$
(173
)
 
$
220

 
$
—

Change in unrealized gains (losses) related to assets still held at reporting date
 
$
69

 
$
(133
)
 
$
220

 
$
—

(b)
The values related to basis swaps were transferred from Level 3 to Level 2 as a result of our ability to begin using data readily available in the public market to corroborate our estimated fair values.
Qualitative and Quantitative Disclosures about Unobservable Inputs for Level 3 Fair Value Measurements
The significant unobservable inputs for Level 3 derivative contracts include unpublished forward prices of oil and natural gas market volatility and credit risk of counterparties. Changes in these inputs impact the fair value measurement of our derivative contracts. For example, an increase or decrease in the forward prices and volatility of oil and natural gas prices decreases or increases the fair value of oil and natural gas derivatives and adverse changes to our counterparties’ creditworthiness decreases the fair value of our derivatives. The following table presents quantitative information about Level 3 inputs used in the fair value measurement of our commodity derivative contracts at fair value as of June 30, 2015:
Instrument
Type
 
Unobservable
Input
 
Range
 
Weighted
Average
 
Fair Value
June 30, 2015
 
 
 
 
 
 
 
 
($ in millions)
Oil trades(a)
 
Oil price volatility curves
 
19.51% – 32.31%
 
26.97%
 
$
(5
)
Supply contracts(b)
 
Oil price volatility curves
 
16.55% – 33.27%
 
20.05%
 
$
221

Natural gas trades(a)
 
Natural gas price volatility
curves
 
20.47% – 56.46%
 
32.19%
 
$
(77
)
___________________________________________
(a)
Fair value is based on an estimate derived from option models.
(b)
Fair value is based on an estimate derived from industry standard methodologies which consider historical relationships among various commodities, modeled market prices, time value and volatility factors.