UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q



ý☒	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended March 31, ~~2019~~2020



o☐	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from ______ to ______

Commission File Number: 001-34778

QEP RESOURCES, INC.

(Exact name of registrant as specified in its charter)



~~STATE OF DELAWARE~~Delaware		87-0287750
(State or other jurisdiction of		(I.R.S. Employer
incorporation or organization)		Identification No.)

1050 17^th Street, Suite 800, Denver, Colorado80265

(Address of principal executive offices)

Registrant's telephone number, including area code ~~(303)~~ (303) 672-6900

Securities registered pursuant to Section 12(b) of the Act:



Title of each class	Trading Symbol(s)	Name of each exchange on which registered
Common stock, $0.01 par value	QEP	New York Stock Exchange

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes ý ☒No o☐

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (Section 232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes ý ☒No o☐

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of "large accelerated filer," "accelerated filer," "smaller reporting company," and "emerging growth company" in Rule 12b-2 of the Exchange Act:



Large accelerated filer	ý☒	Accelerated filer	o☐
Non-accelerated filer	o☐	Smaller reporting company	o☐
		Emerging growth company	o☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. o☐

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes o ☐

No ý☒

At March 31, ~~2019,~~2020, there were ~~238,045,328~~242,182,385 shares of the registrant's common stock, $0.01 par value, outstanding.

QEP Resources, Inc.

Form 10-Q for the Quarter Ended March 31, ~~2019~~2020

TABLE OF CONTENTS



			Page
PART I. FINANCIAL INFORMATION			2

	ITEM 1.	FINANCIAL STATEMENTS	2

		UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS FOR THE THREE MONTHS ENDED MARCH 31, ~~2019~~2020 AND ~~2018~~2019	2

		UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) FOR THE THREE MONTHS ENDED MARCH 31, ~~2019~~2020 AND ~~2018~~2019	3

		UNAUDITED CONDENSED CONSOLIDATED BALANCE SHEETS AT MARCH 31, ~~2019~~2020 AND DECEMBER 31, ~~2018~~2019	4

		UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF EQUITY FOR THE THREE MONTHS ENDED MARCH 31, ~~2019~~2020 AND ~~2018~~2019	5

		UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS FOR THE THREE MONTHS ENDED MARCH 31, ~~2019~~2020 AND ~~2018~~2019	6

		UNAUDITED NOTES ACCOMPANYING THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS	7

	ITEM 2.	MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS	2726

	ITEM 3.	QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK	4645

	ITEM 4.	CONTROLS AND PROCEDURES	5049

PART II. OTHER INFORMATION			5049

	ITEM 1.	LEGAL PROCEEDINGS	5049

	ITEM 1A.	RISK FACTORS	5051

	ITEM 2.	UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS	5256

	ITEM 3.	DEFAULTS UPON SENIOR SECURITIES	5256

	ITEM 4.	MINE SAFETY DISCLOSURES	5256

	ITEM 5.	OTHER INFORMATION	5256

	ITEM 6.	EXHIBITS	5357

SIGNATURES			5458

PART I. FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

QEP RESOURCES, INC.

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(Unaudited)


	Three Months Ended						Three Months Ended
	March 31,						March 31,
	2019			2018			2020			2019
REVENUES	(in millions, except per share amounts)						(in millions, except per share amounts)
Oil and condensate, gas and NGL sales	$	275.6		$	409.8		$	221.8		$	275.6
Other revenues	3.7			5.0			0.4			3.7
Purchased oil and gas sales	1.3			14.1			3.6			1.3
Total Revenues	280.6			428.9			225.8			280.6
OPERATING EXPENSES
Purchased oil and gas expense	1.4			15.5			3.5			1.4
Lease operating expense	51.5			72.5			40.2			51.5
Transportation and processing costs	10.9			34.0			13.5			10.9
Gathering and other expense	3.8			2.8			2.7			3.8
General and administrative	63.3			60.1			15.9			63.3
Production and property taxes	24.0			28.9			18.7			24.0
Depreciation, depletion and amortization	123.3			196.5			142.2			123.3
Impairment	5.0			0.7			—			5.0
Total Operating Expenses	283.2			411.0			236.7			283.2
Net gain (loss) from asset sales, inclusive of restructuring costs	(13.2		)	3.5			3.7			(13.2		)
OPERATING INCOME (LOSS)	(15.8		)	21.4			(7.2		)	(15.8		)
Realized and unrealized gains (losses) on derivative contracts (Note 7)	(181.7		)	(53.2		)
Realized and unrealized gains (losses) on derivative contracts							449.9			(181.7		)
Interest and other income (expense)	2.8			(0.7		)	(2.6		)	2.8
Gain from early extinguishment of debt							25.2			—
Interest expense	(34.0		)	(35.0		)	(31.6		)	(34.0		)
INCOME (LOSS) BEFORE INCOME TAXES	(228.7		)	(67.5		)	433.7			(228.7		)
Income tax (provision) benefit	112.0			13.9			(66.3		)	112.0
NET INCOME (LOSS)	$	(116.7	)	$	(53.6	)	$	367.4		$	(116.7	)

Earnings (loss) per common share
Basic	$	(0.49	)	$	(0.22	)	$	1.54		$	(0.49	)
Diluted	$	(0.49	)	$	(0.22	)	$	1.54		$	(0.49	)

Weighted-average common shares outstanding
Used in basic calculation	237.1			240.9			239.1			237.1
Used in diluted calculation	237.1			240.9			239.1			237.1

Refer to Notes accompanying the Condensed Consolidated Financial Statements.

QEP RESOURCES, INC.

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)

(Unaudited)


	Three Months Ended						Three Months Ended
	March 31,						March 31,
	2019			2018			2020		2019
	(in millions)						(in millions)
Net income (loss)	$	(116.7	)	$	(53.6	)	$	367.4	$	(116.7	)
Other comprehensive income (loss), net of tax:
Fair value of plan assets adjustment⁽¹⁾	—			0.3
Pension and other postretirement plans adjustments:
Amortization of prior service costs	0.1			0.1			—		0.1
Amortization of actuarial losses⁽²⁾	0.1			0.2
Net curtailment⁽³⁾	(0.4		)	—
Other comprehensive income	(0.2		)	0.6
Amortization of actuarial losses							0.1		0.1
Net curtailment⁽¹⁾							—		(0.4		)
Other comprehensive income (loss)							0.1		(0.2		)
Comprehensive income (loss)	$	(116.9	)	$	(53.0	)	$	367.5	$	(116.9	)

____________________________


⁽¹⁾	~~Adjustment recorded during the three months ended March 31, 2018, related to a change in the fair value of plan assets as of December 31, 2017.~~


⁽²⁾	~~Presented net of income tax benefit of $0.1 million during the three months ended March 31, 2018.~~


⁽³⁾	Presented net of income tax expense of $0.1 million ~~during~~for the three months ended March 31, 2019.

Refer to Notes accompanying the Condensed Consolidated Financial Statements.

QEP RESOURCES, INC.

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)


	March 31, 2019			December 31, 2018			March 31, 2020			December 31, 2019
ASSETS	(in millions)						(in millions)
Current Assets
Cash and cash equivalents	$	89.9		$	—		$	70.3		$	166.3
Accounts receivable, net	80.2			104.3			81.1			108.4
Income tax receivable	68.8			75.9			165.4			37.4
Fair value of derivative contracts	—			87.5			370.6			1.5
Prepaid expenses	7.3			12.7
Other current assets	0.2			0.2
Prepaid expenses and other current assets							9.6			11.6
Total Current Assets	246.4			280.6			697.0			325.2
Property, Plant and Equipment (successful efforts method for oil and gas properties)
Proved properties	9,250.1			9,096.9			9,729.5			9,574.9
Unproved properties	706.5			705.5			565.7			599.1
Gathering and other	171.3			167.7			164.9			164.2
Materials and supplies	29.8			29.9			16.5			15.6
Total Property, Plant and Equipment	10,157.7			10,000.0			10,476.6			10,353.8
Less Accumulated Depreciation, Depletion and Amortization
Exploration and production	4,994.3			4,882.4			5,339.4			5,250.5
Gathering and other	61.0			58.1			63.7			61.0
Total Accumulated Depreciation, Depletion and Amortization	5,055.3			4,940.5			5,403.1			5,311.5
Net Property, Plant and Equipment	5,102.4			5,059.5			5,073.5			5,042.3
Fair value of derivative contracts	6.7			35.4			19.1			0.2
Operating lease right-of-use assets, net	61.4			—			55.0			56.8
Other noncurrent assets	53.3			49.6			51.2			53.3
Noncurrent assets held for sale	—			692.7
TOTAL ASSETS	$	5,470.2		$	6,117.8		$	5,895.8		$	5,477.8
LIABILITIES AND EQUITY
Current Liabilities
Checks outstanding in excess of cash balances	$	10.3		$	14.6		$	4.2		$	18.3
Accounts payable and accrued expenses	216.0			258.1			243.1			227.2
Production and property taxes	22.0			24.1			7.9			18.9
Current portion of long term debt	51.7			—
Current portion of long-term debt							331.6			—
Interest payable	33.0			32.4			31.1			31.0
Fair value of derivative contracts	60.3			—			—			18.7
Current operating lease liabilities	20.1			—			18.5			18.0
Asset retirement obligations	5.9			5.1			6.5			6.0
Total Current Liabilities	419.3			334.3			642.9			338.1
Long-term debt	2,026.7			2,507.1			1,587.4			2,015.6
Deferred income taxes	151.2			269.2			469.6			274.5
Asset retirement obligations	96.2			96.9			93.7			94.9
Fair value of derivative contracts	1.5			0.7			—			0.5
Operating lease liabilities	49.4			—			42.3			44.8
Other long-term liabilities	89.8			97.4			33.9			48.8
Other long-term liabilities held for sale	—			61.3
Commitments and contingencies (Note 11)
EQUITY
Common stock – par value $0.01 per share; 500.0 million shares authorized; 242.0 million and 239.8 million shares issued, respectively	2.4			2.4
Treasury stock – 3.9 million and 3.1 million shares, respectively	(51.8		)	(45.6		)
Common stock – par value $0.01 per share; 500.0 million shares authorized; 247.0 million and 242.1 million shares issued, respectively							2.5			2.4
Treasury stock – 4.8 million and 4.4 million shares, respectively							(56.2		)	(55.4		)
Additional paid-in capital	1,440.2			1,431.9			1,459.9			1,456.5
Retained earnings	1,259.8			1,376.5			1,632.2			1,269.6
Accumulated other comprehensive income (loss)	(14.5		)	(14.3		)	(12.4		)	(12.5		)
Total Common Shareholders' Equity	2,636.1			2,750.9			3,026.0			2,660.6
TOTAL LIABILITIES AND EQUITY	$	5,470.2		$	6,117.8		$	5,895.8		$	5,477.8

Refer to Notes accompanying the Condensed Consolidated Financial Statements.

QEP RESOURCES, INC.

CONDENSED CONSOLIDATED STATEMENTS OF EQUITY

(Unaudited)


	Common Stock			Treasury Stock					Additional Paid-in Capital			Retained Earnings			Accumulated Other Comprehensive Income(Loss)				Total			Common Stock				Treasury Stock					Additional Paid-in Capital		Retained Earnings			Accumulated Other Comprehensive Income(Loss)			Total
	Shares	Amount		Shares		Amount					Shares				Accumulated Other Comprehensive Income(Loss)			Amount					Shares		Amount						Additional Paid-in Capital		Retained Earnings			Accumulated Other Comprehensive Income(Loss)			Total
	(in millions)																					(in millions)
Balance at December 31, 2018	239.8	$	2.4	(3.1	)	$	(45.6	)	Additional Paid-in Capital		$	Retained Earnings	1,431.9		$	1,376.5			Total		$	(14.3	)	$	2,750.9
Balance at December 31, 2019																						242.1		$	2.4	(4.4	)	$	(55.4	)	$	1,456.5	$	1,269.6		$	(12.5	)	$	2,660.6
Net income (loss)	—	—		—		—			—			(116.7		)	—				(116.7		)	—		—		—		—			—		367.4			—			367.4
Cash dividends paid, $0.02 per share																						—		—		—		—			—		(4.8		)	—			(4.8		)
Share-based compensation	2.2	—		(0.8	)	(6.2		)	8.3			—			—				2.1			4.9		0.1		(0.4	)	(0.8		)	3.4		—			—			2.7
Change in pension and postretirement liability, net of tax	—	—		—		—			—			—			(0.2		)		(0.2		)	—		—		—		—			—		—			0.1			0.1
Balance at March 31, 2019	242.0	$	2.4	(3.9	)	$	(51.8	)	$	1,440.2		$	1,259.8		$	(14.5	)		$	2,636.1
Balance at March 31, 2020																						247.0		$	2.5	(4.8	)	$	(56.2	)	$	1,459.9	$	1,632.2		$	(12.4	)	$	3,026.0


	Common Stock					Treasury Stock					Additional Paid-in Capital			Retained Earnings				Accumulated Other Comprehensive Income(Loss)			Total
	Shares		Amount			Shares		Amount
	(in millions)
Balance at December 31, 2017	243.0		$	2.4		(2.0	)	$	(34.2	)	Additional Paid-in Capital		$	Retained Earnings			1,398.2	Accumulated Other Comprehensive Income(Loss)			Total				$	2,442.6			$	(11.1	)		$	3,797.9
Balance at December 31, 2018																								239.8			$	2.4			(3.1	)		$	(45.6	)	$	1,431.9	$	1,376.5		$	(14.3	)	$	2,750.9
Net income (loss)	—		—			—		—			—			(53.6		)		—			(53.6		)	—			—				—			—			—		(116.7		)	—			(116.7		)
Common stock repurchased and retired	(5.6	)	(0.1		)	—		—			—			(52.7		)		—			(52.8		)
Share-based compensation	2.9		0.1			(0.6	)	(5.3		)	9.8			—				—			4.6			2.2			—				(0.8	)		(6.2		)	8.3		—			—			2.1
Change in pension and postretirement liability, net of tax	—		—			—		—			—			—				0.6			0.6			—			—				—			—			—		—			(0.2		)	(0.2		)
Balance at March 31, 2018	240.3		$	2.4		(2.6	)	$	(39.5	)	$	1,408.0		$	2,336.3			$	(10.5	)	$	3,696.7
Balance at March 31, 2019																								242.0			$	2.4			(3.9	)		$	(51.8	)	$	1,440.2	$	1,259.8		$	(14.5	)	$	2,636.1

Refer to Notes accompanying the Condensed Consolidated Financial Statements.

QEP RESOURCES, INC.

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)


	Three Months Ended						Three Months Ended
	March 31,						March 31,
	2019			2018			2020			2019
OPERATING ACTIVITIES	(in millions)						(in millions)
Net income (loss)	$	(116.7	)	$	(53.6	)	$	367.4		$	(116.7	)
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:
Depreciation, depletion and amortization	123.3			196.5			142.2			123.3
Deferred income taxes (benefit)	(117.9		)	(14.1		)	195.0			(117.9		)
Impairment	5.0			0.7			—			5.0
Non-cash share-based compensation	8.0			9.2			3.3			8.0
Amortization of debt issuance costs and discounts	1.3			1.3			1.3			1.3
Net (gain) loss from asset sales, inclusive of restructuring costs	13.2			(3.5		)	(3.7		)	13.2
Gain from early extinguishment of debt							(25.2		)	—
Unrealized (gains) losses on marketable securities	(1.9		)	0.1			3.3			(1.9		)
Unrealized (gains) losses on derivative contracts	175.8			10.0			(407.3		)	175.8
Changes in operating assets and liabilities	(11.8		)	13.8			(124.4		)	(11.8		)
Net Cash Provided by (Used in) Operating Activities	78.3			160.4			151.9			78.3
INVESTING ACTIVITIES
Property acquisitions	(0.6		)	(36.2		)	(3.0		)	(0.6		)
Property, plant and equipment, including exploratory well expense	(164.6		)	(370.7		)
Expenditures for property, plant and equipment, including exploratory well expense							(164.6		)	(164.6		)
Proceeds from disposition of assets	617.4			33.3			12.6			617.4
Net Cash Provided by (Used in) Investing Activities	452.2			(373.6		)	(155.0		)	452.2
FINANCING ACTIVITIES
Checks outstanding in excess of cash balances	(4.3		)	(24.2		)	(14.1		)	(4.3		)
Repurchases of senior notes							(72.7		)	—
Proceeds from credit facility	44.5			1,068.5			—			44.5
Repayments of credit facility	(474.5		)	(772.5		)	—			(474.5		)
Common stock repurchased and retired	—			(52.8		)
Treasury stock repurchases	(5.8		)	(4.7		)	(0.8		)	(5.8		)
Dividends paid							(4.8		)	—
Net Cash Provided by (Used in) Financing Activities	(440.1		)	214.3			(92.4		)	(440.1		)
Change in cash, cash equivalents and restricted cash⁽¹⁾	90.4			1.1			(95.5		)	90.4
Beginning cash, cash equivalents and restricted cash⁽¹⁾	28.1			23.4			196.4			28.1
Ending cash, cash equivalents and restricted cash⁽¹⁾	$	118.5		$	24.5		$	100.9		$	118.5

Supplemental Disclosures:
Cash paid for interest, net of capitalized interest	$	31.5		$	26.0		$	29.7		$	31.5
Cash paid (refund received) for income taxes, net							$	(0.7	)	$	—
Cash paid for amounts included in the measurement of lease liabilities	$	6.6		$	—		$	6.0		$	6.6
Non-cash Operating Activities:
Other Non-cash Activities:
Right-of-use assets obtained in exchange for operating lease obligations	$	6.9		$	—		$	0.5		$	6.9
Non-cash Investing Activities:
Change in capital expenditure accruals and other non-cash adjustments	$	2.6		$	48.1
Capital expenditure accruals as of March 31, 2020 and 2019							$	77.3		$	57.2

____________________________


⁽¹⁾	Refer to Cash, Cash Equivalents and Restricted Cash in Note 1 – Basis of Presentation.

Refer to Notes accompanying the Condensed Consolidated Financial Statements.

QEP RESOURCES, INC.

NOTES ACCOMPANYING THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 1 – Basis of Presentation

Nature of Business

QEP Resources, Inc. (QEP or the Company) is an independent crude oil and natural gas exploration and production company with operations in two regions of the United States: the Southern Region (primarily in Texas) and the Northern Region (primarily in North Dakota). Unless otherwise specified or the context otherwise requires, all references to "QEP" or the "Company" are to QEP Resources, Inc. and its subsidiaries on a consolidated basis. QEP's corporate headquarters are located in Denver, Colorado and shares of QEP's common stock trade on the New York Stock Exchange (NYSE) under the ticker symbol "QEP".

Basis of Presentation ~~of Interim Condensed Consolidated Financial Statements~~

The interim Condensed Consolidated Financial Statements (financial statements) contain the accounts of QEP and its majority-owned or controlled subsidiaries. The ~~Condensed Consolidated Financial Statements~~financial statements were prepared in accordance with Generally Accepted Accounting Principles (GAAP) in the United States and with the instructions for Quarterly Reports on Form 10-Q and Regulation S-X. All significant intercompany accounts and transactions have been eliminated in consolidation.

The ~~Condensed~~ Consolidated Financial Statements reflect all normal recurring adjustments and accruals that are, in the opinion of management, necessary for a fair statement of financial position and results of operations for the interim periods presented. Interim ~~Condensed Consolidated Financial Statements and the year-end balance sheet~~financial statements do not include all of the information and notes required by GAAP for ~~audited~~ annual consolidated financial statements. These ~~Condensed Consolidated Financial Statements~~financial statements should be read in conjunction with the Consolidated Financial Statements and Notes thereto included in the Company's Annual Report on Form 10-K for the year ended December 31, ~~2018.~~2019.

The preparation of the ~~Condensed Consolidated Financial Statements~~financial statements and Notes in conformity with GAAP requires that management make estimates and assumptions that affect revenues, expenses, assets and liabilities, and disclosure of contingent assets and liabilities. Actual results could differ from estimates. Further, these estimates and other factors, including those outside the Company's control, such as the impact of sustained lower commodity prices, could have a significant adverse impact to the Company's financial condition, results of operations and cash flows. The results of operations for the three months ended March 31, ~~2019,~~2020, are not necessarily indicative of the results that may be expected for the year ending December 31, ~~2019.~~2020.

~~Reclassifications~~

Certain prior period balances on the Condensed Consolidated Balance Sheets (balance sheets) and Condensed Consolidated Statements of Cash Flows (statements of cash flows) have been reclassified to conform to the current year presentation. Such reclassifications had no effect on the Company's net income (loss), earnings (loss) per share or retained earnings previously reported.

Cash, Cash Equivalents and Restricted Cash

Cash equivalents primarily consist ~~principally~~ of highly liquid investments in securities with original maturities of three months or less made through commercial bank accounts that result in available funds the next business day. Restricted cash are funds that are legally or contractually reserved for a specific purpose and therefore not available for immediate or general business use.

The following table provides a reconciliation of cash, cash equivalents and restricted cash reported within the ~~Condensed Consolidated Balance Sheets~~balance sheets to the amounts shown in the ~~Condensed Consolidated Statements~~statements of ~~Cash Flows:~~cash flows:


	March 31,				March 31,
	2019		2018		2020		2019
	(in millions)				(in millions)
Cash and cash equivalents	$	89.9	$	—	$	70.3	$	89.9
Restricted cash⁽¹⁾	28.6		24.5		30.6		28.6
Total cash, cash equivalents and restricted cash shown in the Condensed Consolidated Statements of Cash Flows	$	118.5	$	24.5
Total cash, cash equivalents and restricted cash shown in the statements of cash flows					$	100.9	$	118.5

_______________________

⁽¹⁾As of March 31, ~~2019~~2020 and ~~2018,~~2019, the restricted cash balance ~~related to~~is cash ~~deposited into~~held in an escrow account ~~for~~related to a title dispute between outside parties in the Williston ~~Basin, and the~~Basin. The restricted cash balance is recorded within "Other noncurrent assets" on the balance sheets.

Income Tax

The tax legislation enacted in December 2017 reduced our federal corporate tax rate from 35% to 21%. In addition, the tax legislation eliminated the corporate Alternative Minimum Tax (AMT), allowing the Company to claim AMT refunds for AMT credits carried forward from prior tax years. The Company received $73.9 million of AMT credit refunds in 2019. The Coronavirus Aid Relief, and Economic Security Act (CARES Act) enacted in March 2020 permitted the Company to carry back its net operating loss (NOL) generated in 2018, creating additional AMT credits, and accelerate all of its AMT refunds into 2020. The Company now anticipates it will receive $165.6 million of AMT credit refunds, after carrybacks, in the next 12 months. The AMT credit refunds are included in "Income tax receivable" on the balance sheets as of March 31, 2020.

QEP’s effective federal and state income tax rate was 15.3% during the first quarter of 2020 compared to a rate of 49.0% during the first quarter of 2019. The decrease in the federal and state income tax rate was primarily driven by the impact of discrete items (unusual or infrequent items impacting the tax provision) recognized during the first quarter of 2019 and 2020. The primary discrete item recognized during the first quarter of 2020 relates to the remeasurement of deferred taxes related to a NOL carryback under the CARES Act to a year with a higher federal tax rate. The primary discrete item recognized during the first quarter of 2019 related to the remeasurement of deferred taxes associated with the Haynesville Divestiture.

Impairment of Long-Lived Assets

During the three months ended March 31, 2020, there were no impairment charges. During the three months ended March 31, 2019, QEP recorded impairment charges of $5.0 million related to an office building lease.

Employee Benefits

QEP provides pension and other postretirement benefits to certain employees through three retiree benefit plans: the QEP Resources, Inc. Retirement Plan (the Pension Plan), the Supplemental Executive Retirement Plan (the SERP), and a postretirement medical plan (the Medical Plan). The Pension Plan is a closed, qualified, defined-benefit pension plan that is funded and provides pension benefits to certain QEP employees. The SERP is a nonqualified retirement plan that is unfunded and provides postretirement benefits to certain QEP employees. The Medical Plan is a self-insured plan. It is unfunded and provides other postretirement benefits including certain health care and life insurance benefits for certain retired QEP employees.

During the three months ended March 31, 2020, the Company made contributions of $9.0 million to its retiree benefit plans (including $2.0 million to the Pension Plan and $7.0 million to the SERP) and expects to contribute an additional $3.7 million during the remainder of 2020 (including $2.0 million to the Pension Plan, $1.5 million to the SERP and $0.2 million to the Medical Plan). Contributions to the Pension Plan increase plan assets whereas contributions to the SERP and Medical Plan are used to fund current benefit payments.

The Company recognizes service costs related to SERP and Medical Plan benefits on the Condensed Consolidated ~~Balance Sheets.~~Statements of Operations (statements of operations) within "General and administrative" expense. All other expenses related to the Pension Plan, SERP and Medical Plan are recognized on the statements of operations within "Interest and other income (expense)".

~~New~~

QEP also offers a nonqualified, unfunded deferred compensation plan (Wrap Plan) to certain individuals. The Wrap Plan provides participants with certain tax planning benefits as well as supplemental funds for retirement and allows participants to defer the receipt of various types of compensation. Participants are able to select from a variety of investment options, including mutual funds and phantom QEP shares. As of March 31, 2020 and December 31, 2019, the Wrap Plan obligations for participants' future benefits were $21.0 million and $26.8 million, respectively, and are included in "Other long-term liabilities" on the balance sheets. The Company established a trust (Rabbi Trust) to hold the investments associated with the Wrap Plan (other than phantom QEP shares) and to pay Wrap Plan obligations as they arise. As of March 31, 2020 and December 31, 2019, the marketable securities held in the Rabbi Trust were $20.6 million and $23.1 million, respectively, and are included in "Other noncurrent assets" on the balance sheets. Refer to Note 6 – Fair Value Measurements for information on the fair value measurement of the marketable securities held in the Rabbi Trust and the Wrap Plan obligations.

Recent Accounting ~~Pronouncements~~Developments

In ~~February~~June 2016, the Financial Accounting Standards Board ~~(FASB)~~("FASB") issued Accounting Standards Update ~~(ASU)~~("ASU") No. ~~2016-02, Leases~~2016-13, Financial Instruments - Credit Losses (Topic ~~842)~~326) - Measurement of credit losses on financial instruments, which requires ~~lessees~~a company immediately recognize management's current estimated credit losses ("CECL") for all financial instruments that are not accounted for at fair value through net income. Previously, credit losses on financial assets were only required to recognize the lease assets and lease liabilities classified as operating leases on the balance sheet and disclose key quantitative and qualitative information about leasing arrangements. The FASB subsequently issued various ASUs which provided additional implementation guidance.be recognized when they were incurred. The Company adopted ASU ~~2016-02~~2016-13 on January 1, ~~2019 using the modified retrospective approach and elected to not adjust periods prior to January 1, 2019.~~2020. The Company elected the package of practical expedients permitted under the transition guidance within the new standard, which, among other things, allowed the carry forward of the historical lease classification, including accounting treatment for land easements. This standard does not apply to QEP's leases that provide the right to explore for minerals, oil or natural gas resources. The adoption of this guidance resulted in the recognition of net operating lease right-of-use assets and operating lease liabilities on QEP's Condensed Consolidated Balance Sheets. These leases primarily relate to office buildings, compressors and generators. This guidance did not have a significant impact on the ~~Condensed Consolidated Statement~~financial statements or notes accompanying the financial statements.

In August 2018, the FASB issued ASU No. 2018-13, Fair value measurement (Topic 820) - Disclosure framework - Changes to the disclosure requirements for fair value measurement, which modifies the disclosure requirements on fair value measurements in Topic 820. The Company adopted ASU 2018-13 on January 1, 2020. The guidance did not have a significant impact on the financial statements or notes accompanying the financial statements.

In March 2020, the FASB issued ASU No. 2020-04, Reference Rate Reform, which provides temporary optional guidance to companies impacted by the transition away from the London Interbank Offered Rate (LIBOR). The amendment provides certain expedients and exceptions to applying GAAP in order to lessen the potential accounting burden when contracts, hedging relationships, and other transactions that reference LIBOR as a benchmark rate are modified. This amendment is effective upon issuance and expires on December 31, 2022. The Company is currently assessing the impact of ~~Operations or~~ the ~~Condensed Consolidated Statement of Cash Flows. Refer to Note 8 – Leases for more information.~~LIBOR transition and this ASU on the Company's financial statements.

Note 2 – Revenue

Revenue Recognition

QEP recognizes revenue from the ~~sales~~sale of oil and condensate, gas and NGL in the period that the performance obligations are satisfied. QEP's performance obligations are satisfied when the customer obtains control of product, when QEP has no further obligations to perform related to the sale, when the transaction price has been determined and when collectability is probable. The ~~sales~~sale of oil and condensate, gas and NGL are made under contracts with customers, which typically include consideration that is based on pricing tied to local indices and volumes delivered in the current month. Reported revenues include estimates for the two most recent months using published commodity price indices and volumes supplied by field operators. Performance obligations under our contracts with customers are typically satisfied at a point in time through monthly delivery of oil and condensate, gas and/or NGL. Our contracts with customers typically require payment for oil and condensate, gas and NGL sales within 30 days following the calendar month of delivery.

QEP's oil and condensate is typically sold at specific delivery points under contract terms that are common in the industry. QEP's gas and NGL are also sold under contract types that are common in the industry; however, under these contracts, the gas and its components, including NGL, may be sold to a single purchaser or the residue gas and NGL may be sold to separate purchasers. Regardless of the contract type, the terms of these contracts compensate ~~the Company~~QEP for the value of the residue gas and NGL constituent components at market prices for each product. QEP also purchases and resells oil and gas primarily to mitigate credit risk related to third party purchasers, to fulfill volume commitments when production does not fulfill contractual commitments and to capture additional margin from subsequent sales of third party purchases. QEP recognizes revenue from these resale activities in the period that the performance obligations are satisfied.

The following ~~table presents~~tables present QEP's revenues that are disaggregated by revenue source and by geographic area. Transportation and processing costs in the following table are not all of the transportation and processing costs that ~~the Company~~QEP incurs, only the expenses that are netted against revenues pursuant to ASC Topic ~~606.~~606, Revenue Recognition.



	Oil and condensate sales		Gas sales		NGL sales		Transportation and processing costs included in revenue			Oil and condensate, gas and NGL sales, as reported
	(in millions)
	Three Months Ended March 31, 2020
Northern Region
Williston Basin	$	79.2	$	4.6	$	3.5	$	(9.3	)	$	78.0
Other Northern	0.1		0.1		—		—			0.2
Southern Region
Permian Basin	140.7		1.8		6.1		(5.0		)	143.6
Other Southern	—		—		—		—			—
Total oil and condensate, gas and NGL sales	$	220.0	$	6.5	$	9.6	$	(14.3	)	$	221.8

	Three Months Ended March 31, 2019
Northern Region
Williston Basin	$	109.9	$	12.5	$	7.4	$	(10.1	)	$	119.7
Other Northern	0.4		0.2		—		—			0.6
Southern Region
Permian Basin	139.2		4.6		9.5		(3.7		)	149.6
Other Southern	—		5.7		—		—			5.7
Total oil and condensate, gas and NGL sales	$	249.5	$	23.0	$	16.9	$	(13.8	)	$	275.6

Oil and condensate sales Gas sales NGL sales Transportation and processing costs included in revenue Oil and condensate, gas and NGL sales, as reported
(in millions)
Three Months Ended March 31, 2019
Northern Region
Williston Basin $ 109.9
$ 12.5
$ 7.4
$ (10.1 ) $ 119.7
Other Northern 0.4
0.2
—
—
0.6
Southern Region
Permian Basin 139.2
4.6
9.5
(3.7 ) 149.6
Other Southern —
5.7
—
—
5.7
Total oil and condensate, gas and NGL sales $ 249.5
$ 23.0
$ 16.9
$ (13.8 ) $ 275.6

Three Months Ended March 31, 2018
Northern Region
Williston Basin $ 160.5
$ 9.8
$ 11.8
$ (9.9 ) $ 172.2
Uinta Basin 8.4
10.1
1.7
—
20.2
Other Northern 1.9
1.0
(0.2 ) —
2.7
Southern Region
Permian Basin 129.8
4.6
6.5
(2.8 ) 138.1
Haynesville/Cotton Valley 0.4
76.4
—
—
76.8
Other Southern (0.3 ) 0.1
—
—
(0.2 )
Total oil and condensate, gas and NGL sales $ 300.7
$ 102.0
$ 19.8
$ (12.7 ) $ 409.8

Note 3 – Acquisitions and Divestitures

Acquisitions

During the three months ended March 31, 2020 and 2019, QEP acquired various oil and gas properties, which primarily included proved leasehold acreage in the Permian Basin for an aggregate purchase price of $3.0 million and $0.6 million, respectively, subject to post-closing purchase price adjustments.

Divestitures

During the three months ended March 31, ~~2018,~~2020, QEP ~~acquired various oil~~received proceeds of $12.6 million and ~~gas properties, which~~recorded a pre-tax gain on sale of $3.7 million, primarily ~~included proved leasehold acreage in the Permian Basin for an aggregate purchase price of $36.2 million. Of the $36.2 million, $35.7 million was~~ related to ~~acquisitions from various entities that owned additional oil and gas interests in~~the divestiture of certain properties ~~included in~~outside its main operating areas. Gains and losses are reported on the ~~2017 acquisition~~statements of ~~oil and gas properties in the Permian Basin (the 2017 Permian Basin Acquisition) on substantially the same terms and conditions as the 2017 Permian Basin Acquisition.~~operations within "Net gain (loss) from asset sales, inclusive of restructuring costs".

~~Divestitures~~

In February 2018, QEP's Board of Directors unanimously approved certain strategic and financial initiatives (2018 Strategic Initiatives) including plans to market its assets in the Williston Basin, the Uinta Basin and Haynesville/Cotton Valley and focus its activities in the Permian Basin. The Company subsequently closed the sale of its Uinta Basin assets in the third quarter of 2018 and the sale of the Haynesville/Cotton Valley assets in the first quarter of 2019. In November 2018, the Company's wholly owned subsidiary, QEP Energy Company, entered into a purchase and sale agreement for its assets in the Williston Basin, however, in February 2019, the Company agreed with the buyer to terminate the purchase and sale agreement.

Haynesville/Cotton Valley Divestiture

In November 2018, the Company's wholly owned subsidiaries, QEP Energy Company, QEP Marketing Company, and QEP Oil & Gas Company, entered into a definitive agreement to sell their assets in Haynesville/Cotton Valley for a purchase price of $735.0 million, subject to purchase price adjustments, including adjustments for certain title and environmental defects asserted prior to the closing (Haynesville Divestiture). In January 2019, QEP ~~closed~~sold its Haynesville/Cotton Valley assets (Haynesville Divestiture) and during the ~~Haynesville Divestiture for~~year ended December 31, 2019, reached final settlement on asserted environmental and title defects and received aggregate net cash proceeds of ~~$615.3 million, subject to post-closing purchase price adjustments, and~~$633.9 million. QEP recorded a net pre-tax loss, ~~on sale~~including restructuring costs, of ~~$18.0 million. Of~~$4.0 million, of which $15.0 million of the ~~$18.0 million~~ pre-tax loss ~~on sale, $15.0 million~~ was recognized during the three months ended March 31, 2019, and ~~$3.0 million~~ was ~~recognized during the fourth quarter of 2018~~recorded within "Net gain (loss) from asset sales, inclusive of restructuring costs" on the ~~Condensed Consolidated Statements~~statements of ~~Operations. Included in the $15.0 million pre-tax loss on sale is $1.4 million of restructuring costs related to the Haynesville Divestiture during~~operations.

During the three months ended March 31, ~~2019. Refer to Note 9 – Restructuring for more information. As of March 31,~~ 2019, $22.1 million remained in escrow due to title defects asserted prior to closing, to be resolved pursuant to the purchase and sale agreement's title dispute resolution procedures, of which $5.8 million was included in "Accounts receivable, net" on the Condensed Consolidated Balance Sheets. As of December 31, 2018, it was deemed unlikely that there will be any significant changes to the Haynesville Divestiture. Accordingly, the assets and liabilities associated with the Haynesville Divestiture were classified as noncurrent assets and liabilities held for sale, on the Condensed Consolidated Balance Sheets.

QEP accounted for revenues and expenses related to Haynesville/Cotton Valley, including the pre-tax loss on sale of $15.0 million, ~~during the three months ended March 31, 2019,~~ as income from continuing operations on the ~~Condensed Consolidated Statements~~statements of ~~Operations~~operations because the Haynesville Divestiture did not cause a strategic shift for the Company and ~~as a result,~~therefore did not qualify as discontinued ~~operations under ASU 2014-08,~~ ~~Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity. For~~operations. During the three months ended March 31, 2019, QEP recorded a net loss before income taxes related to the divested Haynesville/Cotton Valley properties of $11.1 million, which includes the pre-tax loss on sale of $15.0 million. ~~For the three months ended March 31, 2018, QEP recorded net income before income taxes related to the divested Haynesville/Cotton Valley properties of $12.3 million.~~

Other Divestitures

~~The following table presents the carrying amounts of the major classes of assets and liabilities related~~In addition to the Haynesville Divestiture, ~~classified as noncurrent assets and liabilities held for sale on the Condensed Consolidated Balance Sheets:~~

December 31, 2018⁽¹⁾
(in millions)
Assets
Current assets, total $ 1.2
Property, Plant and Equipment 683.7
Other noncurrent assets 7.8
Noncurrent assets held for sale $ 692.7
Liabilities
Current liabilities, total $ 3.4
Asset retirement obligations, current 0.7
Asset retirement obligations, long-term 56.9
Other long-term liabilities 0.3
Other long-term liabilities held for sale $ 61.3

~~____________________________~~


⁽¹⁾	~~The Haynesville Divestiture closed in January 2019, therefore there are no assets and liabilities held for sale as of March 31, 2019.~~

~~Uinta Basin Divestiture~~

In September 2018, QEP sold its natural gas and oil producing properties, undeveloped acreage and related assets located in the Uinta Basin for net cash proceeds of $153.0 million, subject to post-closing purchase price adjustments (Uinta Basin Divestiture). During the three months ended March 31, 2019, QEP recorded a pre-tax gain on sale of $2.2 million, due to post-closing purchase price adjustments, which were recorded within "Net gain (loss) from asset sales, inclusive of restructuring costs". For the three months ended March 31, 2018, QEP recorded net loss before income taxes related to the divested Uinta Basin assets of $5.0 million.

~~Pinedale Divestiture~~

In September 2017, QEP sold its Pinedale assets (Pinedale Divestiture) for net cash proceeds (after purchase price adjustments) of $718.2 million. During the three months ended March 31, 2018, QEP recorded a pre-tax gain on sale of $1.0 million, due to post-closing purchase price adjustments, which were recorded within "Net gain (loss) from asset sales, inclusive of restructuring costs".

QEP agreed to reimburse the buyer of its Pinedale assets for certain deficiency charges it incurs related to gas processing and NGL transportation and fractionation contracts, if any, between the effective date of the sale and December 31, 2019, in an aggregate amount not to exceed $45.0 million. As of March 31, 2019, the remaining liability associated with estimated future payments for this commitment was $5.9 million and is reported on the Condensed Consolidated Balance Sheets within "Accounts payable and accrued expenses".

~~Other Divestitures~~

~~During~~during the three months ended March 31, 2019, QEP received net cash proceeds of $2.1 million and recorded a ~~net~~ pre-tax loss on sale of $0.4 million, primarily related to the divestiture of properties outside its main operating areas.

During the three months ended March 31, 2018, QEP received net cash proceeds of $33.3 million and recorded a pre-tax gain on sale of $2.5 million, primarily related to the divestiture of properties outside its main operating areas in the Williston Basin and Other Northern areas.

These gains and losses were recorded within "Net gain (loss) from asset sales, inclusive of restructuring costs" on the ~~Condensed Consolidated Statements~~statements of ~~Operations.~~operations.

Note 4 – Earnings Per Share

Basic earnings (loss) per share (EPS) are computed by dividing net income (loss) by the weighted-average number of common shares outstanding during the reporting period. Diluted EPS includes the potential increase in the number of outstanding shares that could result from the exercise of in-the-money stock options. QEP's unvested restricted share awards are included in weighted-average basic common shares outstanding because, once the shares are granted, the restricted share awards are considered issued and outstanding, the historical forfeiture rate is minimal and the restricted share awards are eligible to receive dividends.

Unvested share-based payment awards that contain non-forfeitable rights to dividends or dividend equivalents are considered participating securities and are included in the computation of earnings (loss) per share pursuant to the two-class method. The Company's unvested restricted share awards contain non-forfeitable dividend rights and participate equally with common stock with respect to dividends issued or declared. However, the Company's unvested restricted share awards do not have a contractual obligation to share in losses of the Company. The Company's unexercised stock options do not contain rights to dividends. Under the two-class method, the earnings used to determine basic earnings (loss) per common share are reduced by an amount allocated to participating securities. When the Company records a net loss, none of the loss is allocated to the participating securities since the securities are not obligated to share in Company losses. Use of the two-class method has an insignificant impact on the calculation of basic and diluted earnings (loss) per common share. ~~During~~The Company was in a net loss position for the three months ended March 31, ~~2019 and 2018, there~~2019; therefore, all potentially dilutive securities were ~~no anti-dilutive shares.~~anti-dilutive.

The following is a reconciliation of the components of basic and diluted shares used in the EPS calculation:



	Three Months Ended
	March 31,
	2020	2019
	(in millions)
Weighted-average basic common shares outstanding	239.1	237.1
Potential number of shares issuable upon exercise of in-the-money stock options under the Long-Term Stock Incentive Plan	—	—
Average diluted common shares outstanding	239.1	237.1

Three Months Ended
March 31,
2019 2018
(in millions)
Weighted-average basic common shares outstanding 237.1
240.9
Potential number of shares issuable upon exercise of in-the-money stock options under the Long-Term Stock Incentive Plan —
—
Average diluted common shares outstanding 237.1
240.9

Note 5 – Asset Retirement Obligations

QEP records asset retirement obligations (ARO) associated with the retirement of tangible, long-lived assets. The Company's ARO liability applies primarily to abandonment costs associated with oil and gas wells and certain other properties. The fair values of such costs are estimated by Company personnel based on abandonment costs of similar assets and depreciated over the life of the related assets. Revisions to the ARO estimates result from changes in expected cash flows or material changes in estimated asset retirement ~~costs.~~costs or estimated lives. The ARO liability is adjusted to present value each period through an accretion calculation using a credit-adjusted risk-free interest rate.

The ~~Condensed Consolidated Balance Sheet~~balance sheet line items of QEP's ARO liability are presented in the table below:



	Asset Retirement Obligations
	March 31,		December 31,
	2020		2019
Balance Sheet line item	(in millions)
Current:
Asset retirement obligations, current liability	$	6.5	$	6.0
Long-term:
Asset retirement obligations	93.7		94.9
Total ARO Liability	$	100.2	$	100.9

Asset Retirement Obligations
March 31, December 31,
2019 2018
Balance Sheet line item (in millions)
Current:
Asset retirement obligations, current liability $ 5.9
$ 5.1
Long-term:
Asset retirement obligations 96.2
96.9
Other long-term liabilities held for sale —
57.6
Total ARO Liability $ 102.1
$ 159.6

The following is a reconciliation of the changes in the Company's ARO for the period specified below:



	Asset Retirement Obligations
	(in millions)
ARO liability at January 1, 2020	$	100.9
Accretion	0.9
Additions	0.6
Revisions	(0.5		)
Liabilities related to assets sold	(1.3		)
Liabilities settled	(0.4		)
ARO liability at March 31, 2020	$	100.2

Asset Retirement Obligations
(in millions)
ARO liability at January 1, 2019 $ 159.6
Accretion 1.1
Additions 0.1
Revisions (0.3 )
Liabilities related to assets sold⁽¹⁾
(58.1 )
Liabilities settled (0.3 )
ARO liability at March 31, 2019 $ 102.1

~~_______________________~~


⁽¹⁾	Liabilities related to assets sold during the three months ended March 31, 2019, includes $57.6 million related to the Haynesville Divestiture (refer to Note 3 – Acquisitions and Divestitures for more information).

Note 6 – Fair Value Measurements

QEP measures and discloses fair values in accordance with the provisions of ASC 820, Fair Value Measurements and Disclosures. This guidance defines fair value in applying GAAP, establishes a framework for measuring fair value and expands disclosures about fair value measurements. ASC 820 also establishes a fair value hierarchy. Level 1 inputs are quoted prices (unadjusted) for identical assets or liabilities in active markets that the Company has the ability to access at the measurement date. Level 2 inputs are inputs other than quoted prices included within Level 1 that are observable for the asset or liability, either directly or indirectly. Level 3 inputs are unobservable inputs for the asset or liability.

QEP has determined that its commodity derivative instruments are Level 2. The Level 2 fair value of commodity derivative contracts (refer to Note 7 – Derivative Contracts for more information) is based on market prices posted on the respective commodity exchange on the last trading day of the reporting period and industry standard discounted cash flow models. QEP primarily applies the market approach for recurring fair value measurements and maximizes its use of observable inputs and minimizes its use of unobservable inputs. QEP considers bid and ask prices for valuing the majority of its assets and liabilities measured and reported at fair value. In addition to using market data, QEP makes assumptions in valuing its assets and liabilities, including assumptions about risk and the risks inherent in the inputs to the valuation technique. The Company's policy is to recognize significant transfers between levels at the end of the reporting period.

Certain of the Company's commodity derivative instruments are valued using industry standard models that consider various inputs, including quoted forward prices for commodities, time value, volatility, and current market and contractual prices for the underlying instruments, as well as other relevant economic measures. Substantially all of these inputs are observable in the marketplace throughout the full term of the instrument and can be derived from observable data or are supported by observable prices at which transactions are executed in the marketplace. The determination of fair value for derivative assets and liabilities also incorporates nonperformance risk for counterparties and for QEP. Derivative contract fair values are reported on a net basis to the extent a legal right of offset with the counterparty exists.

QEP has determined that the marketable securities held in the Rabbi Trust and the Wrap Plan obligations are Level 1. The fair value of the marketable securities in the Rabbi Trust is based on actively traded mutual funds. The Wrap Plan obligations, which represent the underlying liabilities to the participants in the Wrap Plan, are recorded at amounts due to participants, based on the fair value of participants' selected investments, including both actively traded mutual funds and phantom QEP shares.

The fair value of financial assets and liabilities at March 31, ~~2019~~2020 and December 31, ~~2018,~~2019, is shown in the table below:



	Fair Value Measurements
	Gross Amounts of Assets and Liabilities						Netting Adjustments⁽¹⁾			Net Amounts Presented on the Condensed Consolidated Balance Sheets
	Level 1		Level 2		Level 3		Netting Adjustments⁽¹⁾
	(in millions)
Financial Assets	March 31, 2020
Fair value of derivative contracts – short-term	$	—	$	375.4	$	—	$	(4.8	)	$	370.6
Fair value of derivative contracts – long-term	—		21.2		—		(2.1		)	19.1
Fair value of marketable securities	20.6		—		—		—			20.6
Total financial assets	$	20.6	$	396.6	$	—	$	(6.9	)	$	410.3

Financial Liabilities
Fair value of derivative contracts – short-term	$	—	$	4.8	$	—	$	(4.8	)	$	—
Fair value of derivative contracts – long-term	—		2.1		—		(2.1		)	—
Fair value of Wrap Plan obligations	21.0		—		—		—			21.0
Total financial liabilities	$	21.0	$	6.9	$	—	$	(6.9	)	$	21.0

	December 31, 2019
Financial Assets
Fair value of derivative contracts – short-term	$	—	$	1.5	$	—	$	—		$	1.5
Fair value of derivative contracts – long-term	—		0.2		—		—			0.2
Fair value of marketable securities	23.1		—		—		—			23.1
Total financial assets	$	23.1	$	1.7	$	—	$	—		$	24.8

Financial Liabilities
Fair value of derivative contracts – short-term	$	—	$	18.7	$	—	$	—		$	18.7
Fair value of derivative contracts – long-term	—		0.5		—		—			0.5
Fair value of Wrap Plan obligations	26.8		—		—		—			26.8
Total financial liabilities	$	26.8	$	19.2	$	—	$	—		$	46.0

Fair Value Measurements
Gross Amounts of Assets and Liabilities
Netting Adjustments⁽¹⁾
Net Amounts Presented on the Condensed Consolidated Balance Sheets
Level 1 Level 2 Level 3
(in millions)
Financial Assets March 31, 2019
Fair value of derivative contracts – short-term $ —
$ —
$ —
$ —
$ —
Fair value of derivative contracts – long-term —
6.7
—
—
6.7
Total financial assets $ —
$ 6.7
$ —
$ —
$ 6.7

Financial Liabilities
Fair value of derivative contracts – short-term $ —
$ 60.3
$ —
$ —
$ 60.3
Fair value of derivative contracts – long-term —
1.5
—
—
1.5
Total financial liabilities $ —
$ 61.8
$ —
$ —
$ 61.8

December 31, 2018
Financial Assets
Fair value of derivative contracts – short-term⁽²⁾
$ —
$ 88.2
$ —
$ (0.4 ) $ 87.8
Fair value of derivative contracts – long-term —
35.4
—
—
35.4
Total financial assets $ —
$ 123.6
$ —
$ (0.4 ) $ 123.2

Financial Liabilities
Fair value of derivative contracts – short-term $ —
$ 0.4
$ —
$ (0.4 ) $ —
Fair value of derivative contracts – long-term —
0.7
—
—
0.7
Total financial liabilities $ —

$ 1.1

$ —

$ (0.4 )
$ 0.7

_______________________


⁽¹⁾	The Company nets its derivative contract assets and liabilities outstanding with the same counterparty on the ~~Condensed Consolidated Balance Sheets~~balance sheets for the contracts that contain netting provisions. Refer to Note 7 – Derivative Contracts for additional information regarding the Company's derivative contracts.


⁽²⁾	~~Includes fair value of derivative contracts classified as "Noncurrent assets held for sale" of $0.3 million as of~~

~~December 31, 2018 on the Condensed Consolidated Balance Sheets related to the Haynesville Divestiture.~~

The following table discloses the fair value and related carrying amount of certain financial instruments not disclosed in other ~~Notes~~notes to the ~~Condensed Consolidated Financial Statements in this Quarterly Report on Form 10-Q:~~financial statements:



	Carrying Amount		Level 1 Fair Value		Carrying Amount		Level 1 Fair Value
	March 31, 2020				December 31, 2019
Financial Liabilities	(in millions)
Total debt outstanding	$	1,919.0	$	806.2	$	2,015.6	$	2,029.4

Carrying Amount Level 1 Fair Value Carrying Amount Level 1 Fair Value
March 31, 2019 December 31, 2018
Financial Assets (in millions)
Cash and cash equivalents $ 89.9
$ 89.9
$ —
$ —
Financial Liabilities
Checks outstanding in excess of cash balances $ 10.3
$ 10.3
$ 14.6
$ 14.6
Total debt outstanding $ 2,078.4
$ 2,014.2
$ 2,507.1
$ 2,350.5

The carrying amounts of cash and cash equivalents, accounts receivable, accounts payable and checks outstanding in excess of cash balances approximate fair value. The fair value of fixed-rate long-term debt is based on the trading levels and dollar prices for the Company's debt at the end of the quarter. ~~The~~At times when the Company has outstanding debt under the credit

facility, the carrying amount of variable-rate long-term debt approximates fair value because the floating interest rate paid on such debt ~~was~~is set for periods of one ~~month.~~month or less.

The fair value of the deficiency charge obligation associated with the Pinedale Divestiture was measured utilizing an internally developed cash flow model discounted at QEP's weighted average cost of debt. Given the unobservable nature of the inputs, the fair value calculation associated with the deficiency charges is considered Level 3 within the fair value hierarchy. ~~Refer to Note 3 – Acquisitions and Divestitures for more information.~~

The initial measurement of ARO at fair value is calculated using discounted cash flow techniques and is based on internal estimates of future retirement costs associated with property, plant and equipment. Significant Level 3 inputs used in the calculation of ARO includes plugging costs and reserve lives. A reconciliation of the Company's ARO is presented in Note 5 – Asset Retirement Obligations.

Nonrecurring Fair Value Measurements

The provisions of the fair value measurement standard are also applied to the Company's nonrecurring measurements. The Company ~~utilizes fair value on a periodic basis, at least annually, to review~~reviews its proved oil and gas properties and operating lease right-of-use assets for potential impairment at least annually and when events and changes in circumstances indicate that the carrying amount of such property may not be recoverable. ~~The~~If impairment is indicated, the fair value of property is measured utilizing the income approach and utilizing inputs that are primarily based upon internally developed cash flow models discounted at an appropriate weighted average cost of capital. In addition, the signing of a purchase and sale agreement could also trigger an impairment of proved properties. For assets subject to a purchase and sale agreement, the terms of the purchase and sale agreement are used as an indicator of fair value. If a range is estimated for the amount of future cash flows, the fair value of property is measured utilizing a probability-weighted approach in which the likelihood of possible outcomes is taken into consideration. Given the unobservable nature of the inputs, fair value calculations associated with long-term operating lease right-of-use assets and proved oil and gas property impairments are considered Level 3 within the fair value hierarchy. During the three months ended March 31, ~~2019, there was no~~2020, the Company did not have an impairment ~~related to proved and unproved oil and gas properties.~~charge. During the three months ended March 31, 2019, the Company recorded impairment charges of $5.0 million related to an office building lease. ~~During the three months ended March 31, 2018, the Company recorded impairments on certain proved oil and gas properties of $0.5 million.~~

Acquisitions of proved and unproved properties are also measured at fair value on a nonrecurring basis. The Company utilizes a discounted cash flow model to estimate the fair value of acquired property as of the acquisition date, which utilizes the following inputs to estimate future net cash flows: (i) estimated quantities of oil and condensate, gas and NGL reserves; (ii) estimates of future commodity prices; and (iii) estimated production rates, and future operating and development costs, which are based on the Company's historic experience with similar properties. In some instances, market comparable information of recent transactions is used to estimate fair value of unproved acreage. Due to the unobservable characteristics of the inputs, the fair value of the acquired properties is considered Level 3 within the fair value hierarchy. Refer to Note 3 – Acquisitions and Divestitures for more information on the fair value of acquired properties.

Note 7 – Derivative Contracts

QEP has established policies and procedures for managing commodity price volatility through the use of derivative instruments. In the normal course of business, QEP uses commodity price derivative instruments to reduce the impact of potential downward movements in commodity prices on cash flow, returns on capital investment, and other financial results. However, these instruments typically limit gains from favorable price movements. The volume of production subject to commodity derivative instruments and the mix of the instruments are frequently evaluated and adjusted by management in response to changing market conditions. QEP may enter into commodity derivative contracts for up to 100% of forecasted production, but generally, QEP enters into commodity derivative contracts for approximately 50% to 75% of its forecasted annual production by the end of the first quarter of each fiscal year. ~~In addition, during the time that QEP owned gas storage facilities or had contracts for gas storage capacity, QEP entered into commodity derivative contracts on a portion of its storage transactions.~~ QEP does not enter into commodity derivative contracts for speculative purposes.

QEP uses commodity derivative instruments known as fixed-price swaps, basis swaps or costless collars to realize a known price or price range for a specific volume of production delivered into a regional sales point. QEP's commodity derivative instruments do not require the physical delivery of oil or gas between the parties at settlement. All transactions are settled in cash with one party paying the other for the net difference in prices, multiplied by the contract volume, for the settlement period. Oil price derivative instruments are typically structured as NYMEX fixed-price swaps based at Cushing, Oklahoma. QEP has also entered into oil price derivative swaps that use Intercontinental Exchange, Inc. (ICE) Brent or regional price indices as the reference price. Gas price derivative instruments are typically structured as fixed-price swaps or collars at NYMEX Henry Hub or regional price indices. QEP also enters into oil basis swaps to achieve a fixed-price swap for a portion of its oil sales at prices that reference specific regional index prices.

QEP does not currently have any commodity derivative instruments that have margin requirements or collateral provisions that would require payments prior to the scheduled settlement dates. QEP's commodity derivative contract counterparties are typically financial institutions and energy trading firms with investment-grade credit ratings. QEP routinely monitors and manages its exposure to counterparty risk by requiring specific minimum credit standards for all counterparties, actively monitoring counterparties' public credit ratings and avoiding the concentration of credit exposure by transacting with multiple counterparties. The Company has master-netting agreements with some counterparties that allow the offsetting of receivables and payables in a default situation.

Derivative Contracts – Production

The following table presents QEP's volumes and average prices for its commodity derivative swap contracts as of March 31, ~~2019:~~2020:



Year	Index	Total Volumes	Average Swap Price per Unit
		(in millions)
Oil sales		(bbls)	($/bbl)
2020	NYMEX WTI	11.0	$	57.75
2020	Argus WTI Midland	1.1	$	57.30
2020	Argus WTI Houston	0.5	$	60.06
2021	NYMEX WTI	1.6	$	55.04
Gas sales		(MMbtu)	($/MMbtu)
2020	IF Waha⁽¹⁾	8.3	$	0.63
2020	NYMEX HH	5.5	$	2.11
2021	IF Waha⁽¹⁾	7.3	$	1.47
2021	NYMEX HH	7.3	$	2.38

Year Index Total Volumes Average Swap Price per Unit
(in millions)
Oil sales (bbls)
($/bbl)
2019 NYMEX WTI 9.5
$ 54.93
2019 ICE Brent 1.1
$ 66.54
2020 NYMEX WTI 5.1
$ 60.01
_______________________


⁽¹⁾	IF Waha Index pricing reported in Platts' Inside FERC's Gas Market Report, reflecting the weighted average price of Natural Gas transactions at the Waha Hub in west Texas on the first day of the month.

QEP uses oil basis swaps, combined with NYMEX WTI fixed-price swaps, to achieve fixed price swaps for the location at which it physically sells its ~~physical~~ production. The following table presents details of QEP's oil basis swaps as of March 31, ~~2019:~~2020:



Year	Index	Basis	Total Volumes	Weighted-Average Differential
			(in millions)
Oil sales			(bbls)	($/bbl)
2020	NYMEX WTI	Argus WTI Midland	5.2	$	0.20
2020	NYMEX WTI	Argus WTI Houston	0.2	$	3.75
2021	NYMEX WTI	Argus WTI Midland	4.4	$	0.99

Year Index Basis Total Volumes Weighted-Average Differential
(in millions)
Oil sales (bbls)
($/bbl)
2019 NYMEX WTI Argus WTI Midland 5.0
$ (2.22 )
2019 NYMEX WTI Argus WTI Houston 0.6
$ 3.75
2020 NYMEX WTI Argus WTI Midland 2.6
$ (0.46 )

~~QEP Derivative Financial Statement Presentation~~

The following table identifies the Condensed Consolidated Balance Sheet location of QEP's outstanding derivative contracts on a gross contract basis as opposed to the net contract basis presentation on the Condensed Consolidated Balance Sheets and the related fair values at the balance sheet dates:

Gross asset derivative
instruments fair value Gross liability derivative
instruments fair value
Balance Sheet line item March 31,
2019 December 31,
2018 March 31,
2019 December 31,
2018
Current: (in millions)
Commodity⁽¹⁾
Fair value of derivative contracts $ —
$ 88.2
$ 60.3
$ 0.4
Long-term:
Commodity Fair value of derivative contracts 6.7
35.4
1.5
0.7
Total derivative instruments $ 6.7
$ 123.6
$ 61.8
$ 1.1

~~_______________________~~


⁽¹⁾	Includes fair value of derivative contracts classified as "Noncurrent assets held for sale" of $0.3 million as of December 31, 2018 on the Condensed Consolidated Balance Sheet related to the Haynesville Divestiture.

The effects of the change in fair value and settlement of QEP's derivative contracts recorded in "Realized and unrealized gains (losses) on derivative contracts" on the ~~Condensed Consolidated Statements~~statements of ~~Operations~~operations are summarized in the following table:



	Three Months Ended
Derivative contracts	March 31,
Derivative contracts	2020			2019
Realized gains (losses) on commodity derivative contracts	(in millions)
Production
Oil derivative contracts	$	42.6		$	(3.0	)
Gas derivative contracts	—			(2.9		)
Realized gains (losses) on commodity derivative contracts	42.6			(5.9		)
Unrealized gains (losses) on commodity derivative contracts
Production
Oil derivative contracts	413.9			(177.3		)
Gas derivative contracts	(6.6		)	(0.3		)
Unrealized gains (losses) on commodity derivative contracts	407.3			(177.6		)
Total realized and unrealized gains (losses) on commodity derivative contracts related to production	$	449.9		$	(183.5	)

Derivatives associated with Haynesville Divestiture
Unrealized gains (losses) on commodity derivative contracts
Production
Gas derivative contracts	—			1.8
Unrealized gains (losses) on commodity derivative contracts related to divestitures ⁽¹⁾	$	—		$	1.8

Total realized and unrealized gains (losses) on commodity derivative contracts	$	449.9		$	(181.7	)

Three Months Ended
Derivative contracts March 31,
2019 2018
Realized gains (losses) on commodity derivative contracts (in millions)
Production
Oil derivative contracts $ (3.0 ) $ (44.3 )
Gas derivative contracts (2.9 ) 0.9
Gas Storage
Gas derivative contracts —
0.2
Realized gains (losses) on commodity derivative contracts (5.9 ) (43.2 )
Unrealized gains (losses) on commodity derivative contracts
Production
Oil derivative contracts (177.3 ) (6.9 )
Gas derivative contracts (0.3 ) (2.8 )
Gas Storage
Gas derivative contracts —
(0.3 )
Unrealized gains (losses) on commodity derivative contracts (177.6 ) (10.0 )
Total realized and unrealized gains (losses) on commodity derivative contracts related to production and storage $ (183.5 ) $ (53.2 )

Derivatives associated with Haynesville Divestiture
Unrealized gains (losses) on commodity derivative contracts
Production
Gas derivative contracts 1.8
—
Unrealized gains (losses) on commodity derivative contracts related to divestitures⁽¹⁾
$ 1.8
$ —

Total realized and unrealized gains (losses) on commodity derivative contracts $ (181.7 ) $ (53.2 )

_______________________

⁽¹⁾

During the three months ended March 31, 2019, the unrealized gains (losses) on commodity derivative contracts related to the Haynesville Divestiture were comprised of derivatives included as part of the Haynesville/Cotton Valley purchase and sale agreement, which were subsequently novated to the buyer upon the closing of the sale in January 2019. Refer to Note 3 – Acquisitions and Divestitures for more information. The unrealized gains (losses) on commodity derivatives associated with the Haynesville Divestiture are offset by an equal amount recorded within "Net gain (loss) from asset sales, inclusive of restructuring costs" on the ~~Condensed Consolidated Statements~~statements of ~~Operations.~~operations.

Note 8 – Leases

~~Adoption of ASC Topic 842,~~ ~~Leases~~

~~On January 1, 2019, QEP adopted ASC Topic 842,~~ ~~Leases~~, using the modified retrospective approach, which was applied to historical leases that were still effective as of January 1, 2019. Results for reporting periods beginning January 1, 2019, are presented in accordance with ASC Topic 842, while prior period amounts are reported in accordance with historical accounting treatment under ASC Topic 840, ~~Leases~~.

In accordance with the adoption of ASC Topic 842, QEP now records a net operating lease right-of-use asset and operating lease liability on the Condensed Consolidated Balance Sheets for all operating leases with a contract term in excess of 12 months. Prior to the adoption of ASC Topic 842, these same leases were treated as operating leases under ASC Topic 840 and therefore were not recorded on the December 31, 2018 Consolidated Balance Sheets. There was no impact to retained earnings and no significant impact on the Condensed Statement of Operations or the Condensed Consolidated Statement of Cash Flows as a result of adopting ASC Topic 842.

~~Lease Recognition~~

QEP ~~has entered~~enters into contractual lease arrangements to rent office space, compressors, generators, drilling rigs and other equipment from third-party lessors. ~~Right-of-use~~QEP records a net operating lease right-of-use (ROU) asset and operating lease liability on the balance sheets for all operating leases with a contract term in excess of 12 months. ROU assets represent QEP’s right to use an underlying asset for the lease term and lease liabilities represent QEP’s obligation to make future lease payments arising from the lease. Operating lease ROU assets and liabilities are recorded at commencement date based on the present value of lease payments over the lease term. Leases with an initial term of 12 months or less are not recorded on the balance ~~sheet.~~sheets. The Company recognizes lease expense for these short-term leases on a straight-line basis over the lease term. With the exception of generators, QEP does not account for lease components separately from the non-lease components. The contractual consideration provided under QEP's leased generators is allocated between lease components, such as equipment, and non-lease components, such as maintenance service fees, based on estimated costs from the vendor. QEP uses ~~the implicit interest rate when readily determinable. However, most of QEP's lease agreements do not provide an implicit interest rate. As such, QEP uses~~ its incremental borrowing rate ~~based on the information available~~ at commencement date of the contract in ~~determining~~calculating the present value of future lease payments. The incremental borrowing rate is calculated using a risk-free interest rate adjusted for QEP's risk. The operating lease ROU asset also includes any lease incentives received in the recognition of the present value of future lease payments. Certain of QEP's leases may also include escalation clauses or options to extend or terminate the lease. These options are included in the present value recorded for the leases when it is reasonably certain that QEP will exercise that option. Lease expense for lease payments is recognized on a straight-line basis over the lease term.

QEP determines if an arrangement is a lease at inception of the contract and records the resulting operating lease asset on the ~~Condensed Consolidated Balance Sheets~~balance sheets as “Operating lease right-of-use assets, net” with offsetting liabilities recorded as “Current operating lease liabilities” and “Operating lease ~~liabilities”.~~liabilities.” QEP recognizes a lease in the financial statements when the arrangement either explicitly or implicitly involves property, plant, or equipment (PP&E), the contract terms are dependent on the use of the PP&E, and QEP has the ability or right to operate the PP&E or to direct others to operate the PP&E and receive ~~greater than 10%~~the majority of the economic benefits of the assets. As of March 31, ~~2019,~~2020, QEP does not have any financing leases.

Lease costs represent the ~~straight line~~straight-line lease expense of ROU assets and short-term leases. The components of lease cost are classified as follows:


			Three Months Ended		Three Months Ended
	March 31, 2019⁽¹⁾		March 31, 2020		March 31, 2019
Lease Cost included in the Condensed Consolidated Balance Sheets	(in millions)		(in millions)
Property, Plant and Equipment acquisitions⁽²⁾	$	4.7
Property, Plant and Equipment acquisitions⁽¹⁾			$	4.4	$	4.7

	Three Months Ended		Three Months Ended		Three Months Ended
	March 31, 2019⁽¹⁾		March 31, 2020		March 31, 2019
Lease Cost included in the Condensed Consolidated Statement of Operations	(in millions)		(in millions)
Lease operating expense	$	3.1	$	2.5	$	3.1
Gathering and other expense	1.5		1.9		1.5
General and administrative	1.6		1.5		1.6

Total lease cost	$	10.9	$	10.3	$	10.9

____________________________


⁽¹⁾	Prior periods are not presented as prior period amounts have not been adjusted under the modified retrospective method for the new lease recognition rule. Refer to Note 1 – Basis of Presentation for additional information.


⁽²⁾	Represents short-term lease capital expenditures related to drilling rigs for the three months ended March 31, 2020 and 2019. These costs are capitalized as a part of "Proved properties" on the balance sheets.

Lease term and discount rate related to the Company's leases are as follows:



	Three Months Ended		Three Months Ended
	March 31, 2020		March 31, 2019
Weighted-average remaining lease term (years)	4.3		3.8
Weighted-average discount rate	7.5	%	8.1	%



	~~Three Months Ended~~
	~~March 31, 2019~~⁽¹⁾
~~Weighted-average remaining lease term (years)~~	~~3.8~~
~~Weighted-average discount rate~~	~~8.1~~	%

As of March 31, 2020 and December 31, 2019, the maturity analysis for long-term operating leases under the scope of ASC 842 are as follows:



	March 31, 2020			December 31, 2019
Year	(in millions)
2020	$	17.0		$	22.3
2021	21.1			20.4
2022	16.3			15.9
2023	11.0			10.6
2024	1.7			1.4
After 2024	2.5			2.4
Less: Interest⁽¹⁾	(8.8		)	(10.2		)
Present value of lease liabilities⁽²⁾	$	60.8		$	62.8

____________________________


⁽¹⁾	~~Prior periods are not presented as prior period amounts have not been adjusted under~~Calculated using the ~~modified retrospective method~~estimated interest rate for each lease.

⁽²⁾

As of March 31, 2020 and December 31, 2019, of the ~~new~~total present value of lease ~~recognition rule. Refer to Note 1 – Basis of Presentation for additional information.~~liabilities, $18.5 million and $18.0 million, was recorded in "Current operating lease liabilities", respectively, and $42.3 million and $44.8 million was recorded in "Operating lease liabilities", respectively, on the balance sheets.

~~Refer to Note 11 – Commitments and Contingencies for a reconciliation of our minimum future lease payments to the Condensed Consolidated Balance Sheets.~~

Note 9 – Restructuring

In February 2018, QEP's Board of Directors approved certain strategic and financial ~~initiatives and in~~initiatives. In February 2019, QEP's Board of Directors commenced a comprehensive review of strategic alternatives to maximize shareholder value. In connection with these ~~strategic and financial initiatives,~~activities, QEP has incurred ~~or expects to incur~~ various restructuring costs associated with contractual termination benefits including severance, accelerated vesting of share-based compensation and other expenses. The termination benefits ~~will be~~are accounted for under ASC 712, Compensation – Nonretirement Postemployment Benefits and ASC 718, Compensation – Stock Compensation.

Restructuring costs recognized are summarized below:



	Total recognized			Recognized in "General and administrative"		Recognized in "Net (gain) loss from asset sales, inclusive of restructuring costs"			Recognized in "Interest and other (income) expense"
	Three Months Ended March 31, 2020
	(in millions)
Termination benefits	$	1.0		$	1.0	$	—		$	—
Accelerated share-based compensation⁽¹⁾	0.2			0.2		—			—
Retention expense (including share-based compensation)	0.2			0.2		—			—
Total restructuring costs	$	1.4		$	1.4	$	—		$	—

	Three Months Ended March 31, 2019
Termination benefits	$	6.8		$	6.7	$	0.1		—
Office lease termination costs	0.6			0.6		—			—
Accelerated share-based compensation⁽¹⁾	8.4			6.9		1.5			—
Retention expense (including share-based compensation)	6.1			6.1		—			—
Pension and Medical Plan curtailment	(0.5		)	—		(0.2		)	(0.3		)
Total restructuring costs	$	21.4		$	20.3	$	1.4		$	(0.3	)

Total recognized Recognized in "General and administrative" Recognized in "Net gain (loss) from asset sales, inclusive of restructuring costs" Recognized in "Interest and other income (expense)"
Three Months Ended March 31, 2019
(in millions)
Termination benefits $ 6.8
$ 6.7
$ 0.1
—
Office lease termination costs 0.6
0.6
—
—
Accelerated share-based compensation⁽¹⁾
8.4
6.9
1.5
—
Retention expense (including share-based compensation) 6.1
6.1
—
—
Pension and Medical Plan curtailment (0.5 ) —
(0.2 ) (0.3 )
Total restructuring costs $ 21.4
$ 20.3
$ 1.4
$ (0.3 )

Three Months Ended March 31, 2018
(in millions)
Termination benefits $ 3.4
$ 3.4
$ —
$ —
Office lease termination costs —
—
—
—
Accelerated share-based compensation 2.8
2.8
—
—
Retention expense (including share-based compensation) 1.7
1.7
—
—
Pension and Medical Plan curtailment —
—
—
—
Total restructuring costs $ 7.9
$ 7.9
$ —
$ —

____________________________

⁽¹⁾

Accelerated share-based compensation represents the additional expense or loss recognized in the ~~Consolidated Statement~~statement of ~~Operations~~operations for the three months ended March 31, 2020 and 2019. Total accelerated ~~share based~~share-based compensation was $0.6 million and $8.8 million as of March 31, 2020 and 2019, respectively, and was determined based on the contractual vesting date, with $0.2 million and $8.4 million recognized during the three months ended March 31, 2020 and 2019, respectively, as shown above, and the remaining amount recognized in prior periods.


	Costs recognized period from inception to March 31, 2019⁽¹⁾			Total remaining costs expected to be incurred			Costs recognized from inception through March 31, 2020⁽¹⁾		Total remaining costs expected to be incurred
	(in millions)						(in millions)
Termination benefits	$	39.0		$	—	⁽²⁾	$	45.6	$	—
Office lease termination costs	1.6			—		⁽²⁾	1.6		—
Accelerated share-based compensation⁽²⁾	19.7			—		⁽²⁾	23.8		—		⁽²⁾
Retention expense (including share-based compensation)	24.9			15.1			38.5		0.2
Pension and Medical Plan curtailment	(0.4		)	—		⁽²⁾	1.3		—
Total restructuring costs	$	84.8		$	15.1		$	110.8	$	0.2

____________________________


⁽¹⁾	Represents costs incurred since February 2018 when QEP's Board of Directors approved certain strategic and financial initiatives.


⁽²⁾	Due to the nature of the ~~strategic initiatives and uncertain factors such~~accelerated share-based compensation, as ~~the timing and terms~~ of ~~the potential strategic alternatives,~~March 31, 2020, the Company is not able to reasonably estimate the total cost to be incurred ~~as a part of~~in connection with these restructurings.

The following table is a reconciliation of QEP's restructuring liability, which is included within "Accounts payable and accrued expenses" on the ~~Condensed Consolidated Balance Sheets.~~balance sheets.



	Restructuring liability
	Termination benefits			Office lease termination costs		Accelerated share-based compensation			Retention expense			Pension curtailment		Total
	(in millions)
Balance at December 31, 2019	$	1.2		$	—	$	—		$	6.5		$	—	$	7.7
Costs incurred and charged to expense	1.0			—		0.2			0.2			—		1.4
Costs paid or otherwise settled	(1.0		)	—		(0.2		)	(6.5		)	—		(7.7		)
Balance at March 31, 2020	$	1.2		$	—	$	—		$	0.2		$	—	$	1.4

Restructuring liability
Termination benefits Office lease termination costs Accelerated share-based compensation Retention expense Pension curtailment Total
(in millions)
Balance at December 31, 2018 $ 19.5
$ —
$ —
$ 10.8
$ —
$ 30.3
Costs incurred and charged to expense 6.8
0.6
8.4
6.1
(0.5 ) 21.4
Costs paid or otherwise settled (16.3 ) —
(8.4 ) (15.5 ) 0.5
(39.7 )
Balance at March 31, 2019 $ 10.0
$ 0.6
$ —
$ 1.4
$ —
$ 12.0

Note 10 – Debt

As of the indicated dates, the principal amount of QEP's debt consisted of the following:



	March 31, 2020			December 31, 2019
	(in millions)
Revolving Credit Facility due 2022	$	—		$	—
6.875% Senior Notes due 2021	332.3			382.4
5.375% Senior Notes due 2022	465.1			500.0
5.25% Senior Notes due 2023	636.8			650.0
5.625% Senior Notes due 2026	500.0			500.0
Less: unamortized discount and unamortized debt issuance costs	(15.2		)	(16.8		)
Total principal amount of debt (including current portion)	1,919.0			2,015.6
Less: current portion of long-term debt	(331.6		)	—
Total long-term debt outstanding	$	1,587.4		$	2,015.6

March 31,
2019 December 31,
2018
(in millions)
Revolving Credit Facility due 2022 $ —
$ 430.0
6.80% Senior Notes due 2020 51.7
51.7
6.875% Senior Notes due 2021 397.6
397.6
5.375% Senior Notes due 2022 500.0
500.0
5.25% Senior Notes due 2023 650.0
650.0
5.625% Senior Notes due 2026 500.0
500.0
Less: unamortized discount and unamortized debt issuance costs (20.9 ) (22.2 )
Total principal amount of debt (including current portion) 2,078.4
2,507.1
Less: current portion of long-term debt (51.7 ) —
Total long-term debt outstanding $ 2,026.7
$ 2,507.1

Of the total debt outstanding on March 31, ~~2019, the 6.80% Senior Notes due March 1,~~ 2020, the 6.875% Senior Notes due March 1, 2021, the 5.375% Senior Notes due October 1, 2022 and the 5.25% Senior Notes due May 1, 2023, will mature within the next five years. In addition, the revolving credit facility matures on September 1, 2022.

Credit Facility

QEP's unsecured revolving credit facility, which matures ~~subject to satisfaction of certain conditions,~~ in September 2022, provides for loan commitments of $1.25 billion. The credit facility provides for borrowings at short-term interest rates and contains customary covenants and restrictions. The credit agreement ~~governing QEP's revolving credit facility~~ contains financial covenants (that are defined in the credit agreement) that limit the amount of debt the Company can incur and may limit the amount available to be drawn under the credit facility including: (i) a net funded debt to capitalization ratio that may not exceed 60%, (ii) a leverage ratio under which net funded debt may not exceed 3.75 times consolidated EBITDA (as defined in the credit agreement), and (iii) a present value coverage ratio under which the present value of the Company's proved reserves must exceed net funded debt by ~~1.40 times through December 31, 2019, and must exceed net funded debt by~~ 1.50 times at any time on or after January 1, 2020. At March 31, ~~2019~~2020 and December 31, ~~2018,~~2019, QEP was in compliance with the covenants under ~~the~~its credit agreement.

~~During the three months ended March 31, 2019, QEP's weighted-average interest rate on borrowings from its credit facility was 4.73%.~~ As of March 31, 2020, and December 31, 2019, respectively, QEP had no borrowings outstanding and ~~$1.3 million in letters of credit outstanding under the credit facility. As of December 31, 2018, QEP had $430.0 million of borrowings outstanding and $0.3~~$2.9 million in letters of credit outstanding under the credit facility.

Senior Notes

At March 31, ~~2019,~~2020, the Company had ~~$2,099.3~~$1,934.2 million in principal amount of senior notes outstanding with maturities ranging from March ~~2020~~1, 2021 to March 1, 2026, and coupons ranging from 5.25% to 6.875%. The senior notes pay interest semi-annually, are unsecured senior obligations and rank equally with all of QEP's other existing and future unsecured and senior obligations. QEP may redeem some or all of its senior notes at any time before their maturity at a redemption price based on a make-whole amount plus accrued and unpaid interest to the date of redemption. The indentures governing QEP's senior notes contain customary events of default and covenants that may limit QEP's ability to, among other things, place liens on its property or assets. During the period ended March 31, 2020, QEP repurchased principal amounts of $50.1 million of its 6.875% Senior Notes due March 2021, $34.9 million of its 5.375% Senior Notes due October 1, 2022 and $13.2 million of its 5.25% Senior Notes due May 1, 2023. The Company recorded $25.2 million in "Gain from early extinguishment of debt" on the statements of operations associated with the repurchase of Senior Notes during the period ended March 31, 2020.

Note 11 – Commitments and Contingencies

The Company is involved in various commercial and regulatory claims, litigation and other legal proceedings that arise in the ordinary course of its business. In each reporting period, the Company assesses these claims in an effort to determine the degree of probability and range of possible loss for potential accrual in its ~~Condensed Consolidated Financial Statements.~~financial statements. In accordance with ASC 450, Contingencies, an accrual is recorded for a material loss contingency when its occurrence is probable and damages are reasonably estimable based on the anticipated most likely outcome or the minimum amount within a range of possible outcomes.

Legal proceedings are inherently unpredictable and unfavorable resolutions can occur. Assessing contingencies is highly subjective and requires judgment about uncertain future events. When evaluating contingencies related to legal proceedings, the Company may be unable to estimate losses due to a number of factors, including potential defenses, the procedural status of the matter in question, the presence of complex legal and/or factual issues and the ongoing discovery and/or development of information important to the matter.

~~Landowner~~Mabee Ranch Royalty Partnership Litigation – In October 2017, the owners of certain surface and mineral interests in Martin and Andrews County, Texas, filed suit against QEP, alleging QEP improperly used the surface of the properties and failed to correctly pay royalties, and seeking ~~money~~monetary damages and a declaratory judgment that portions of the oil and gas leases covering the properties are no longer in effect. The parties have reached a settlement involving no cash consideration and have jointly moved to dismiss the litigation.

Mandan, Hidatsa and Arikara Nation ("MHA Nation") Title Dispute – In June 2018, the MHA Nation notified QEP of its position that QEP has no valid lease covering certain minerals underlying the Missouri and Little Missouri Riverbeds on the Fort Berthold Reservation in North Dakota. The MHA Nation also passed a resolution purporting to rescind those portions of QEP's IMDA lease covering the disputed minerals underlying the Missouri River.

~~The~~Overriding Royalty Interest Litigation –In July 2019, owners of small overriding royalty interests in certain wells in the South Antelope oil and gas field in North Dakota filed suit against QEP, alleging QEP has improperly taken deductions for post-production expenses.

In many cases, the Company is unable to make an estimate of the range of reasonably possible loss related to its contingencies. To the extent that the Company can reasonably estimate losses for contingencies where the risk of material loss (in excess of accruals, if any) is reasonably possible, the Company estimates such losses to be in a range of zero to approximately $10.0 million, in the aggregate.

~~Commitments~~

QEP has entered into contractual lease arrangements to rent office space, compressors, generators, drilling rigs and other equipment from third-party lessors. On January 1, 2019, QEP adopted ASC Topic 842, ~~Leases, using the modified retrospective approach. Refer to Note 8 – Leases for additional information.~~

~~As of March 31, 2019, minimum future payments, including imputed interest, for long-term operating leases under the scope of ASC 842 are as follows:~~

Year Amount
(in millions)
2019 $ 19.5
2020 $ 20.3
2021 $ 18.1
2022 $ 14.1
2023 $ 8.9
After 2023 $ 0.5
Less: Interest⁽¹⁾
$ (11.9 )
Present value of lease liabilities⁽²⁾
$ 69.5

~~____________________________~~


⁽¹⁾	~~Calculated using the estimated or stated interest rate for each lease.~~


⁽²⁾	Of the total present value of lease liabilities, $20.1 million was recorded in "Current operating lease liabilities" and $49.4 million was recorded in "Operating lease liabilities" on the Condensed Consolidated Balance Sheets.

~~As of December 31, 2018, minimum future contractual payments for long-term operating leases under the scope of ASC 840 are as follows:~~

Year Amount
(in millions)
2019 $ 17.4
2020 $ 13.8
2021 $ 9.1
2022 $ 7.4
2023 $ 4.5
After 2023 $ —

Note 12 – Share-Based and Long-Term Incentive Compensation

In 2018, QEP's Board of Directors and QEP's shareholders approved the QEP Resources, Inc. 2018 Long-Term Incentive Plan (LTIP), which ~~replaces~~replaced the 2010 Long-Term Stock Incentive Plan (LTSIP) and provides for the issuance of up to 10.0 million shares such that the Board of Directors may grant long-term incentive compensation. QEP ~~has issued stock options,~~issues restricted share awards, restricted cash awards and restricted share units under its LTSIP or LTIP and awards performance share units under its Cash Incentive Plan (CIP) to certain officers, employees and non-employee directors. Grants issued prior to May 15, 2018 were under the LTSIP and grants issued on or after May 15, 2018 are under the LTIP. QEP recognizes the expense over the vesting periods for ~~the~~ stock options, restricted share awards, restricted cash awards, restricted share units and performance share units. There were ~~8.3~~3.7 million shares available for future grants under the LTIP at March 31, ~~2019.~~2020.

Share-based compensation expense is generally recognized within "General and administrative" expense on the ~~Condensed Consolidated Statements~~statements of ~~Operations~~operations and is summarized in the table below.



	Three Months Ended
	March 31,
	2020⁽¹⁾		2019⁽²⁾
	(in millions)
Stock options	$	—	$	0.3
Restricted share awards	3.3		6.1
Restricted cash awards	0.2		—
Performance share units	0.4		5.2
Restricted share units	—		0.1
Total share-based compensation expense	$	3.9	$	11.7

________________________


⁽¹⁾	During the three months ended March 31, 2020, the Company recorded an additional $0.2 million of share-based compensation expense related to the acceleration of vesting that occurred as part of the restructuring program. Refer to Note 9 – Restructuring for additional information.

⁽²⁾

During the three months ended March 31, 2019, the Company recorded $8.4 million of share-based compensation expense related to the acceleration of vesting that occurred as part of the restructuring program, of which $1.5 million was recorded in "Net gain (loss) from asset sales, inclusive of restructuring costs" on the statement of operations during the three months ended March 31, 2019 and the remaining $6.9 million is included in the table above. Refer to Note 9 – Restructuring for additional information.

Stock Options

During the three months ended March 31, ~~2019,~~2020, QEP did not issue stock options to its employees. In periods when QEP granted stock options, the Company recorded an additional $8.4 million of share-based compensation expense related to the acceleration of vesting that occurred as part of the restructuring program, of which $1.5 million was recorded in "Net gain (loss) from asset sales, inclusive of restructuring costs" on the Condensed Consolidated Statement of Operations and the remaining $6.9 million is included in the table below. During the three months ended March 31, 2018, the Company recorded an additional $2.8 million of share-based compensation expense, related to the acceleration of vesting that occurred as part of the restructuring program, all of which is included in the table below. Refer to Note 9 – Restructuring for additional information.

Three Months Ended
March 31,
2019 2018
(in millions)
Stock options $ 0.3
$ 0.5
Restricted share awards 6.1
8.8
Performance share units 5.2
1.9
Restricted share units 0.1
—
Total share-based compensation expense $ 11.7
$ 11.2

~~Stock Options~~

~~QEP uses~~historically used the Black-Scholes-Merton mathematical model to estimate the fair value of stock option awards at the date of grant. Fair value calculations rely upon subjective assumptions used in the mathematical model and may not be representative of future results. The Black-Scholes-Merton model is intended for calculating the value of ~~stock~~ options not traded on an exchange. The Company ~~utilizes~~utilized the "simplified" method to estimate the expected term of the stock options granted as there iswas limited historical exercise data available in estimating the expected term of the stock options. QEP ~~uses~~used a historical volatility method to estimate the fair value of stock ~~options~~option awards, and the risk-free interest rate iswas based on the yield on U.S. Treasury strips with maturities similar to those of the expected term of the stock options. The stock options typically vest in equal installments over ~~a three-year period~~three years from the grant date and are exercisable immediately upon vesting through the seventh anniversary of the grant date. To fulfill options exercised, QEP either reissues treasury stock or issues new shares. The Company recognizes forfeitures of stock options as they occur. ~~During the three months ended March 31, 2019, QEP did not issue stock options.~~

Stock option transactions under the terms of the LTSIP are summarized below:



	Options Outstanding		Weighted-Average Exercise Price		Weighted-Average Remaining Contractual Term	Aggregate Intrinsic Value
			(per share)		(in years)	(in millions)
Outstanding at December 31, 2019	1,802,387		$	20.87
Cancelled	(305,163	)	30.12
Outstanding at March 31, 2020	1,497,224		$	18.98	2.51	$	—
Options Exercisable at March 31, 2020	1,494,157		$	19.00	2.51	$	—
Unvested Options at March 31, 2020	3,067		$	7.52	4.42	$	—

Options Outstanding Weighted-Average Exercise Price Weighted-Average Remaining Contractual Term Aggregate Intrinsic Value
(per share) (in years) (in millions)
Outstanding at December 31, 2018 2,098,933
$ 22.27

Cancelled (283,029 ) 30.90

Outstanding at March 31, 2019 1,815,904
$ 20.93
3.05 $ —
Options Exercisable at March 31, 2019 1,754,713
$ 21.10
2.98 $ —
Unvested Options at March 31, 2019 61,191
$ 16.03
4.93 $ —

During the three months ended March 31, ~~2019 and 2018,~~2020 there were no exercises of stock options. The Company recognized $1.0 million of income tax expense for the cancellation of options for the three months ended March 31, 2020, and no income tax expense related to stock options for the three months ended March 31, 2019. As of March 31, ~~2019, $0.1 million of~~2020, there was no unrecognized compensation expense related to stock options granted under the ~~LTSIP is expected to be recognized over a weighted-average vesting period of 1.00 year. The weighted-average vesting period may be reduced due to accelerated vestings under the restructuring program.~~LTSIP. Refer to Note 9 – Restructuring for additional information.

Restricted Share Awards

Restricted share award grants typically vest in equal installments over ~~a three-year period~~three years from the grant date. The grant date fair value is determined based on the closing bid price of the Company's common stock on the grant date. The Company recognizes restricted share forfeitures as they occur. The total fair value of restricted share awards that vested during the three months ended March 31, 2020 and 2019 was $10.5 million and ~~2018 was~~ $22.8 million, respectively. The Company recognized $1.9 million of income tax expense for shares that were either vested or forfeited during the three months ended March 31, 2020, and ~~$21.0 million, respectively.~~no income tax expense related to restricted shares for the three months ended March 31, 2019. The weighted-average grant date fair value of restricted share awards was ~~$7.98~~$2.18 per share and ~~$9.55~~$7.98 per share for the three months ended March 31, ~~2019~~2020 and ~~2018,~~2019, respectively. As of March 31, ~~2019, $24.3~~2020, $16.4 million of unrecognized compensation expense related to restricted share awards granted under the LTSIP and LTIP is expected to be recognized over a weighted-average vesting period of ~~2.50~~2.51 years. ~~The weighted-average vesting period may be reduced due to accelerated vestings under the restructuring program. Refer to Note 9 – Restructuring for additional information.~~

Transactions involving restricted share awards under the terms of the LTSIP and LTIP are summarized below:



	Restricted Share Awards Outstanding		Weighted-Average Grant Date Fair Value
			(per share)
Unvested balance at December 31, 2019	2,845,033		$	8.67
Granted	4,860,052		2.18
Vested	(1,073,255	)	9.76
Forfeited	(12,583	)	8.61
Unvested balance at March 31, 2020	6,619,247		$	3.73

Restricted Share Awards Outstanding Weighted-Average Grant Date Fair Value
(per share)
Unvested balance at December 31, 2018 3,822,133
$ 10.76
Granted 2,178,950
7.98
Vested (2,052,013 ) 11.13
Forfeited (73,925 ) 9.40
Unvested balance at March 31, 2019 3,875,145
$ 9.03

Restricted Cash Awards

Beginning in March 2020, QEP issued restricted cash awards under its LTIP to certain employees. Restricted cash award grants vest in equal installments over three years from the grant date. The Company recognizes restricted cash forfeitures as they occur. There were no restricted cash awards granted or outstanding during the three months ended March 31, 2019. As of March 31, 2020, $3.1 million of unrecognized compensation expense related to restricted cash awards granted under the LTIP is expected to be recognized over a weighted-average vesting period of 3.0 years.

Transactions involving restricted cash awards under the terms of the LTIP are summarized below:



	Restricted Cash Awards Outstanding

Unvested balance at December 31, 2019	$	—
Granted	3,216,675
Vested	—
Forfeited	—
Unvested balance at March 31, 2020	$	3,216,675

Performance Share Units

The payouts ~~for~~associated with performance share units under the CIP are dependent upon the Company's total shareholder return compared to a group of its peers over ~~a three-year period.~~three years. The awards are denominated in share units and have historically been paid in cash. The Company has the option to settle earned awards in cash or shares of common stock under the Company's LTIP; however, as of March 31, ~~2019,~~2020, the Company expects to settle all awards ~~in cash~~ under the ~~CIP.~~CIP in cash. These awards are classified as liabilities and are included within "Other long-term liabilities" on the ~~Condensed Consolidated Balance Sheets. As~~balance sheets. Because these awards are dependent upon the Company's total shareholder return and stock price, they are remeasured at fair value at the end of each reporting period. The Company paid $10.9 million ~~and $1.7 million~~ for vested performance share units during the three months ended March 31, ~~2019 and 2018, respectively.~~2019. The weighted-average grant date fair value of the performance share units granted during the three months ended March 31, 2020 and 2019 was $2.17 and ~~2018 was~~ $7.93 ~~and $9.55~~ per share, respectively. As of March 31, ~~2019, $11.6~~2020, $4.9 million of unrecognized compensation cost, which represents the unvested portion of the fair market value of performance shares granted, is expected to be recognized over a weighted-average vesting period of ~~2.51~~2.53 years. ~~The weighted-average vesting period may be reduced due to accelerated vestings under the restructuring program.~~ Refer to Note 9 – Restructuring for additional information.

Transactions involving performance share units under the terms of the CIP are summarized below:



	Performance Share Units Outstanding		Weighted-Average Grant Date Fair Value
			(per share)
Unvested balance at December 31, 2019	625,922		$	9.04
Granted	1,926,026		2.17
Vested and paid	(55,186	)	16.37
Unvested balance at March 31, 2020	2,496,762		$	3.65

Performance Share Units Outstanding Weighted-Average Grant Date Fair Value
(per share)
Unvested balance at December 31, 2018 1,559,312
$ 11.47
Granted 589,412
7.93
Vested (1,075,334 ) 10.70
Unvested balance at March 31, 2019 1,073,390
$ 9.73

Restricted Share Units

Employees may elect to defer their grants of restricted share awards and these deferred awards are designated as restricted share units. Restricted share units vest over ~~a three-year period~~three years and are deferred into the Company's nonqualified, unfunded deferred compensation plan at the time of ~~vesting.~~grant. These awards are ultimately paid in ~~cash.~~cash when distributed from the deferred compensation plan. They are classified as liabilities in "Other long-term liabilities" on the ~~Condensed Consolidated Balance Sheets~~balance sheets and are measured at fair value at the end of each reporting period. The weighted-average grant date fair value of the restricted share units was ~~$7.93~~$2.08 and ~~$9.55~~$7.93 per share for the three months ended March 31, 2020 and 2019, respectively. The Company recognized $0.2 million of income tax expense related to restricted share units for the three months ended March 31, 2020, and ~~2018, respectively.~~no income tax expense related to restricted share units for the three months ended March 31, 2019. As of March 31, ~~2019, $0.4~~2020, there was less than $0.1 million of unrecognized compensation cost, which represents the unvested portion of the fair market value of restricted share units granted, is expected to be recognized over a weighted-average vesting period of 2.13 years. The weighted-average vesting period may be reduced due to accelerated vestings under the restructuring program.granted. Refer to Note 9 – Restructuring for additional information.

Transactions involving restricted share units under the terms of the LTSIP and LTIP are summarized below:



	Restricted Share Units Outstanding		Weighted-Average Grant Date Fair Value
			(per share)
Unvested balance at December 31, 2019	34,393		$	8.16
Granted	76,083		2.08
Vested and paid	(26,770	)	8.20
Unvested balance at March 31, 2020	83,706		$	2.62

Restricted Share Units Outstanding Weighted-Average Grant Date Fair Value
(per share)
Unvested balance at December 31, 2018 42,675
$ 10.47
Granted 37,224
7.93
Vested (19,039 ) 10.67
Unvested balance at March 31, 2019 60,860
$ 8.85

Note 13 – ~~Employee Benefits~~Subsequent Event

~~Pension~~On January 30, 2020, the World Health Organization (WHO) announced a global health emergency due to the risks imposed to the international community by a new strain of coronavirus known as COVID-19. In March 2020, the WHO classified the COVID-19 outbreak as a global pandemic. During this time, the crude oil market began to experience a decline in oil prices in response to concerns about oil demand due to the global economic impacts of COVID-19. In addition, policy disputes in the first quarter of 2020 between OPEC and ~~Other Postretirement Benefits~~Russia resulted in Saudi Arabia significantly discounting the price of its crude oil, as well as Saudi Arabia and Russia significantly increasing their oil supply. These actions have led to significant weakness in oil prices that have continued to decline subsequent to March 31, 2020 and caused concern for the outlook on crude oil prices for 2020 and beyond.

The Company ~~provides pension~~is not able to reasonably estimate the future costs, total magnitude and ~~other postretirement benefits to certain employees through three retiree benefit plans:~~duration of potential social, economic and labor instability as a direct result of COVID-19 at this time. Should any of these potential impacts continue for an extended period of time, it will have a negative impact on the ~~QEP Resources, Inc. Retirement Plan (the Pension Plan), the Supplemental Executive Retirement Plan (the SERP),~~demand for our oil and ~~a postretirement medical plan (the Medical Plan).~~

~~The Pension Plan is a closed, qualified, defined-benefit pension plan that is funded~~natural gas products and ~~provides pension benefits to certain QEP employees. During the three months ended March 31, 2019, the Company made contributions~~an adverse effect on our financial position and results of $2.5 million to the Pension Plan and expects to contribute an additional $2.5 million to the Pension Plan during the remainder of 2019. Contributions to the Pension Plan increase plan assets. The Pension Plan was amended in June 2015 and was frozen effective January 1, 2016, such that employees do not earn additional defined benefits for future services.

The SERP is a nonqualified retirement plan that is unfunded and provides pension benefits to certain QEP employees. During the three months ended March 31, 2019, the Company made contributions of $0.1 million to its SERP and expects to contribute an additional $0.3 million to its SERP during the remainder of 2019. Contributions to the SERP are used to fund current benefit payments. The SERP was amended and restated in June 2015 and was closed to new participants effective January 1, 2016.

The Medical Plan is a self-insured plan. It is unfunded and provides other postretirement benefits including certain health care and life insurance benefits for certain retired QEP employees. During the three months ended March 31, 2019, the Company made contributions of $0.1 million to the Medical Plan and expects to contribute $0.1 million to the Medical Plan during the remainder of 2019. Contributions to the Medical Plan are used to fund current benefit payments.

In February 2017, the Company changed the eligibility requirements for active employees eligible for the Medical Plan, as well as retirees currently enrolled. Effective July 1, 2017, the Company no longer offers the Medical Plan to retirees and spouses that are both Medicare eligible.operations. In addition, a decline in oil and gas prices and additional volatility in future pricing could negatively impact our ability to execute our operating and development plans and our ability to generate operating cash flows. To the ~~Company no longer offers life insurance to individuals retiring on or after July 1, 2017.~~

~~The Company's implementation~~extent the COVID-19 pandemic adversely affects our business and financial results, it may also have the effect of ~~its strategic initiatives may trigger curtailments related to the Pension Plan, SERP and/or Medical Plan at the closing~~heightening many of the ~~various transactions. Refer~~other risks, such as those relating to ~~Note 9 – Restructuring for more information. The Company recognized a $0.5 million pension curtailment gain as part of~~our indebtedness, our need to generate sufficient cash flows to service our indebtedness and our ability to comply with the Haynesville Divestiture included in "Interest and other income (expense)" and "Net gain (loss) from asset sales, inclusive of restructuring costs" on the Condensed Consolidated Statements of Operations.

The Company recognizes service costs related to SERP and Medical Plan benefits on the Condensed Consolidated Statements of Operations within "General and administrative" expense. All other expenses related to the Pension Plan, SERP and Medical Plan are recognized on the Condensed Consolidated Statements of Operations within "Interest and other income (expense)".

~~The following table sets forth the Company's net periodic benefit costs related to its Pension Plan, SERP and Medical Plan:~~

Three Months Ended
March 31,
2019 2018
Pension Plan and SERP benefits (in millions)
Service cost $ 0.1
$ 0.2
Interest cost 1.2
1.1
Expected return on plan assets (1.5 ) (1.4 )
Amortization of prior service costs⁽¹⁾
0.1
0.2
Amortization of actuarial losses⁽¹⁾
0.1
0.3
Curtailment (gain) loss⁽²⁾
0.3
—
Periodic expense $ 0.3
$ 0.4

Medical Plan benefits
Amortization of prior service costs⁽¹⁾
$ —
$ (0.1 )
Curtailment (gain) loss⁽²⁾
(0.8 ) —
Periodic expense $ (0.8 ) $ (0.1 )

~~____________________________~~


⁽¹⁾	Amortization of prior service costs and actuarial losses out of accumulated other comprehensive income (loss) are recognized on the Condensed Consolidated Statements of Operations within "Interest and other income (expense)".

⁽²⁾

A curtailment is recognized when there is a significant reduction in, or an elimination of, defined benefit accruals for current employees' future services. The net curtailment gain between the SERP and Medical Plan of $0.5 million is related to the Haynesville Divestiture. Of the $0.5 million curtailment gain recognized, $0.3 million was recognized on the Condensed Consolidated Statements of Operations within "Interest and other income (expense)" and $0.2 million was recognized on the Condensed Consolidated Statements of Operations within "Net gain (loss) from asset sales, inclusive of restructuring costs" for the three months ended March 31, 2019.

~~Employee Investment Plan~~

~~QEP employees may participate~~covenants contained in the QEP Employee Investment Plan, a defined-contribution plan (the 401(k) Plan). The 401(k) Plan allows eligible employees to make investments, including purchasing shares of QEP common stock, through payroll deduction at the current fair market value on the transaction date. Both employees and QEP make contributions to the 401(k) Plan. The Company may contribute a discretionary portion beyond the Company's matching contribution to employees not in the Pension Plan or SERP. During the three months ended March 31, 2019, the Company made contributions of $1.8 million to the 401(k) Plan and expects to contribute an additional $3.1 million to the 401(k) Plan during the remainder of 2019. The Company recognizes expense equal to its yearly contributions. Due to the Company's strategic initiatives, the amount expected to be contributed to the 401(k) Plan is subject to change. Refer to Note 9 – Restructuring for more information.agreements that govern our indebtedness.

As a result of freezing benefits under the Pension Plan, the 401(k) Plan and a nonqualified, unfunded deferred compensation plan (the Wrap Plan) were amended to allow the Company to make discretionary contributions in the form of Company Transition Credits to eligible participants. Eligible participants are certain highly and non-highly compensated employees who were active participants in the Pension Plan on December 31, 2015. During the three months ended March 31, 2019, the Company did not make a discretionary contribution to active participants of the Pension Plan but expects to contribute $0.1 million to eligible participants during the fourth quarter of 2019.

ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Management's Discussion and Analysis of Financial Condition and Results of Operations (MD&A) is intended to provide the reader of the financial statements with a narrative from the perspective of management on the financial condition, results of operations, liquidity and certain other factors that may affect the Company's operating results. MD&A should be read in conjunction with the ~~Condensed Consolidated Financial Statements~~financial statements and related Notes included in Part I, Item 1 of this Quarterly Report on Form 10-Q.

The following information updates the discussion of QEP's financial condition provided in its Annual Report on Form 10-K for the year ended December 31, ~~2018 (2018~~2019 (2019 Form 10-K) and analyzes the changes in the results of operations between the three months ended March 31, ~~2019~~2020 and ~~2018.~~2019. For definitions of commonly used oil and gas terms found in this Quarterly Report on Form 10-Q, please refer to the "Glossary of Terms" provided in the ~~2018~~2019 Form 10-K.

OVERVIEW

QEP Resources, Inc. is an independent crude oil and natural gas exploration and production company with operations in two regions of the United States: the Southern Region (primarily in Texas) and the Northern Region (primarily in North Dakota). Unless otherwise specified or the context otherwise requires, all references to "QEP" or the "Company" are to QEP Resources, Inc. and its subsidiaries on a consolidated basis. QEP's corporate headquarters are located in Denver, Colorado and shares of QEP's common stock trade on the New York Stock Exchange (NYSE) under the ticker symbol "QEP".

In February 2018, QEP's Board of Directors unanimously approved certain strategic and financial initiatives (2018 Strategic Initiatives), including plans to market its assets in the Williston Basin, Uinta Basin and Haynesville/Cotton Valley and focus its activities in the Permian Basin. The Company sold its Uinta Basin assets in September 2018 (Uinta Basin Divestiture) and closed the sale of the Haynesville/Cotton Valley assets in January 2019 (Haynesville Divestiture). In addition, the Company entered intoAs a ~~purchase and sale agreement for its Williston Basin assets in November 2018. However, in February 2019, the Company agreed with the buyer to terminate the purchase and sale agreement.~~

~~In February 2019, QEP's Board of Directors commenced a comprehensive review of strategic alternatives to maximize shareholder value, which could~~ result ~~in a merger or sale of the Company or other transaction involving the Company's assets. Additionally, in light~~ of the reduction of the Company's operational footprint ~~over~~in 2019 following the ~~last twelve months,~~Board of Directors' comprehensive review of strategic alternatives and determination to move forward as an independent company, QEP ~~continues to reassess~~reassessed its organizational needs and ~~intends to~~ significantly ~~reduce~~reduced its general and administrative expense ~~(excluding $61.0 million of expenses associated with our 2018 Strategic Initiatives) by approximately 45%~~in 2019 to ensure its cost structure is competitive with industry peers. The Company incurred $20.3 million of general and administrative restructuring costs related to organizational changes implemented during the first quarter of 2019 and continues to evaluate reductions in general and administrative expense.

As a part of the ~~2018~~strategic initiatives and ~~2019 strategic initiatives,~~reduction in general and administrative expense, QEP has incurred ~~or expects to incur additional~~ costs associated with contractual termination benefits, including severance, accelerated vesting of share-based compensation and other expenses. Refer to Note 3 – Acquisitions and Divestitures and Note 9 – Restructuring in Part 1, Item I of this Quarterly Report on Form 10-Q for more information.

~~Acquisitions~~The Company continues to focus on reducing its operating costs, per well drilling costs, general and ~~Divestitures~~

~~While we~~administrative costs and managing its liquidity. We believe our ~~inventory of identified drilling locations provides a solid base for growth in production~~plan to generate Free Cash Flow (FCF) on an annual basis will allow us to further strengthen our balance sheet and ~~reserves, we will~~ continue returning capital to ~~evaluate~~shareholders.

Financial and ~~acquire properties in our operating areas to add additional development opportunities and facilitate the drilling of long lateral wells.~~Operating Highlights

~~Acquisitions~~

During the three months ended March 31, 2019, QEP acquired various oil and gas properties, which primarily included proved acreage in the Permian Basin for an aggregate purchase price of $0.6 million, subject to post-closing purchase price adjustments.

During the three months ended March 31, 2018, QEP acquired various oil and gas properties, which primarily included proved and unproved leasehold acreage in the Permian Basin for an aggregate purchase price of $36.2 million, subject to post-closing purchase price adjustments. Of the $36.2 million, $35.7 million was related to acquisitions from various entities that owned additional oil and gas interests in certain properties included in the 2017 acquisition of oil and gas properties in the Permian Basin (2017 Permian Basin Acquisition) on substantially the same terms and conditions as the 2017 Permian Basin Acquisition in the fourth quarter of 2017.

~~Divestitures~~

In January 2019, QEP closed its previously announced Haynesville Divestiture for net cash proceeds of $615.3 million, subject to post-closing purchase price adjustments, and recorded a pre-tax loss on sale of $18.0 million. Of the $18.0 million pre-tax loss on sale, $15.0 million was recognized during the three months ended March 31, 2019, and $3.0 million was recognized during the fourth quarter of 2018 within "Net gain (loss) from asset sales, inclusive of restructuring costs" on the Condensed Consolidated Statements of Operations. Included in the $15.0 million pre-tax loss on sale is $1.4 million of restructuring costs related to the Haynesville Divestiture during the three months ended March 31, 2019. Refer to Note 9 – Restructuring for more information. As of March 31, 2019, $22.1 million remained in escrow due to title defects asserted prior to closing, to be resolved pursuant to the purchase and sale agreement's title dispute resolution procedures, of which $5.8 million was included in "Accounts receivable, net" on the Condensed Consolidated Balance Sheets. As of December 31, 2018, the Haynesville/Cotton Valley assets were classified in the Company's Condensed Consolidated Financial Statements as held for sale. Refer to Note 3 – Acquisitions and Divestitures in Part 1, Item I of this Quarterly Report on Form 10-Q for more information.

In addition to the Haynesville Divestiture, during the three months ended March 31, 2019, QEP received net cash proceeds of $2.1 million and recorded a net pre-tax loss on sale of $0.4 million related to the divestiture of properties outside our main operating areas.

During the three months ended March 31, 2018, QEP received net cash proceeds of $33.3 million and recorded a pre-tax gain on sale of $3.5 million, primarily related to the divestiture of properties outside our main operating areas in the Williston Basin, Pinedale and Other Northern areas.

~~Financial and Operating Highlights~~

~~During the three months ended March 31, 2019,~~2020, QEP:

~~Closed the Haynesville Divestiture, for net cash proceeds of $615.3 million;~~

~~Delivered oil and condensate production of 5.1 MMbbls, a 2% increase over the first quarter 2018 volumes;~~

~~Increased oil and condensate production in the Permian Basin by 35% to 2.9 MMbbls over the first quarter 2018;~~

~~Reported net realized oil price of $48.50 per bbl, a 6% decrease from the first quarter 2018;~~

Generated a net ~~loss~~income of ~~$116.7~~$367.4 million, or ~~$0.49~~$1.54 per diluted share; ~~and~~

Reported Adjusted EBITDA (a non-GAAP financial measure defined and reconciled below) of ~~$119.8 million.~~$173.9 million;

Reported cash provided by operating activities of $151.9 million;

~~Outlook~~Reported Free Cash Flow (a non-GAAP measure defined and reconciled below) outspend of $31.6 million;

Lowered lease operating expense by 22% compared to the first quarter of 2019;

~~The Company continues~~Reduced general and administrative expenses by 75% compared to ~~focus~~the first quarter 2019;

Recognized an additional $128.1 million in accelerated alternative minimum tax (AMT) credit refunds from the CARES Act, resulting in an aggregate income tax receivable of $165.6 million as of March 31, 2020;

Repurchased a principal amount of $98.2 million of senior notes, which were due in 2021, 2022 and 2023, and recorded a $25.2 million gain on ~~reducing its operating costs~~early extinguishment of debt; and ~~per well drilling costs and managing its liquidity. We believe our balance sheet and sufficient liquidity will allow us to grow~~

Reported oil and condensate production of 3.3 MMbbls in the Permian Basin, an increase of 14% compared to the first quarter 2019;

Outlook

The novel coronavirus disease (COVID-19) has created unprecedented challenges for our ~~operating areas~~industry, customers and ~~achieve~~employees. The Company is taking decisive action to protect the core of its business and to ensure the health and safety of our ~~strategic initiatives.~~employees, business partners and communities until this crisis passes. The Company instituted various measures, including remote working and business travel restrictions, starting in March 2020, and we remain engaged with our business and community partners on how we can assist them during this time. The Company is taking additional safeguards and has implemented new procedures

and policies to help protect the health and safety of the portion of the workforce whose jobs cannot be completed from home, including those who run our field operations. We continue to monitor the guidelines and recommendations provided by the relevant authorities, and we will continue to make the difficult decisions to ensure we are doing our part in preventing the spread of the virus.

As a result of lower demand caused by the COVID-19 pandemic and oversupply of crude oil, the future prices of crude oil are at or near historic lows. In light of current market conditions, the Company has taken significant steps to proactively manage its cash flow and preserve liquidity by suspending completion operations and releasing two drilling rigs in the Permian Basin as well as suspending the refracturing program in the Williston Basin upon the completion of current projects. These actions have reduced the Company's capital spending forecast for 2020 by 32% compared to our original guidance. While these decisions are expected to result in lower 2020 oil production than originally forecasted, the Company believes that it will be able to maintain positive cash flow and protect its balance sheet, with the ultimate goal of protecting shareholder returns over the long term. Although the Company has already reduced activity dramatically, we are prepared to reduce it further for an extended period if necessary. The Company will utilize this slowdown to improve on its best in class operations and to continue to reduce expenses to the lowest and most efficient cost structure possible.

Due to the Company’s derivative positions and reduction in capital expenditures, the Company expects to generate significant FCF in 2020 despite the current market conditions. In addition to generating FCF, due to changes enacted by the CARES Act, the Company anticipates receiving alternative minimum tax (AMT) credit refunds of $165.6 million in the next 12 months. The Company believes that the cash on hand, generation of FCF and anticipated AMT credit refunds positions the Company to meet its liquidity needs for the next twelve 12 months, including its debt maturity in March 2021.

The Company believes that the overall reduction of global spending on new development projects, especially in the U.S., will cause a reduction in the global oil supply, and that the eventual recovery from the COVID-19 pandemic will cause demand to be more in line with previously anticipated levels and, consequently, cause oil prices to recover. As a result of the actions taken, and continuing to be taken, and the expected stabilization of the global economy, the Company expects to emerge in a stronger position.

Based on current commodity prices, we expect to be able to fund our planned capital program for ~~2019~~2020 with cash on hand and cash flow from operating ~~activities, cash on hand and borrowings under our credit facility.~~activities. Our total capital expenditures (excluding property acquisitions) for ~~2019~~2020 are expected to be approximately ~~$640.0~~$385.0 million, a decrease of ~~approximately 46%~~over 30% from ~~2018~~both our 2019 capital ~~expenditures.~~expenditures and our original 2020 guidance. We continuously evaluate our level of drilling and completion activity in light of commodity prices, drilling results ~~commodity prices~~ and changes in our operating and development costs and will adjust our capital investment program based on such evaluations. See "Cash Flow from Investing Activities" for further discussion of our capital expenditures.

Factors Affecting Results of Operations

~~Shareholder Activism~~

Elliott Management Corporation (Elliott), is a beneficial holder of approximately 4.9% of our common stock (based on Elliott's Form 13F-HR filed on February 14, 2019). On January 7, 2019, Elliott made a proposal to our Board to acquire all of our outstanding shares of common stock for $8.75 per share in cash. Our Board made a decision to engage in a process to explore strategic alternatives, which could result in a merger or sale of the Company or another transaction involving the Company's assets. Our business and/or operations could be adversely affected by these and any future actions of activist shareholders. Responding to actions by activist shareholders could be costly and time-consuming, disrupting our operations and diverting the attention of our management and employees. Activities of activist shareholders could interfere with our ability to execute our strategic plan or realize short- or long-term value from our assets and could interfere with our ability to pursue strategic alternatives to Elliott's proposal. Perceived uncertainties as to our future direction could also result in the loss of potential business opportunities, make it more difficult or costly to attract and retain qualified personnel and affect the trading price of our securities.

Supply, Demand, Market Risk and their Impact on Oil Prices

~~Oil~~In the first quarter of 2020 the average price of WTI crude oil dropped 65.9% from the first quarter of 2019. Crude oil prices ~~are affected~~were negatively impacted by ~~many~~a variety of factors ~~outside of our control, including changes in~~affecting current and expected supply and demand dynamics, including: the COVID-19 pandemic and related shut-down of various sectors of the global economy which ~~are impacted~~has resulted in a significant reduction in demand for crude oil, continued U.S. supply growth driven by advances in drilling and completion technologies, and the delay of an agreement on production levels by members of the Organization of Petroleum Exporting Countries (OPEC) and other oil producing countries, including Russia, resulting in increased supply in the global market. Other factors impacting supply and demand include weather conditions, pipeline capacity constraints, inventory storage levels, basis differentials, export capacity, strength of the U.S. dollar as well as other factors, the majority of which are outside of our control. While OPEC and other ~~factors. In recent years,~~oil producing countries reached an agreement in April 2020 with respect to production levels, it is not expected to have an immediate impact on crude oil prices ~~have been affected~~until global supply matches current lower levels of demand caused by ~~supply growth, particularly in~~ the ~~U.S., driven by advances in drilling and completion technologies, and fluctuations in demand driven by a variety of factors.~~factors mentioned above, including the COVID-19 pandemic.

Changes in the market prices for oil directly impact many aspects of QEP's business, including its financial condition, revenues, results of operations, planned drilling and completion activity and related capital expenditures, its ~~proved undeveloped (PUD)~~PUD reserves conversion rate, liquidity, rate of growth, costs of goods and services required to drill, complete and operate wells, and the carrying value of its oil and gas properties. ~~Historically, field-level prices received for QEP's oil production have been volatile. During~~The decline in the ~~past five years, the posted~~ price ~~for WTI~~of crude oil negatively impacted our oil revenue during the first quarter of 2020 but the value of our oil derivatives portfolio increased significantly. Additionally, the volatility in commodity prices has ~~ranged from~~impacted the Company’s stock price and the fair value of the Company's debt securities, all of which impact our financial and operating results. Due to the changes in our drilling plans, we expect that our 2020 proved undeveloped (PUD) conversion rate will be lower than originally anticipated. In addition, a prolonged low ~~of $26.19 per barrel in February 2016 to a high of $107.95 per barrel in June 2014.~~price environment may impact our future drilling plans and decrease our total PUD reserves. If oil prices ~~decline to early 2016~~remain consistent with March 2020 levels for an extended period of time, or

decline further, our operations, financial condition and level of expenditures for the development of our oil reserves may be materially and adversely affected.

QEP's producing properties are primarily located in the Permian and Williston basins. As a result of our lack of diversification

in asset type and limited geographic diversification, any delays or interruptions of production caused by factors such as

governmental regulation, transportation capacity constraints, curtailment of production or interruption of transportation, price

fluctuations, natural disasters or shutdowns of the pipelines connecting our production to refineries would have a significantly

greater impact on our results of operations than if we possessed more diverse assets and locations.

Global Geopolitical and Macroeconomic Factors

QEP continues to monitor the global economy, including ~~Europe and China's~~global economic ~~outlook; the Organization of Petroleum Exporting Countries (OPEC)~~issues such as COVID-19; political unrest; oil producing countries' oil production and policies regarding production quotas; ~~political unrest and global economic issues; slowing growth in certain emerging market economies;~~ actions taken by the United States Congress and the ~~president~~President of the United States; the U.S. federal budget deficit; changes in regulatory oversight policy; the impact of regulations and public and financial market sentiment regarding climate change; commodity price volatility; tariffs on goods we use in our operations or on the products we sell; the impact of a potential increase in interest rates; volatility in various global currencies; and other factors. A dramatic decline in regional or global economic conditions, a major recession or depression, regional political instability, economic sanctions, war, or other factors beyond the control of QEP have had, and could continue to have, a significant impact on short-term and long-term oil and condensate, gas and NGL supply, demand and prices and the Company's ability to continue its planned drilling programs ~~and~~which could materially impact the Company's financial position, results of operations and cash flow from operations. Disruption to the global oil supply system, political and/or economic instability, fluctuations in currency values, and/or other factors could trigger additional volatility in oil prices.

Due to continued global economic uncertainty and the corresponding volatility of commodity prices, QEP continues to focus on maintaining a sufficient liquidity position to ensure financial flexibility. QEP uses commodity derivatives to reduce the volatility of the prices QEP receives for a portion of its production and to partially protect cash flow and returns on invested capital from a drop in commodity prices. Generally, QEP intends to enter into commodity derivative contracts for approximately 50% to 75% of its forecasted annual production by the end of the first quarter of each fiscal year. ~~At March 31, 2019, QEP~~Gains on settled derivatives offset a large portion of the impact of the recent decline in oil prices on our oil revenues. There can be no assurances that we will be able to add derivative positions to cover the balance of our forecasted ~~its 2019 annual~~ production ~~to be approximately 29.4 MMboe (mid-point of guidance)~~for 2020 and ~~had approximately 64% of its forecasted oil and condensate production covered with fixed price swaps.~~2021 at favorable prices. See Part 1, Item 3 – "Quantitative and Qualitative Disclosures about Market Risk-Commodity Price Risk Management" for further details on QEP's commodity derivatives transactions.

Potential for Future Asset Impairments

The carrying values of the Company's properties are sensitive to declines in oil, gas and NGL prices as well as increases in various development and operating costs and expenses and, therefore, are at risk of impairment. The Company uses a cash flow model to assess its proved oil and gas properties and operating lease right-of-use assets for impairment. The cash flow model includes numerous assumptions, including estimates of future oil and condensate, gas and NGL production, estimates of future prices for production that are based on the price forecast that management uses to make investment decisions, including estimates of basis differentials, future operating costs, transportation expenses, production taxes, and development costs that management believes are consistent with its price forecast, and discount rates. Management also considers a number of other factors, including the forward curve for future oil and gas prices, and developments in regional transportation infrastructure when developing its estimate of future prices for production. All inputs for the cash flow model are evaluated at each date of estimate.

We base our ~~fair value~~ estimates on projected financial information that we believe to be reasonably likely to occur. An assessment of the sensitivity of our capitalized costs to changes in the assumptions in our cash flow calculations is not practicable, given the numerous assumptions (e.g., future oil, gas and NGL prices; production and reserves; pace and timing of development drilling plans; timing of capital expenditures; operating costs; drilling and development costs; and inflation and discount rates) that can materially affect our estimates. Unfavorable adjustments to some of the above listed assumptions would likely be offset by favorable adjustments in other assumptions. For example, the impact of sustained reduced oil, gas and NGL prices on future undiscounted cash flows would likely be offset by lower drilling and development costs and lower operating costs. The signing of a purchase and sale agreement could also cause the Company to recognize an impairment of proved properties. For assets subject to a purchase and sale agreement, the terms of the purchase and sale agreement are used as an indicator of fair value.

During the three months ended March 31, ~~2019, there was~~2020, the Company recorded no impairment ~~related to proved and unproved oil and gas properties.~~charges. During the three months ended March 31, 2019, ~~the Company~~QEP recorded impairment charges of $5.0 million related to an office building lease.

During the three months ended March 31, 2018, QEP recorded an impairment charge of $0.7 million, which was primarily related to the impairment of proved properties related to a divestiture in the Other Northern area and expiring leaseholds on unproved properties.

We could be at risk for proved and unproved property and operating lease right-of-use asset impairments if ~~forward oil prices decline from March 31, 2019 levels,~~current market conditions persist for an extended period of time, we experience negative changes in estimated reserve quantities or the

forward oil prices decline from ~~our strategic initiative results.~~March 31, 2020 levels. The actual amount of impairment incurred, if any, for ~~these~~oil and gas properties will depend on a variety of factors including, but not limited ~~to,~~to: subsequent forward price curve changes, the additional risk-adjusted value of probable and possible reserves associated with ~~the~~our properties, weighted-average cost of capital, operating cost estimates and future capital expenditure estimates.

Income Tax ~~Legislation~~

The ~~Tax Legislation~~tax legislation enacted in December 2017 reduced our federal corporate tax rate from 35% to 21%. In addition, the ~~Tax Legislation~~tax legislation eliminated the corporate Alternative Minimum Tax (AMT) ~~and QEP has~~, allowing the ~~ability~~Company to ~~offset its regular tax liability or~~ claim AMT refunds ~~for taxable years 2018 through 2021~~ for AMT credits carried forward from prior tax years. The Company ~~currently~~received $73.9 million of AMT credit refunds in 2019. The CARES Act enacted in March 2020 permitted the Company to carry back its net operating loss (NOL) generated in 2018, creating additional AMT credits, and accelerate all of its AMT credit refunds into 2020. The Company now anticipates it will ~~realize approximately $148.4~~receive $165.6 million inof AMT credit refunds, ~~over~~after carry backs in the next ~~four years with $74.2 million to be realized in 2019 for tax year 2018, which is~~12 months. The AMT credits refunds are included in "Income tax receivable" ~~with the remaining $74.2 million included in "Deferred income taxes"~~ on the ~~Condensed Consolidated Balance Sheet~~balance sheets as of March 31, ~~2019.~~2020.

Acquisitions and Divestitures

QEP's strategy is to generate Free Cash Flow (FCF) (a non-GAAP financial measure defined and reconciled below), and it believes its inventory of identified drilling locations provides a solid base to achieve this strategy, but it will continue to evaluate and potentially acquire properties in its operating areas to add additional development opportunities and facilitate the drilling of long lateral wells.

Acquisitions

During the three months ended March 31, 2020 and 2019, QEP acquired various oil and gas properties, which primarily included proved acreage in the Permian Basin for an aggregate purchase price of $3.0 million and $0.6 million, respectively, subject to post-closing purchase price adjustments.

Divestitures

During the three months ended March 31, 2020, QEP received net cash proceeds of $12.6 million and recorded a net pre-tax gain on sale of $3.7 million, primarily related to the divestiture of properties outside its main operating areas.

In January 2019, QEP sold its Haynesville/Cotton Valley assets (Haynesville Divestiture) and during the year ended December 31, 2019, reached final settlement on asserted environmental and title defects and received aggregate net cash proceeds of $633.9 million. QEP recorded a net pre-tax loss, including restructuring costs, of $4.0 million, of which $15.0 million of the pre-tax loss on sale was recognized during the three months ended March 31, 2019, and was recorded within "Net gain (loss) from asset sales, inclusive of restructuring costs" on the statements of operations. Refer to Note 3 – Acquisitions and Divestitures in Part 1, Item I of this Quarterly Report on Form 10-Q for more information. In addition to the Haynesville Divestiture, during the three months ended March 31, 2019, QEP recorded net cash proceeds of $2.1 million and recorded a net pre-tax loss on sale of $0.4 million related to the divestiture of properties outside our main operating areas.

Multi-Well Pad Drilling and Completion

To reduce the costs of well location construction and rig mobilization and demobilization and to obtain other efficiencies, QEP utilizes multi-well pad drilling, where practical. For example, in the Permian Basin, QEP utilizes "tank-style" development, in which we simultaneously develop multiple subsurface targets by drilling and completing all wells in a given "tank" before any individual well is turned to production. We believe this approach maximizes the economic recovery of oil and condensate through the simultaneous development of multiple subsurface targets, while improving capital efficiency though shared surface facilities, which we believe will reduce per-unit operating costs and result in expanded operating margins and improve our returns on invested capital. ~~In certain of our producing areas,~~Because wells drilled on a pad are not completed and brought into production until all wells on the pad are drilled and the drilling rig is moved from the ~~location. As a result,~~location, multi-well pad drilling delays the completion of wells, ~~and~~ the commencement of ~~production.~~production from new wells, and may negatively affect production from existing offset wells. In addition, existing wells that offset new wells being completed by QEP or offset operators may need to be temporarily shut-in during the completion process. Such delays and well shut-ins have caused and may continue to cause volatility in QEP's quarterly operating results. In addition, delays in completion of wells may impact the timing of planned ~~conversion~~conversions of PUD reserves to proved developed reserves.

Uncertainties Related to Claims

QEP is currently subject to claims that could adversely impact QEP's liquidity, operating results and capital expenditures for a particular reporting period, including, but not limited to those described in Note 11 – Commitments and Contingencies, in Item 1 of Part I of this Quarterly Report on Form 10-Q. Given the uncertainties involved in these matters, QEP is unable to predict the ultimate outcomes.

Critical Accounting Estimates

QEP's significant accounting policies are described in Item 7 of Part II of its ~~2018~~2019 Form 10-K. The Company's ~~Condensed Consolidated Financial Statements~~financial statements are prepared in accordance with GAAP. The preparation of the Company's ~~Condensed Consolidated Financial Statements~~financial statements requires management to make assumptions and estimates that affect the reported results of operations and financial position. QEP's accounting policies on oil and gas reserves, successful efforts accounting for oil and gas operations, impairment of long-lived assets ~~asset retirement obligations, revenue recognition, litigation~~ and ~~other contingencies, derivative contracts, pension and other postretirement benefits, share-based compensation,~~ income taxes, ~~and purchase price allocations,~~ among others, may involve a high degree of complexity and judgment on the part of management. Further, these estimates and other factors, including those outside of the Company’s control, such as the impact of sustained lower commodity prices, could have a significant adverse impact to the Company’s financial condition, results of operations and cash flows.

Drilling, Completion and Production Activities

The following table presents operated and non-operated wells in the process of being drilled or waiting on completion as of March 31, ~~2019:~~2020:


		Operated				Non-operated					Operated				Non-operated
	Drilling	Drilling		Waiting on completion		Drilling		Waiting on completion		Drilling	Drilling		Waiting on completion		Drilling		Waiting on completion
	Rigs	Gross	Net	Gross	Net	Gross	Net	Gross	Net	Rigs	Gross	Net	Gross	Net	Gross	Net	Gross	Net
Northern Region
Williston Basin⁽¹⁾	1	7	6.4	—	—	1	0.0	11	0.9	1	6	4.3	—	—	5	1.9	16	1.7
Other Northern	—	—	—	—	—	—	—	—	—
Southern Region
Permian Basin⁽²⁾	3	11	11.0	46	46.0	—	—	5	0.4	3	18	18.0	36	34.5	—	—	—	—
Other Southern	—	—	—	—	—	—	—	—	—

____________________________


⁽¹⁾	~~All 7~~Five of the six gross operated ~~drilling~~ wells in the Williston Basin represent wells infor which surface casing ~~has~~had been set as of March 31, ~~2019.~~2020.

⁽²⁾

~~The number~~One of the three rigs in the Permian Basin was an intermediate drilling rig, and fifteen of the 18 gross operated ~~drilling~~ wells in the Permian Basin ~~includes 9~~represent wells for which ~~surface~~intermediate casing ~~has~~had been set as of March 31, ~~2019.~~2020. Subsequent to March 31, 2020, due to the current market conditions, the Company released two of the three rigs.

~~Each gross well completed in more than one producing zone is counted as a single well.~~ Delays and well shut-ins resulting from multi-well pad drilling have caused and may continue to cause volatility in QEP's quarterly operating results. In addition, delays in completion of wells could impact planned ~~conversion~~conversions of PUD reserves to proved developed reserves. QEP had 4636 gross operated wells waiting on completion as of March 31, ~~2019.~~2020.

The following table presents the number of operated wells in the process of being drilled or waiting on completion at March 31, 2020 and operated wells completed and turned to sales (put on production) for the three months ended March 31, 2020:



	Permian Basin		Williston Basin
	As of March 31, 2020
	Gross	Net	Gross	Net
Well Progress
Drilling	18	18.0	6	4.3

At total depth - under drilling rig	—	—	—	—
Waiting to be completed	25	25.0	—	—
Completed, awaiting production	11	9.5	—	—
Waiting on completion	36	34.5	—	—

Put on production	25	24.9	—	—

The following table presents the number of operated and non-operated wells completed and turned to sales (put on production) for the three months ended March 31, ~~2019:~~2020:



	Operated Put on Production		Non-operated Put on Production
	Three Months Ended		Three Months Ended
	March 31, 2020		March 31, 2020
	Gross	Net	Gross	Net ⁽¹⁾
Northern Region
Williston Basin	—	—	5	—
Southern Region
Permian Basin	25	24.9	—	—

Operated Put on Production Non-operated Put on Production
Gross Net Gross Net
Northern Region
Williston Basin —
—
—
—
Other Northern —
—
—
—
Southern Region
Permian Basin 12
12.0
—
—
Other Southern —
—
—
—
_______________________

~~The following table presents~~⁽¹⁾Net working interest related to the ~~number of operated~~5 gross non-operated wells in the ~~process of being drilled or waiting on completion at March 31, 2019 and operated wells completed and turned to sales (put on production)~~Williston Basin is immaterial as QEP's working interest is less than 0.1% for the three months ended March 31, ~~2019:~~2020.

Permian Basin Williston Basin
As of March 31, 2019
Gross Net Gross Net
Well Progress
Drilling 11
11.0
7
6.4

At total depth - under drilling rig 3
3.0
—
—
Waiting to be completed 28
28.0
—
—
Undergoing completion 4
4.0
—
—
Completed, awaiting production 11
11.0
—
—
Waiting on completion 46
46.0
—
—

Put on production 12
12.0
—
—

RESULTS OF OPERATIONS

Net Income

QEP generated a net ~~loss~~income during the first quarter of ~~2019~~2020 of ~~$116.7~~$367.4 million or ~~$0.49~~$1.54 per diluted share, compared to a net loss of ~~$53.6~~$116.7 million or ~~$0.22~~$0.49 per diluted share, in the first quarter of ~~2018. QEP's~~2019. The $484.1 million increase in net income in the first quarter of 2020 compared to 2019 ~~net loss~~ was primarily ~~driven by a $134.2 million decrease in oil and condensate, gas and NGL sales~~ due to ~~a 74% decrease in gas production due to the Haynesville/Cotton Valley and Uinta Basin divestitures and a 19% decrease in average field-level oil prices, and a $128.5~~$631.6 million increase in realized and unrealized derivative ~~losses. These changes were~~gains, partially offset by ~~a $98.1~~an $178.3 million increase in income tax ~~benefit, a decrease in depreciation, depletion, and amortization expense~~expense.

See below for additional discussion regarding the components of ~~$73.2 million, and a decrease in both transportation and processing costs and lease operating expense~~net income (loss) for each of ~~$44.1 million due to~~ the ~~Haynesville/Cotton Valley and Uinta Basin divestitures.~~periods presented.

Adjusted EBITDA (Non-GAAP)

Management defines Adjusted EBITDA (a non-GAAP measure) as earnings before interest, income taxes, depreciation,

depletion and amortization (EBITDA), adjusted to exclude changes in fair value of derivative contracts, exploration expenses,

gains and losses from asset sales, impairment, gains or losses from early extinguishment of debt and certain other items. Management uses Adjusted EBITDA to evaluate QEP's financial performance and trends, make operating decisions and allocate resources. Management believes the measure is useful supplemental information for investors because it eliminates the impact of certain nonrecurring, non-cash and/or other items that management does not consider as indicative of QEP's performance from period to period. QEP's Adjusted EBITDA may be determined or calculated differently than similarly titled measures of other companies in our industry, which ~~would~~could reduce the usefulness of this non-GAAP financial measure when comparing our performance to that of other companies.

Below is a reconciliation of net income (loss) (the most comparable GAAP measure) to Adjusted EBITDA. This non-GAAP measure should be considered by the reader in addition to, but not instead of, the financial statements prepared in accordance with GAAP.


	Three Months Ended March 31,							Three Months Ended March 31,
	2019			2018				2020			2019
	(in millions)						(in millions)
Net income (loss)	$	(116.7	)	$	(53.6	)		$	367.4		$	(116.7	)
Interest expense	34.0			35.0				31.6			34.0
Interest and other (income) expense	(2.8		)	0.7				2.6			(2.8		)
Income tax provision (benefit)	(112.0		)	(13.9		)		66.3			(112.0		)
Depreciation, depletion and amortization	123.3			196.5				142.2			123.3
Unrealized (gains) losses on derivative contracts	175.8			10.0				(407.3		)	175.8
Gain from early extinguishment of debt								(25.2		)	—
Net (gain) loss from asset sales, inclusive of restructuring costs	13.2			(3.5		)		(3.7		)	13.2
Impairment	5.0			0.7				—			5.0
Adjusted EBITDA	$	119.8		$	171.9			$	173.9		$	119.8

Forward-Looking Statements

The quarterly report contains information that includes or is based upon "forward-looking statements" within the meaning of Section 27A of the Securities Act of 1933, as amended (the Securities Act), and Section 21E of the Securities Exchange Act of 1934, as amended. Forward-looking statements give expectations or forecasts of future events. You can identify these statements by the fact that they do not relate strictly to historical or current facts. We use words such as "anticipate," "estimate," "expect," "project," "intend," "plan," "believe," and other words and terms of similar meaning in connection with a discussion of future operating or financial performance. Forward-looking statements include statements relating to, among other things:

our strategic ~~initiatives to maximize shareholder value, including through a merger or sale of the Company or other transaction involving the Company's assets;~~objectives;

plans to reduce general and administrative ~~expense~~expenses significantly;

~~timing of the implementation of organizational changes;~~

~~expected~~restructuring costs associated with contractual termination benefits, including ~~severance and~~ accelerated ~~vesting~~vestings of share-based ~~compensations, as part~~compensation;

expectation to generate free cash flow and focus on capital efficiency;

effect of the ~~strategic initiatives;~~COVID-19 pandemic on our business results;

~~resolution~~expectation of ~~asserted title defects~~proved undeveloped (PUD) reserve conversion rate and total PUD reserves;

the coverage and amounts of insurance are consistent with ~~respect to the Haynesville divestiture;~~

~~reducing operating and per well drilling costs and managing liquidity;~~

~~plans to grow oil and condensate production;~~industry practice;

drilling and completion plans and strategies;

adding additional acreage in our operating areas;

adequacy of procedures implemented to protect against credit-related losses;

expectations and assumptions regarding oil, gas and NGL ~~prices, including volatility and effects on our business;~~prices;

our ability to meet delivery and sales commitments;

~~impact~~volatility of ~~potential activist shareholders to our operations, personnel retention, strategies~~oil, gas and ~~costs;~~NGL prices and factors impacting such prices;

beliefs about the reduction of global spending on new oil and gas projects and a corresponding reduction in the global oil supply;

the ~~unfunded status~~effects of oil, gas and NGL prices on our ~~pension plan;~~business;

~~estimates of future liability for deficiency charges~~factors impacting our ability to transport oil and condensate and gas;

credit agreement limitations that could prevent QEP from incurring certain indebtedness, which could limit QEP's ability to engage in ~~connection with the divestiture of our assets in Pinedale;~~acquisitions;

the conditions impacting the timing and amount of share repurchases under our share repurchase program;

incurring penalties related to air emission noncompliance and capital expenditures to maintain or obtain operating permits and approvals;

the underfunded status of our pension plan;

the adjustments made to GAAP ~~measures~~Measures to arrive at non-GAAP measures and the usefulness of non-GAAP financial measures;

~~solid base for growth in production and reserves provided by~~ our inventory of drilling ~~locations;~~locations and the ability of that inventory to provide a solid base for generating free cash flow and capital efficiency;

evaluation of potential acquisitions, divestitures and joint venture opportunities;

our balance sheet and sufficient liquidity providing for the ability to ~~grow oil~~meet future financial obligations, ensure financial flexibility, withstand commodity price volatility and ~~condensate production~~fund its development projects, operations and ~~achieve~~ capital expenditures and return capital to shareholders;

our ~~strategic initiatives;~~ability to fund maturities of senior notes;

future availability under our revolving credit facility or continued compliance with restrictive financial covenants;

adjustments to our capital investment program based on a variety of ~~factors;~~factors, including an evaluation of drilling and completion activities and drilling results;

focus and reduction on operating costs and per well drilling costs;

amount and allocation of forecasted capital expenditures (excluding property acquisitions) and, plans and sources for funding operations and capital investments;

impact of lower or higher commodity prices and interest rates;

potential for asset impairments and factors impacting impairment amounts;

fair value estimates and related assumptions and assessment of the sensitivity of changes in assumptions, and critical accounting estimates, including estimated asset retirement obligations;

~~critical accounting estimates, including assets retirement obligations;~~

impact of global geopolitical and macroeconomic events and the monitoring of such events;

plans regarding derivative contracts, including the volumes utilized, and the anticipated benefits derived there from;

outcome and impact of various claims;

expected cost savings and other efficiencies from multi-well pad drilling, including "tank-style" development;

delays in completion of wells, well shut-ins and volatility to operating results caused by multi-well pad ~~drilling, including the effect~~drilling;

value of ~~such delays on quarterly operating results~~pension plan assets and ~~planned conversion of PUD reserves;~~our plans regarding additional contributions to our Pension Plan, nonqualified retirement plan (SERP), Medical Plan;

maintaining a sufficient liquidity position to ensure financial flexibility, withstand commodity price volatility, and fund our development projects, operations, capital expenditures and strategic initiatives;

estimates of the amount of additional indebtedness we may incur under our revolving credit facility;

~~factors impacting ability to incur additional indebtedness;~~

off-balance sheet arrangements;

redemption of senior notes;

factors impacting our ability to borrow and the interest rates offered;

unrecognized tax benefits and the realization of those benefits;

assumptions regarding share-based compensation;

settlement of performance share units and restricted share units in cash;

~~AMT credits amount and timing;~~ and

~~our plans regarding contributions to the nonqualified retirement plan (SERP), medical plan~~alternative minimum tax credit refund amounts and ~~401(k) plan.~~timing.

Any or all forward-looking statements may turn out to be incorrect. They can be affected by inaccurate assumptions or by known or unknown risks and uncertainties. Many such factors will be important in determining actual future results. These statements are based on current expectations and the current economic environment. They involve a number of risks and uncertainties that are difficult to predict. These statements are not guarantees of future performance. Actual results could differ materially from those expressed or implied in the forward-looking statements. Factors that could cause actual results to differ materially include, but are not limited to the following:

the risk factors discussed in Item 1A of Part I of the ~~2018~~2019 Form 10-K and Item 1A of Part II of this Quarterly Report on Form 10-Q;

~~any potential impact from the announcement that the Board of Directors of the Company is conducting a review of strategic alternatives;~~

changes in oil, gas and NGL prices;

global geopolitical and macroeconomic factors;

general economic conditions, including the performance of financial markets and interest rates;

the length and severity of a pandemic or other health crisis, such as the recent outbreak of COVID-19 and the measures that international, federal, state and local governments, agencies, law enforcement and/or health authorities implement to address it, which may (as with COVID-19) precipitate or exacerbate one or more of the factors herein, reduce the demand for oil, gas and NGLs and significantly disrupt or prevent us from operating our business in the ordinary course for an extended period;

the risks and liabilities associated with acquired assets;

asset impairments;

liquidity constraints, including those resulting from the cost and availability of debt and equity financing;

drilling and completion strategies, methods and results;

assumptions around well density/spacing and recoverable reserves per well prove to be inaccurate;

changes in estimated reserve quantities;

changes in management's assessments as to where QEP's capital can be most profitably deployed;

shortages and costs of oilfield equipment, services and personnel;

changes in development plans;

lack of available pipeline, processing and refining capacity;

processing volumes and pipeline throughput;

risks associated with hydraulic fracturing;

the outcome of contingencies such as legal proceedings;

delays in obtaining permits and governmental approvals;

operating risks such as unexpected drilling conditions and risks inherent in the production of oil and gas;

weather conditions;

changes in, adoption of and compliance with laws and regulations, including decisions and policies concerning: the environment, climate change, greenhouse gas or other emissions, renewable energy mandates, natural resources, fish and wildlife, hydraulic fracturing, water use and drilling and completion techniques, as well as the risk of legal proceedings arising from such matters, whether involving public or private claimants or regulatory investigative or enforcement measures;

derivative activities;

potential losses or earnings reductions from our commodity price risk management programs;

volatility in the commodity-futures market;

failure of internal controls and procedures;

failure of our information technology infrastructure or applications to prevent a cyberattack;

elimination of federal income tax deductions for oil and gas exploration and development costs;

production, severance and property taxation rates;

~~the amount of AMT credit refunds realized;~~

~~tariffs on products we use in our operations on products we sell;~~

discount rates;

regulatory approvals and compliance with contractual obligations;

actions of, or inaction by federal, state, local or tribal governments, foreign countries and the Organization of Petroleum Exporting Countries;

lack of, or disruptions in, adequate and reliable transportation for our production;

competitive conditions;

production and sales volumes;

actions of operators on properties in which we own an interest but do not operate;

estimates of oil and gas reserve quantities;

reservoir performance;

operating costs;

inflation;

capital costs;

creditworthiness and performance of the Company's counterparties, including financial institutions, operating partners and other parties;

volatility in the securities, capital and credit markets;

actions by credit rating agencies and their impact on the Company;

changes in guidance issued related to tax reform legislation;

~~actions of activist shareholders;~~ and

other factors, most of which are beyond the Company's control.

QEP undertakes no obligation to publicly correct or update the forward-looking statements in this Quarterly Report on

Form 10-Q, in other documents, or on the Company's website to reflect future events or circumstances. All such statements are expressly qualified by this cautionary statement.

ITEM 4. CONTROLS AND PROCEDURES

Evaluation of Disclosure Controls and Procedures

The Company's Chief Executive Officer and Chief Financial Officer have evaluated the effectiveness of the design and operation of the Company's disclosure controls and procedures (as such term is defined in Rules 13a-15(e) and 15d-15(b) under the Securities Exchange Act of 1934, as amended), as of March 31, ~~2019.~~2020. Based on such evaluation, such officers have concluded that, as of March 31, ~~2019,~~2020, the Company's disclosure controls and procedures are designed and effective to ensure that information required to be included in the Company's reports filed or submitted under the Exchange Act is recorded, processed, summarized and reported within the time periods specified by the Securities and Exchange Commission's rules and forms and that information required to be disclosed in the Company's reports filed or submitted under the Exchange Act is accumulated and communicated to the Company's management including its principal executive officer and principal financial officer, or persons performing similar functions, as appropriate, to allow timely decisions regarding required disclosure.

In designing and evaluating the Company's disclosure controls and procedures, management recognizes that any controls and procedures, no matter how well designed and operated, can provide only reasonable, and not absolute, assurance that the objectives of the control system will be met. In addition, the design of any control system is based in part upon certain assumptions about the likelihood of future events and the application of judgment in evaluating the cost-benefit relationship of possible controls and procedures. Because of these and other inherent limitations of control systems, there is only reasonable assurance that the Company's controls will succeed in achieving their goals under all potential future conditions.

Changes in Internal Control over Financial Reporting

There were no changes in the Company's internal control over financial reporting (as defined by Rules 13a-15(f) and 15d-15(f) under the Exchange Act) that occurred during the quarter ended March 31, ~~2019,~~2020, that have materially affected, or are reasonably likely to materially affect, the Company's internal control over financial reporting.

PART II. OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

~~There have been no~~The Company is involved in various commercial and regulatory claims, litigation and other legal proceedings that arise in the ordinary course of its business. Item 103 of the SEC's Regulation S-K requires disclosure of material ~~changes with respect~~pending legal proceedings, other than ordinary routine litigation incidental to the ~~legal~~business, to which QEP or any of its subsidiaries is a party or of which any of their property is the subject. Item 103 also requires disclosure of certain environmental matters when a governmental authority is a party to the proceedings ~~reported~~and the proceedings involve potential monetary sanctions that the Company reasonably believes could exceed $100,000. The matter below is disclosed pursuant to the first requirement.

The Mabee Ranch Royalty Partnership, LP, et al. v. QEP Energy Company - As previously disclosed, in ~~our 2018 Form 10-K.~~ October 2017, the Mabee Ranch Royalty Partnership, LP, John W. Mabee and Joseph Guy Mabee, Jr., surface and mineral owners of acreage in the Permian Basin in Martin and Andrews County, Texas, filed a petition in the District Court of Martin County, Texas, alleging various tort and breach of contract claims and seeking actual monetary damages in excess of $1,000,000, plus interest, exemplary damages, court costs, and attorneys' fees, and a declaratory judgment that portions of the oil and gas leases covering the properties are void and no longer in effect. The parties have reached a settlement involving no cash consideration and have jointly moved to dismiss the litigation.

Refer to Note 11 – Commitments and Contingencies in Item I of Part I of this Quarterly Report on Form 10-Q for additional information regarding our legal proceedings.

ITEM 1A. RISK FACTORS

Risk factors relating to the Company are set forth in its ~~2018~~2019 Form 10-K. There have been no material changes to such risk factors since filing the ~~2018~~2019 Form 10-K, except for the risk ~~factor~~factors below. The risks described below and in the ~~2018~~2019 Form 10‑K are not the only risks facing QEP. Additional risks and uncertainties not currently known to QEP or that the Company currently deems to be immaterial also may materially adversely affect its business, financial condition, or future results.

The outbreak of COVID-19 and recent oil market developments could adversely impact our financial condition and results of operations. On January 30, 2020, the WHO announced a global health emergency because of a new strain of coronavirus known as COVID-19 due to the risks it imposes on the international community as the virus spreads globally. In March 2020, the WHO classified the COVID-19 outbreak as a pandemic, based on the rapid increase in exposure globally. During this time, the crude oil market began to experience a decline in oil prices in response to concerns about oil demand due to the global economic impacts of COVID-19. In addition, policy disputes in the first quarter 2020 between OPEC and Russia resulted in Saudi Arabia significantly discounting the price of its crude oil, as well as Saudi Arabia and Russia significantly increasing their oil supply. These actions have led to significant weakness in oil prices and caused us to reduce our capital and operating budgets as well as slow our development plan. In addition, the spread of the virus into our workforce and the workforces of our counterparties could have an adverse impact on our operations.

The total magnitude and duration of potential social, economic and labor instability as a direct result of COVID-19 cannot be estimated at this time. Should any of these potential impacts continue for an extended period of time, it will have a negative impact on the demand for our oil and natural gas products and have an adverse effect on our financial position and results of operations. We expect the COVID-19 pandemic to have an adverse effect on our business results in the second quarter of 2020. To the extent the COVID-19 pandemic adversely affects our business and financial results, it may also have the effect of heightening many of the other risks described in this “Risk Factors” section and the “Risk Factors” section of our Annual Report on Form 10-K for the year ended December 31, 2019, such as those relating to our indebtedness, our need to generate sufficient cash flows to service our indebtedness and our ability to comply with the covenants contained in the agreements that govern our indebtedness.

The prices for oil, gas and NGL are volatile, and declines in such prices could adversely affect QEP's earnings, cash flows, asset values and stock price. Historically, oil, gas and NGL prices have been volatile and unpredictable, and that volatility is expected to continue. Volatility in oil, gas and NGL prices is due to a variety of factors that are beyond QEP's control, including:

changes in local, regional, domestic and foreign supply of and demand for oil, gas and NGL;

the impact of an abundance of oil, gas and NGL from unconventional sources on the global and local energy supply;

the level of imports and/or exports of, and the price of, foreign oil, gas and NGL;

localized supply and demand fundamentals, including the proximity, cost and availability of pipelines and other transportation facilities, and other factors that result in differentials to benchmark prices from time to time;

the availability of refining and storage capacity;

domestic and global economic and political conditions;

changes in government energy policies, including imposed price controls or product subsidies or both;

speculative trading in crude oil and natural gas derivative contracts;

the continued threat of terrorism and the impact of military and other action;

the activities of the Organization of Petroleum Exporting Countries (OPEC) and other oil producing countries such as Russia and Saudi Arabia, including the ability of members of OPEC and Russia to maintain oil price and production controls;

including events in the Middle East, Africa, South America and Russia;

the strength of the U.S. dollar relative to other currencies;

weather conditions, natural disasters and epidemic or pandemic disasters such as the recent outbreak of COVID-19;

domestic and international laws, regulations and taxes, including regulations, legislation or executive orders relating to climate change, induced seismicity or oil and gas exploration and production activities, including, but not limited to hydraulic fracturing;

technological advances affecting energy consumption and energy supply;

conservation efforts;

the price, availability and acceptance of alternative energy sources, including coal, nuclear energy, renewables and biofuels;

demand for electricity and natural gas used as fuel for electricity generation;

pandemic and health events that could reduce demand of petroleum products;

pandemic events that could impair our employees and contractors abilities to drill and produce oil and gas;

the level of global oil, gas and NGL inventories and exploration and production activity; and

the quality of oil and gas produced.

Declines in oil, gas and NGL prices would not only reduce revenue, but could also reduce the amount of oil, gas and NGL that we can economically produce and therefore potentially lower our oil and gas reserve quantities. In addition, a decline in oil and gas prices and volatility could negatively impact our ability to execute our operating and development plans and the ability to generate Free Cash Flow.

The long-term effect of factors impacting the prices of oil, gas and NGL is uncertain. Substantial or prolonged declines in these commodity prices may have the following effects on QEP's business:

adversely affect QEP's financial condition and liquidity and QEP's ability to finance planned capital expenditures, borrow money, repay debt and raise additional capital;

reduce the amount of oil, gas and NGL that QEP can produce economically;

limit QEP's ability to generate Free Cash Flow;

cause QEP to delay, postpone or cancel some of its capital projects;

cause QEP to divest properties to generate funds to meet cash flow or liquidity requirements;

reduce QEP's revenues, operating income or cash flows;

reduce the amounts of QEP's estimated proved oil, gas and NGL reserves;

reduce the carrying value of QEP's oil and gas properties due to recognizing additional impairments of proved and unproved properties;

limit QEP's access to, or increasing the cost of, sources of capital such as equity and long-term debt;

cause additional counterparty credit risk;

decrease the value of QEP's common stock; and

increase shareholder activism.

Alternatively, higher oil prices may result in increased volatility in commodity prices, inflation, slower economic growth, a global recession or more international conflicts. Higher oil prices may also result in higher costs for QEP and significant mark-to-market losses being incurred in QEP's commodity derivatives, which may in turn cause us to experience net losses.

~~Uncertainty relating~~QEP's operations are subject to operational hazards and unforeseen interruptions for which QEP may not be adequately insured and that could adversely affect our business, financial condition and results of operations. There are operational risks associated with the exploration, production, gathering, transporting, and storage of oil, gas and NGL, including:

pandemic health events, injuries and/or deaths of employees, supplier personnel, or other individuals;

fires, explosions and blowouts;

earthquakes and other natural disasters;

aging infrastructure and mechanical problems;

unexpected drilling conditions, including abnormally pressured formations or loss of drilling fluid circulation;

pipe, cement or casing failures;

equipment malfunctions, mechanical failures or accidents;

theft or vandalism of oilfield equipment and supplies, especially in areas of increased activity;

adverse weather conditions;

plant, pipeline, railway and other facility accidents and failures;

truck and rail loading and unloading problems;

delays imposed by or resulting from compliance with regulatory requirements;

delays in or limits on the issuance of drilling permits on our federal leases, including as a result of government shutdowns;

delays imposed by or resulting from legal proceedings;

environmental accidents such as oil spills, natural gas leaks, pipeline or tank ruptures, or discharges of air pollutants, brine water or well fluids into the environment;

security breaches, cyberattacks, piracy, or terrorist acts;

flaring of natural gas, including, where required, accurate and timely payment of royalty on flared gas;

pipeline takeaway and refining and processing capacity issues; and

title problems.

QEP could incur substantial losses as a result of pandemic health events, injury to or loss of life, pollution or other environmental damage, damage to or destruction of property or equipment, regulatory compliance investigations, fines or curtailment of operations, or attorneys' fees and other expenses incurred in the prosecution or defense of litigation. As a working interest owner in wells operated by other companies, QEP may also be exposed to the ~~LIBOR calculation~~risks enumerated above from operations that are not within its care, custody or control.

Consistent with industry practice, QEP generally indemnifies drilling contractors and oilfield service companies (collectively, contractors) against certain losses suffered by QEP as the operator and certain third parties resulting from a well blowout or fire or other uncontrolled flow of hydrocarbons, regardless of fault. Therefore, QEP may be liable, regardless of fault, for some or all of the costs of controlling a blowout, drilling a relief and/or replacement well and the cleanup of any pollution or contamination resulting from a blowout in addition to claims for personal injury or death suffered by QEP's employees and certain others. QEP's drilling contracts and oilfield service agreements, however, often provide that the contractor will indemnify QEP for claims related to injury and death of employees of the contractor and its subcontractors and for property damage suffered by the contractor and its subcontractors.

QEP's insurance coverage may not be sufficient to cover 100% of potential losses arising as a result of the foregoing risks. QEP has limited or no coverage for certain other risks, such as political risk, lost reserves, business interruption, cyber risk, earthquakes, war and terrorism. Although QEP believes the coverage and amounts of insurance that it carries are consistent with industry practice, QEP does not have insurance protection against all risks that it faces because QEP chooses not to insure certain risks, insurance is not available at a level that balances the costs of insurance and QEP's desired rates of return, or actual losses may exceed coverage limits. QEP could sustain significant losses and substantial liability for uninsured risks. The occurrence of a significant event against which QEP is not fully insured could have a material adverse effect on its financial condition, results of operations and cash flows.

If we cannot meet the continued listing requirements of the NYSE, the NYSE may delist our common stock. On April 10, 2020, we received written notification from the New York Stock Exchange (NYSE) that the average closing price of our common stock had fallen below $1.00 per share over a period of 30 consecutive trading days, which is the minimum average closing share price required to maintain listing under Section 802.01C of the NYSE Listed Company Manual. The notice has no immediate impact on the listing of our common stock, which will continue to be listed and traded on the NYSE during the six month period that we are allowed to regain compliance, subject to our compliance with other listing standards. Our common stock is permitted to continue to trade on the NYSE under the symbol “QEP,” but will have an added designation of “.BC” to indicate the status of the common stock as “below compliance.”

We informed the NYSE that we intend to cure the deficiency and to return to compliance with the NYSE continued listing requirements. We can regain compliance at any time during the six-month period following receipt of the notification if our common stock has a closing share price of at least $1.00 on the last trading day of any calendar month during the six-month period and also has an average closing share price of at least $1.00 over the 30-trading day period ending on the last trading day of that month. We can also regain compliance by (i) obtaining the requisite stockholder approval for a reverse stock split and (ii) implementing the reverse stock split promptly thereafter, such that the price of our common stock would promptly exceed $1.00 per share, provided that the price must remain above that level for at least the following 30 trading days. However, there is no assurance that our stockholders will vote for such proposal.

While we are considering various options to cure the deficiency, it may take a significant effort to regain compliance with this continued listing standard, and there can be no assurance that we will be successful.

Our common stock could also be delisted if (i) our average market capitalization over a consecutive 30 trading-day period is less than $15 million, or (ii) our common stock trades at an “abnormally low” price, which the NYSE has historically viewed to be $0.16 per share. If either event were to occur, we would not have an opportunity to cure the deficiency, and, as a result, our common stock would be suspended from trading on the NYSE immediately, and the NYSE would begin the process to delist our common stock, subject to our right to appeal under NYSE rules. There is no assurance that any appeal we undertake in these or other circumstances would be successful, nor is there any assurance that we will continue to comply with the other NYSE continued listing standards.

Failure to maintain our NYSE listing could negatively impact us and ~~potential phasing out~~our stockholders by reducing the willingness of ~~LIBOR after 2021~~investors to hold our common stock because of the resulting decreased price, liquidity and trading of our common stock, limited availability of price quotations, and reduced news and analyst coverage. These developments may also require brokers trading in our common stock to adhere to more stringent rules and may limit our ability to raise capital by issuing additional shares in the future. Delisting may adversely ~~affect~~impact the ~~market~~perception of our financial condition and cause reputational harm with investors and parties conducting business with us. In addition, the perceived decreased value of ~~QEP’s current~~employee equity incentive awards may reduce their effectiveness in encouraging performance and retention.

Failure to obtain stockholder approval for the proposed reverse stock split may result in the company being unable to obtain compliance with the continued listing requirements of the NYSE and may result in our common stock being delisted from the NYSE. We are seeking approval from our stockholders at our 2020 annual meeting to approve an amendment to our Amended and Restated Certificate of Incorporation to effect a reverse stock split at a ratio of at least 1-for-10 and up to 1-for-40, with the exact ratio within the foregoing range to be determined by our board of directors. Provided that this proposal is approved by our stockholders, we anticipate effecting a reverse stock split to regain compliance with the continued listing requirements of the NYSE. If the reverse stock split proposal is not approved by our stockholders, we may not be able to regain compliance with the NYSE’s minimum average closing share price requirements, and, as a consequence our common stock may be delisted. However, even if we are successful in receiving approval for and implementing the reverse stock split at a ratio that would allow us to regain compliance with the NYSE’s continued listing requirements, the reverse stock split would not cure any additional deficiencies that the NYSE may identify prior to or following our 2020 annual meeting, and therefore, we may still be subject to a potential delisting.

Substantially all of our producing properties and operations are located in the Williston Basin and Permian Basin, making us vulnerable to risks associated with operating in a limited number of basins. As a result of our lack of diversification in asset type and our limited geographic diversification, any delays or interruptions of production caused by such factors as governmental regulation; density and proration requirements of state regulators; transportation capacity constraints; curtailment of production or interruption of transportation; price fluctuations; natural disasters; or shutdowns of the pipelines connecting our production to refineries would have a significantly greater impact on our results of operations than if we possessed more diverse assets and locations. In addition, the effect of fluctuations on supply and demand may become more pronounced within specific geographic oil and natural gas producing areas such as the Williston Basin and Permian Basin, which may cause these conditions to occur with greater frequency or magnify the effect of these conditions. Due to the concentrated nature of our portfolio of properties, a number of our properties could experience any of the same conditions at the same time, resulting in a relatively greater impact on our results of operations than they might have on other companies that have a more diversified portfolio of properties. Such delays or interruptions could have a material adverse effect on our financial condition and results of operations.

Lack ofavailability of refining, gas processing, storage, gathering or transportation capacity will likely impact results of operations.The lack of availability of satisfactory oil, gas and NGL gathering and transportation, including trucks, railways and pipelines, gas processing, storage or refining capacity may hinder QEP's access to oil, gas and NGL markets or delay production from its wells. QEP's ability to market its production depends in substantial part on the availability, proximity and capacity of gathering, transportation, gas processing facilities, storage or refineries owned and operated by third parties. Although QEP has some contractual control over the transportation of its production through firm transportation and gas processing arrangements, third-party systems may be temporarily unavailable due to market conditions, mechanical failures, accidents, lack of contracted capacity on such systems or other reasons such as temporary suspension of service due to legal challenges and/or the pipeline’s failure to comply with applicable laws and regulations. If gathering, transportation, gas processing or storage facilities do not exist near producing wells; if gathering, transportation, gas processing, storage or refining capacity is limited; or if gathering, transportation, gas processing or refining capacity is unexpectedly disrupted, completion activity could be delayed, sales could be reduced, gas flaring increased, or production shut-in, each of which could reduce profitability. The curtailments arising from these circumstances may last from a few days to several months, and in many cases, QEP is provided with limited, if any, notice as to when these circumstances will arise and their duration. Furthermore, if QEP were required to shut-in wells, it might also be obligated to pay certain demand charges for gathering and processing services, as well as shut-in royalties to certain mineral interest owners in order to maintain its leases; or depending on the specific lease provisions, some leases could terminate. In addition, rail accidents involving crude oil carriers have resulted in regulations, and may result in additional regulations, on transportation of oil by railway. QEP might be required to install or contract for additional treating or processing equipment for transport of crude oil by rail, which could increase costs. Federal and state regulation of oil and gas production and transportation, tax and energy policies, changes in supply and demand, transportation pressures, damage to or destruction of transportation facilities and general economic conditions could also adversely affect QEP's ability to transport oil and gas.

QEP's debt and other financial commitments may limit its financial and operating flexibility. QEP's total debt was

approximately $1.9 billion at March 31, 2020. QEP also has various commitments for leases, drilling contracts, derivative

contracts, firm transportation, and purchase obligations for services, products and properties. QEP's financial commitments

could have important consequences to its business, including, but not limited to, limiting QEP's ability to fund future working

capital and capital expenditures, to engage in future acquisitions or development activities, to pay dividends, to repurchase

shares of its common stock, or to otherwise realize the value of its assets and opportunities fully because of the need to dedicate

a substantial portion of its cash flows from operations and proceeds from the divestiture of its assets to payments on its debt ~~obligations, including QEP’s~~or

to comply with any restrictive terms of its debt. QEP may be at a competitive disadvantage as compared to similar companies

that have less debt. Higher levels of debt may make QEP more vulnerable to general adverse economic and industry conditions.

Additionally, the agreement governing QEP's revolving credit ~~facility.~~ ~~Regulators~~facility and ~~law enforcement agencies~~the indentures governing QEP's senior notes contain

a number of covenants that impose constraints on the Company, including requirements to comply with certain financial

covenants and restrictions on QEP's ability to dispose of assets, make certain investments, incur liens and additional debt, and

engage in transactions with affiliates. If commodity prices decline and QEP reduces its level of capital spending and production

declines or QEP incurs additional impairment expense or the value of the Company's proved reserves declines, the Company

may not be able to incur additional indebtedness, may need to repay outstanding indebtedness and may not be in compliance

with the financial covenants in its credit agreement in the ~~United Kingdom and elsewhere are conducting civil and criminal investigations into whether~~future. For example, the ~~banks~~agreement governing our revolving credit facility requires that ~~contributed~~the present value of the Company's proved reserves be delivered to the ~~British Bankers Association (BBA)~~bank group by April 1 of each year in ~~connection~~order to determine compliance with the ~~calculation~~present value coverage ratio covenant. The present value is calculated using the prior year-end reserve report and an average commodity price deck provided by a subset of ~~daily LIBOR may have been under-reporting or otherwise manipulating or attempting to manipulate LIBOR. A number~~the bank group. As of ~~BBA member banks have entered into settlements with their regulators and law enforcement agencies~~April 23, 2020, the present value coverage ratio was the most restrictive financial covenant with respect to ~~this alleged manipulation of LIBOR. Actions by~~ the ~~BBA or any other administrator of LIBOR, regulators or law enforcement agencies may result in changes~~Company incurring additional indebtedness. Based on the current market conditions, the Company can make no assurance regarding future availability under its revolving credit facility, continued compliance with the restrictive financial covenants and ability to borrow under the credit facility beyond April 1, 2021, at which time the next present value calculation required to be delivered to the ~~manner~~bank group. Refer to Item 2 – Management's Discussion and Analysis of Financial Condition and Results of Operations in ~~which LIBOR is determined,~~Part I of this Quarterly Report on Form 10-Q for more information regarding the phasing out of LIBOR or the establishment of alternative reference rates. For example, in July 2017, the U.K. Financial Conduct Authority announced that it intends to stop persuading or compelling banks to submit LIBOR rates after 2021. As a result, LIBOR may be discontinued by 2021. Furthermore, in the United States, efforts to identify a set of alternative U.S. dollar reference interest rates that could replace LIBOR include proposals by the Alternative Reference Rates Committee of the Federal Reserve Boardfinancial covenants and the Federal Reserve Bank of New York. At this time, it is not possible to predict whether any such changes will occur, whether LIBOR will be phased out or any such alternative reference rates or other reforms to LIBOR will be enacted in the United Kingdom, the United States or elsewhere or the effect that any such changes, phase out, alternative reference rates or other reforms, if they occur, would have on the amount of interest paid on, or the market value of, QEP’s current or future debt obligations, including QEP'sour revolving credit facility. Uncertainty as to the nature of such potential changes, phase out, alternative reference rates or other reforms may materially adversely affect the terms of QEP's revolving credit facility. Reform of, or the replacement or phasing out of, LIBOR and proposed regulation of LIBOR and other "benchmarks" may materially adversely affect the market value of, the applicable interest rate on and the amount of interest paid on QEP’s current or future debt obligations, including QEP's revolving credit facility.agreement.

ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

On February 28, 2018, QEP announced the authorization by its Board of Directors to repurchase up to $1.25 billion of the Company's outstanding shares of common stock ~~(the February~~(February 2018 $1.25 billion Repurchase Program). The timing and amount of any QEP share repurchases will be subject to available liquidity and market conditions. The share repurchase program does not obligate QEP to acquire any specific number of shares and may be discontinued at any time.

~~During~~ The repurchases of shares during the three months ended March 31, ~~2019, no shares~~2020 were in connection with the settlement of income tax and related benefit withholding obligations arising from the vesting of restricted share grants. As of March 31, 2020, the remaining value that may be repurchased under the ~~previously announced plan. The following repurchases of QEP shares were made by QEP in association with vested restricted share awards withheld for~~

~~taxes and pursuant to the Company's~~ share repurchase ~~authorization.~~

program was $1,191.6 million.

Period
Total shares purchased⁽¹⁾
Weighted-average price paid per share Total shares purchased as part of publicly announced plans or programs Remaining dollar amount that may be purchased under the plans or programs
(in millions)
January 1, 2019 - January 31, 2019 277,392
$ 8.51
—
1,191.6
February 1, 2019 - February 28, 2019 1,246
$ 8.02
—
1,191.6
March 1, 2019 - March 31, 2019 437,685
$ 7.90
—
1,191.6
Total 716,323
—

~~____________________________~~


⁽¹⁾	During the three months ended March 31, 2019, QEP purchased 716,323 shares from employees in connection with the settlement of income tax and related benefit withholding obligations arising from the vesting of restricted share grants.

ITEM 3. DEFAULTS UPON SENIOR SECURITIES

None.

ITEM 4. MINE SAFETY DISCLOSURES

Not applicable.

ITEM 5. OTHER INFORMATION

None.

ITEM 6. EXHIBITS

The following exhibits are being filed as part of this report:



Exhibit No.		Description of Exhibit
3.1		Amended and Restated Certificate of Incorporation dated May 15, 2018 (incorporated by reference to Exhibit 3.1 to the Company's Current Report on Form 8-K, filed with the Securities and Exchange Commission on May 17, 2018).
3.2		Amended and Restated Bylaws, ~~dated effective October 23, 2017 (incorporated by reference to Exhibit 3.2 to the Company’s Quarterly Report~~as amended and restated on ~~Form 10-Q, filed with the Securities and Exchange Commission on October 25, 2017).~~
~~3.3~~		~~First Amendment to Amended and Restated Bylaws, dated effective January 11,~~May 14, 2019 (incorporated by reference to Exhibit 3.1 to the ~~Company’s~~Company's Current Report on Form ~~8 K,~~8-K, filed with the Securities and Exchange Commission on ~~January 14,~~May 17, 2019).
31.1*		Certification signed by Timothy J. Cutt, QEP Resources, Inc.'s Chief Executive Officer, pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.2*		Certification signed by ~~Richard~~William J. ~~Doleshek,~~Buese, QEP Resources, Inc.'s Chief Financial Officer, pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32.1**		Certification signed by Timothy J. Cutt and ~~Richard~~William J. ~~Doleshek,~~Buese, QEP Resources, Inc.'s Chief Executive Officer and Chief Financial Officer, respectively, pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
101.INS*		XBRL Instance ~~Document.~~Document - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document.
101.SCH*		XBRL Schema Document.
101.CAL*		XBRL Calculation Linkbase Document.
101.LAB*		XBRL Label Linkbase Document.
101.PRE*		XBRL Presentation Linkbase Document.
101.DEF*		XBRL Definition Linkbase Document.

____________________________


*	Filed herewith.


**	Furnished herewith.

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.



	QEP RESOURCES, INC.
	(Registrant)

April ~~24, 2019~~29, 2020	/s/ Timothy J. Cutt
	Timothy J. Cutt,
	President and Chief Executive Officer

April ~~24, 2019~~29, 2020	/s/ ~~Richard~~William J. ~~Doleshek~~Buese
	~~Richard~~William J. ~~Doleshek,~~Buese,
	~~Executive~~ Vice President, ~~and~~ Chief Financial Officer and Treasurer

5458



	December 31, 2018⁽¹⁾
	(in millions)
Assets
Current assets, total	$	1.2
Property, Plant and Equipment	683.7
Other noncurrent assets	7.8
Noncurrent assets held for sale	$	692.7
Liabilities
Current liabilities, total	$	3.4
Asset retirement obligations, current	0.7
Asset retirement obligations, long-term	56.9
Other long-term liabilities	0.3
Other long-term liabilities held for sale	$	61.3



	Asset Retirement Obligations
	(in millions)
ARO liability at January 1, 2019	$	159.6
Accretion	1.1
Additions	0.1
Revisions	(0.3		)
Liabilities related to assets sold⁽¹⁾	(58.1		)
Liabilities settled	(0.3		)
ARO liability at March 31, 2019	$	102.1



		Gross asset derivative instruments fair value				Gross liability derivative instruments fair value
	Balance Sheet line item	March 31, 2019		December 31, 2018		March 31, 2019		December 31, 2018
Current:		(in millions)
Commodity⁽¹⁾	Fair value of derivative contracts	$	—	$	88.2	$	60.3	$	0.4
Long-term:
Commodity	Fair value of derivative contracts	6.7		35.4		1.5		0.7
Total derivative instruments		$	6.7	$	123.6	$	61.8	$	1.1



	Total recognized			Recognized in "General and administrative"		Recognized in "Net gain (loss) from asset sales, inclusive of restructuring costs"			Recognized in "Interest and other income (expense)"
	Three Months Ended March 31, 2019
	(in millions)
Termination benefits	$	6.8		$	6.7	$	0.1		—
Office lease termination costs	0.6			0.6		—			—
Accelerated share-based compensation⁽¹⁾	8.4			6.9		1.5			—
Retention expense (including share-based compensation)	6.1			6.1		—			—
Pension and Medical Plan curtailment	(0.5		)	—		(0.2		)	(0.3		)
Total restructuring costs	$	21.4		$	20.3	$	1.4		$	(0.3	)

	Three Months Ended March 31, 2018
	(in millions)
Termination benefits	$	3.4		$	3.4	$	—		$	—
Office lease termination costs	—			—		—			—
Accelerated share-based compensation	2.8			2.8		—			—
Retention expense (including share-based compensation)	1.7			1.7		—			—
Pension and Medical Plan curtailment	—			—		—			—
Total restructuring costs	$	7.9		$	7.9	$	—		$	—



	Permian Basin		Williston Basin
	As of March 31, 2019
	Gross	Net	Gross	Net
Well Progress
Drilling	11	11.0	7	6.4

At total depth - under drilling rig	3	3.0	—	—
Waiting to be completed	28	28.0	—	—
Undergoing completion	4	4.0	—	—
Completed, awaiting production	11	11.0	—	—
Waiting on completion	46	46.0	—	—

Put on production	12	12.0	—	—


⁽¹⁾	~~Transportation and processing costs are deducted from revenue and~~Depending on the terms of the contract, a portion of the total transportation and processing costs ~~incurred.~~incurred by the Company are deducted from revenue. Refer to the Operating Expenses section below for a reconciliation of total transportation and processing costs.


	Oil and condensate			Gas			NGL			Total			Oil and condensate			Gas			NGL			Total
	(in millions)												(in millions)
Oil and condensate, gas and NGL sales, as adjusted
Three months ended March 31, 2018	$	300.7		$	102.0		$	19.8		$	422.5
Three months ended March 31, 2019													$	249.5		$	23.0		$	16.9		$	289.4
Changes associated with volumes⁽¹⁾	6.6			(75.3		)	6.1			(62.6		)	6.7			(2.9		)	2.7			6.5
Changes associated with prices⁽²⁾	(57.8		)	(3.7		)	(9.0		)	(70.5		)	(36.2		)	(13.6		)	(10.0		)	(59.8		)
Three months ended March 31, 2019	$	249.5		$	23.0		$	16.9		$	289.4
Three months ended March 31, 2020													$	220.0		$	6.5		$	9.6		$	236.1


⁽¹⁾	The revenue variance attributed to the change in volume is calculated by multiplying the change in volume from the three months ended March 31, ~~2019,~~2020, as compared to the three months ended March 31, ~~2018,~~2019, by the average field-level price for the three months ended March 31, ~~2018.~~2019.


⁽¹⁾	~~Excludes acquisition deposits held in escrow of $0.2 million for the three months ended March 31, 2018.~~

									Production Commodity Derivative Swaps
Year	Index	Total Volumes	Average Swap Price per Unit		Index	Total Volumes	Average Swap Price per Unit
		(in millions)				(in millions)
Oil sales		(bbls)	($/bbl)			(bbls)	($/bbl)
2019	NYMEX WTI	9.5	$	54.93
2019	ICE Brent	1.4	$	66.73
2019 (May through December)	Argus Houston MEH	0.2	$	65.70
2020	NYMEX WTI	5.5	$	60.01	NYMEX WTI	11.5	$	56.45
2020	Argus WTI Midland	0.4	$	60.00	Argus WTI Midland	1.1	$	57.30
2020					Argus WTI Houston	0.5	$	60.06
2021					NYMEX WTI	1.6	$	55.04
Gas sales						(MMbtu)	($/MMbtu)
2020					IF Waha	8.3	$	0.63
2020					NYMEX HH	5.5	$	2.11
2021					IF Waha	11.0	$	1.59
2021					NYMEX HH	7.3	$	2.38

													Production Commodity Derivative Basis Swaps
Year	Index	Basis	Total Volumes	Weighted-Average Differential			Index	Basis	Total Volumes	Weighted-Average Differential
			(in millions)						(in millions)
Oil sales			(bbls)	($/bbl)					(bbls)	($/bbl)
2019	NYMEX WTI	Argus WTI Midland	5.0	$	(2.22	)
2019	NYMEX WTI	Argus WTI Houston	0.6	$	3.75
2020	NYMEX WTI	Argus WTI Midland	2.6	$	(0.46	)	NYMEX WTI	Argus WTI Midland	5.5	$	(0.03	)
2020							NYMEX WTI	Argus WTI Houston	0.2	$	3.75
2021							NYMEX WTI	Argus WTI Midland	4.4	$	0.99



	Commodity derivative contracts
	(in millions)
Net fair value of oil and gas derivative contracts outstanding at December 31, 2018	$	122.5
Contracts settled	5.9
Change in oil prices on futures markets	97.4
Contracts added	(280.9		)
Net fair value of oil derivative contracts outstanding at March 31, 2019	$	(55.1	)



Period	Total shares purchased⁽¹⁾	Weighted-average price paid per share		Total shares purchased as part of publicly announced plans or programs	Remaining dollar amount that may be purchased under the plans or programs
					(in millions)
January 1, 2019 - January 31, 2019	277,392	$	8.51	—	1,191.6
February 1, 2019 - February 28, 2019	1,246	$	8.02	—	1,191.6
March 1, 2019 - March 31, 2019	437,685	$	7.90	—	1,191.6
Total	716,323			—