The Company is subject primarily to commodity price risk due to fluctuations in the market price of natural gas, SRECs and electricity. To manage this risk, the Company enters into a variety of derivative instruments including, but not limited to, futures contracts, physical forward contracts, financial options and swaps to economically hedge the commodity price risk associated with its existing and anticipated commitments to purchase and sell natural gas, SRECs and electricity. In addition, the Company is exposed to foreign currency and interest rate risk and may utilize foreign currency derivatives to hedge Canadian dollar denominated natural gas purchases and/or sales and interest rate derivatives to reduce exposure to fluctuations in interest rates. All of these types of contracts are accounted for as derivatives, unless the Company elects NPNS, which is done on a contract-by-contract election. Accordingly, all of the financial and certain of the Company's physical derivative instruments are recorded at fair value on the Unaudited Condensed Consolidated Balance Sheets. For a more detailed discussion of the Company’s fair value measurement policies and level disclosures associated with the Company’s derivative instruments, see Note 6. Fair Value.

Energy Services chooses not to designate its financial commodity and physical forward commodity derivatives as accounting hedges or to elect NPNS. The changes in the fair value of these derivatives are recorded as a component of natural gas purchases or operating revenues, as appropriate for Energy Services, on the Unaudited Condensed Consolidated Statements of Operations as unrealized gains or losses. For Energy Services at settlement, realized gains and losses on all financial derivative instruments are recognized as a component of natural gas purchases and realized gains and losses on all physical derivatives follow the presentation of the related unrealized gains and losses as a component of either natural gas purchases or operating revenues.

Energy Services also enters into natural gas transactions in Canada and, consequently, is exposed to fluctuations in the value of Canadian currency relative to the U.S. dollar. Energy Services may utilize foreign currency derivatives to lock in the exchange rates associated with natural gas transactions denominated in Canadian currency. The derivatives may include currency forwards, futures, or swaps and are accounted for as derivatives. These derivatives are typically used to hedge demand fee payments on pipeline capacity, storage and natural gas purchase agreements.

As a result of Energy Services entering into transactions to borrow natural gas, commonly referred to as “park and loans,” an embedded derivative is recognized relating to differences between the fair value of the amount borrowed and the fair value of the amount that will ultimately be repaid, based on changes in the forward price for natural gas prices at the borrowed location over the contract term. This embedded derivative is accounted for as a forward sale in the month in which the repayment of the borrowed natural gas is expected to occur, and is considered a derivative transaction that is recorded at fair value on the Unaudited Condensed Consolidated Balance Sheets, with changes in value recognized in current period earnings.

Changes in fair value of NJNG's financial commodity derivatives are recorded as a component of regulatory assets or liabilities on the Unaudited Condensed Consolidated Balance Sheets. The Company elects NPNS accounting treatment on all physical commodity contracts that NJNG entered into on or before December 31, 2015, and accounts for these contracts on an accrual basis. Accordingly, physical natural gas purchases are recognized in regulatory assets or liabilities on the Unaudited Condensed Consolidated Balance Sheets when the contract settles and the natural gas is delivered. The average cost of natural gas is charged to expense in the current period earnings based on the BGSS factor times the therm sales. Effective for contracts executed on or after January 1, 2016, NJNG no longer elects NPNS accounting treatment on a portfolio basis. However, since NPNS is a contract-by-contract election, where it makes sense to do so, NJNG can and may elect to treat certain contracts as normal. Because NJNG recovers these amounts through future BGSS rates as increases or decreases to the cost of natural gas in NJNG’s tariff for natural gas service, the changes in fair value of these contracts are deferred as a component of regulatory assets or liabilities on the Unaudited Condensed Consolidated Balance Sheets.

In February 2020 and March 2020, NJNG entered into treasury lock transactions to fix the benchmark treasury rate associated with a $75 million debt tranche that was issued in September 2020. Settlement of the treasury locks resulted in a $6.6 million loss, which was recorded as a component of regulatory assets on the Unaudited Condensed Consolidated Balance Sheets. The loss is being amortized into earnings over the term of the debt as a component of interest expense on the Unaudited Condensed Consolidated Statements of Operations, which totaled $54,000 and $114,000 during the three and six months ended March 31, 2021.

The Company elects NPNS accounting treatment on PPA contracts executed by Clean Energy Ventures that meet the definition of a derivative and accounts for the contract on an accrual basis. Accordingly, electricity sales are recognized in revenues throughout the term of the PPA as electricity is delivered. NPNS is a contract-by-contract election and where it makes sense to do so, the Company can and may elect to treat certain contracts as normal.

During fiscal 2020, NJR entered into treasury lock transactions to fix the benchmark treasury rate associated with a $260 million debt issuance that was finalized in July 2020 and a $200 million debt issuance that was finalized in September 2020. NJR designated its treasury lock contracts as cash flow hedges, therefore, changes in fair value of the effective portion of the hedges were recorded in OCI. Settlement of the treasury locks in fiscal 2020 resulted in a loss of $13.7 million, which was recorded within OCI. The loss is being amortized into earnings over the term of the debt as a component of interest expense on the Unaudited Condensed Consolidated Statements of Operations, which totaled $263,000 and $494,000, net of tax, during the three and six months ended March 31, 2021.


			Derivatives at Fair Value
			March 31, 2021						September 30, 2020
(Thousands)	Balance Sheet Location	Assets			Liabilities			Assets			Liabilities
Derivatives not designated as hedging instruments:
Natural Gas Distribution:
Physical commodity contracts	Derivatives - current		$	177		$	1		$	78		$	76

Financial commodity contracts	Derivatives - current		589			88			71			282



Energy Services:
Physical commodity contracts	Derivatives - current		3,668			16,415			6,454			20,438
	Derivatives - noncurrent		1,364			20,090			1,264			12,003


Financial commodity contracts	Derivatives - current		12,770			7,166			16,671			12,965
	Derivatives - noncurrent		585			407			2,037			1,346
Foreign currency contracts	Derivatives - current		229			20			36			104
	Derivatives - noncurrent		28			9			48			3




Total fair value of derivatives			$	19,410		$	44,196		$	26,659		$	47,217

The Company transacts under master netting arrangements or equivalent agreements that allow it to offset derivative assets and liabilities with the same counterparty. However, the Company’s policy is to present its derivative assets and liabilities on a gross basis at the contract level unit of account on the Unaudited Condensed Consolidated Balance Sheets. The following table summarizes the reported gross amounts, the amounts that the Company has the right to offset but elects not to, financial collateral, as well as the net amounts the Company could present on the Unaudited Condensed Consolidated Balance Sheets but elects not to.


(Thousands)	Amounts Presented on Balance Sheets (1)			Offsetting Derivative Instruments (2)			Financial Collateral Received/Pledged (3)			Net Amounts (4)
As of March 31, 2021:
Derivative assets:
Energy Services
Physical commodity contracts		$	5,032		$	(1,757)		$	(200)		$	3,075
Financial commodity contracts		13,355			(7,573)						5,782
Foreign currency contracts		257			(29)						228
Total Energy Services		$	18,644		$	(9,359)		$	(200)		$	9,085
Natural Gas Distribution
Physical commodity contracts		$	177		$	(1)		$	—		$	176
Financial commodity contracts		589			(88)			—			501

Total Natural Gas Distribution		$	766		$	(89)		$	—		$	677



Derivative liabilities:
Energy Services
Physical commodity contracts		$	36,505		$	(1,757)		$	—		$	34,748

Financial commodity contracts		7,573			(7,573)			—			—
Foreign currency contracts		29			(29)			—			—
Total Energy Services		$	44,107		$	(9,359)		$	—		$	34,748
Natural Gas Distribution
Physical commodity contracts		$	1		$	(1)					$	—
Financial commodity contracts		88			(88)						—

Total Natural Gas Distribution		$	89		$	(89)		$	—		$	—



As of September 30, 2020:
Derivative assets:
Energy Services
Physical commodity contracts		$	7,718		$	(3,587)		$	(200)		$	3,931
Financial commodity contracts		18,708			(14,311)			—			4,397
Foreign currency contracts		84			(84)			—			—
Total Energy Services		$	26,510		$	(17,982)		$	(200)		$	8,328
Natural Gas Distribution
Physical commodity contracts		$	78		$	(65)		$	—		$	13
Financial commodity contracts		71			(71)			—			—
Total Natural Gas Distribution		$	149		$	(136)		$	—		$	13



Derivative liabilities:
Energy Services
Physical commodity contracts		$	32,441		$	(3,587)		$	—		$	28,854
Financial commodity contracts		14,311			(14,311)			—			—
Foreign currency contracts		107			(84)			—			23
Total Energy Services		$	46,859		$	(17,982)		$	—		$	28,877
Natural Gas Distribution
Physical commodity contracts		$	76		$	(65)		$	—		$	11
Financial commodity contracts		282			(71)			—			211

Total Natural Gas Distribution		$	358		$	(136)		$	—		$	222

Energy Services utilizes financial derivatives to economically hedge the gross margin associated with the purchase of physical natural gas to be used for storage injection and its subsequent sale at a later date. The gains or (losses) on the financial transactions that are economic hedges of the cost of the purchased natural gas are recognized prior to the gains or (losses) on the physical transaction, which are recognized in earnings when the natural gas is delivered. Therefore, mismatches between the timing of the recognition of realized gains or (losses) on the financial derivative instruments and gains or (losses) associated with the actual sale of the natural gas that is being economically hedged along with fair value changes in derivative instruments, creates volatility in the results of Energy Services, although the Company's intended economic results relating to the entire transaction are unaffected.


(Thousands)	Location of gain (loss) recognized in income on derivatives	Amount of gain (loss) recognized in income on derivatives
		Three Months Ended				Six Months Ended
		March 31,				March 31,
Derivatives not designated as hedging instruments:		2021		2020		2021		2020
Energy Services:
Physical commodity contracts	Operating revenues	$	36,419	$	12,096	$	41,671	$	21,932
Physical commodity contracts	Natural gas purchases	2,650		(1,892)		(2,404)		(3,302)
Financial commodity contracts	Natural gas purchases	(27,315)		23,319		20,440		69,412
Foreign currency contracts	Natural gas purchases	27		(475)		227		(360)


Total unrealized and realized gains		$	11,781	$	33,048	$	59,934	$	87,682

NJNG’s derivative contracts are part of the Company's risk management activities that relate to its natural gas purchases and BGSS incentive programs. At settlement, the resulting gains and/or losses are payable to or recoverable from utility customers and are deferred in regulatory assets or liabilities resulting in no impact to earnings. The following table reflects the (losses) gains associated with NJNG's derivative instruments for the periods set forth below:


(Thousands)	Amount of Pre-tax Gain (Loss) Recognized in OCI on Derivatives				Location of Gain (Loss) Reclassified from OCI into Income	Amount of Pre-tax Gain (Loss) Reclassified from OCI into Income
	Three Months Ended					Three Months Ended
	March 31,					March 31,
Derivatives in cash flow hedging relationships:	2021		2020			2021		2020
Interest rate contracts	$	—	$	(12,492)	Interest expense	$	(342)	$	—
	Six Months Ended					Six Months Ended
	March 31,					March 31,
Derivatives in cash flow hedging relationships:	2021		2020			2021		2020
Interest rate contracts	$	—	$	(12,492)	Interest expense	$	(685)	$	—

Futures exchanges have contract specific margin requirements that require the posting of cash or cash equivalents relating to traded contracts. Margin requirements consist of initial margin that is posted upon the initiation of a position, maintenance margin that is usually expressed as a percent of initial margin, and variation margin that fluctuates based on the daily marked-to-market relative to maintenance margin requirements. The Company maintains separate broker margin accounts for the Natural Gas Distribution and Energy Services segments. The balances are as follows:

NJNG, Energy Services, Clean Energy Ventures and the Storage and Transportation segment are exposed to credit risk as a result of their sales/wholesale marketing activities. As a result of the inherent volatility in the prices of natural gas commodities, derivatives, SRECs, the market value of contractual positions with individual counterparties could exceed established credit limits or collateral provided by those counterparties. If a counterparty fails to perform the obligations under its contract then the Company could sustain a loss.

The Company monitors and manages the credit risk of its wholesale operations through credit policies and procedures that management believes reduce overall credit risk. These policies include a review and evaluation of current and prospective counterparties' financial statements and/or credit ratings, daily monitoring of counterparties' credit limits and exposure, daily communication with traders regarding credit status and the use of credit mitigation measures, such as collateral requirements and netting agreements. Examples of collateral include letters of credit and cash received for either prepayment or margin deposit. Collateral may be requested due to the Company's election not to extend credit or because exposure exceeds defined thresholds. Most of the Company's wholesale marketing contracts contain standard netting provisions. These contracts include those governed by ISDA and the NAESB. The netting provisions refer to payment netting, whereby receivables and payables with the same counterparty are offset and the resulting net amount is paid to the party to which it is due.

Internally-rated exposure applies to counterparties that are not rated by Fitch or Moody's. In these cases, the counterparty's or guarantor's financial statements are reviewed, and similar methodologies and ratios used by Fitch and/or Moody's are applied to arrive at a substitute rating. Gross credit exposure is defined as the unrealized fair value of physical and financial derivative commodity contracts, plus any outstanding wholesale receivable for the value of natural gas delivered and/or financial derivative commodity contract that has settled for which payment has not yet been received.

Conversely, certain of NJNG's and Energy Services' derivative instruments are linked to agreements containing provisions that would require cash collateral payments from the Company if certain events occur. These provisions vary based upon the terms in individual counterparty agreements and can result in cash payments if NJNG's credit rating were to fall below its current level. Specifically, most, but not all, of these additional payments will be triggered if NJNG's debt is downgraded by the major credit agencies, regardless of investment grade status. In addition, some of these agreements include threshold amounts that would result in additional collateral payments if the values of derivative liabilities were to exceed the maximum values provided for in relevant counterparty agreements. Other provisions include payment features that are not specifically linked to ratings, but are based on certain financial metrics.

Collateral amounts associated with any of these conditions are determined based on a sliding scale and are contingent upon the degree to which the Company's credit rating and/or financial metrics deteriorate, and the extent to which liability amounts exceed applicable threshold limits. There were no derivative instruments with credit-risk-related contingent features that were in a liability position for which collateral is required as of March 31, 2021. These amounts differ from the respective net derivative liabilities reflected on the Unaudited Condensed Consolidated Balance Sheets because the agreements also include clauses, commonly known as “Rights of Offset,” that would permit the Company to offset its derivative assets against its derivative liabilities for determining additional collateral to be posted, as previously discussed.