UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

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

For the quarterly period ended ~~March 31,~~September 30, 2020

☐ 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 001-37419

PDC ENERGY, INC.

(Exact name of registrant as specified in its charter)



Delaware			95-2636730
(State of incorporation)			(I.R.S. Employer Identification No.)

1775 Sherman Street, Suite 3000

Denver, Colorado 80203

(Address of principal executive offices) (Zip code)

Registrant's telephone number, including area code: (~~303~~)(303) 860-5800

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

Title of each class

Ticker Symbol

Name of each exchange on which registered

Common stock, par value $0.01 per share

PDCE

Nasdaq Global Select Market

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 x 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 (§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 x 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 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	x	Accelerated filer	☐
Non-accelerated filer	☐	Smaller reporting company	☐
		Emerging growth company	☐

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 ☐ No x

Indicate the number of shares outstanding of each of the issuer's classes of common stock, as of the latest practicable date: ~~99,542,924~~99,637,673 shares of the Company's Common Stock ($0.01 par value) were outstanding as of ~~April~~October 22, 2020.

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PDC ENERGY, INC.

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		PART I – FINANCIAL INFORMATION		Page

Item 1.		~~PART I – FINANCIAL INFORMATION~~ Financial Statements (Unaudited)		~~Page~~

~~Item 1.~~	~~Financial Statements~~
	Condensed Consolidated Balance Sheets ~~(unaudited)~~		1
		Condensed Consolidated Statements of Operations ~~(unaudited)~~		2
		Condensed Consolidated Statements of Cash Flows ~~(unaudited)~~		3
		Condensed Consolidated Statements of Stockholders' Equity ~~(unaudited)~~		4
		Notes to Condensed Consolidated Financial Statements		56
Item 2.		Management’s Discussion and Analysis of Financial Condition and Results of Operations		2932
Item 3.		Quantitative and Qualitative Disclosures About Market Risk		4852
Item 4.		Controls and Procedures		4953

PART II – OTHER INFORMATION

Item 1.		Legal Proceedings		5054
Item 1A.		Risk Factors		5054
Item 2.		Unregistered Sales of Equity Securities and Use of Proceeds		5156
Item 3.		Defaults Upon Senior Securities		5156
Item 4.		Mine Safety Disclosures		5156
Item 5.		Other Information		5156
Item 6.		Exhibits		5257

		~~SIGNATURES~~Signatures		5358

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SPECIAL NOTE REGARDING FORWARD-LOOKING STATEMENTS

This Quarterly Report on Form 10-Q contains forward-looking statements within the meaning of Section 27A of the Securities Act of 1933 ("Securities Act"), Section 21E of the Securities Exchange Act of 1934 ("Exchange Act") and the United States ("U.S.") Private Securities Litigation Reform Act of 1995 regarding our business, financial condition, results of operations and prospects. All statements other than statements of historical fact included in and incorporated by reference into this report are "forward-looking statements." Words such as expect, anticipate, intend, plan, believe, seek, estimate, schedule and similar expressions or variations of such words are intended to identify forward-looking statements herein. Forward-looking statements include, among other things, statements regarding future: production, costs and cash flows; drilling locations, zones and growth opportunities; commodity prices and differentials; capital expenditures and projects, including the number of rigs employed; cash flows from operations relative to future capital investments; our currently suspended stock repurchase program; financial ratios and compliance with covenants in our revolving credit facility and other debt instruments; impacts of certain accounting and tax changes; timing and adequacy of infrastructure projects of our midstream ~~providers and the related impact on our midstream capacity and related curtailments; fractionation capacity;~~providers; impacts of Colorado political matters, ~~and expected timing of rulemakings;~~including recent rulemaking initiatives given our geographic concentration; ability to meet our volume commitments to midstream providers; ~~ability to obtain permits from the Colorado Oil and Gas Conservation Commission ("COGCC") in a timely manner; and~~ ongoing compliance with our consent ~~decree~~decree; risk of our counterparties non-performance on derivative instruments; and ~~expected timing of certain litigation.~~our ability to repay our 2021 Convertible Notes and fund planned activities.

The above statements are not the exclusive means of identifying forward-looking statements herein. Although forward-looking statements contained in this report reflect our good faith judgment, such statements can only be based on facts and factors currently known to us. Forward-looking statements are always subject to risks and uncertainties, and become subject to greater levels of risk and uncertainty as they address matters further into the future. Throughout this report or accompanying materials, we may use the term “projection” or similar terms or expressions, or indicate that we have “modeled” certain future scenarios. We typically use these terms to indicate our current thoughts on possible outcomes relating to our business or our industry in periods beyond the current fiscal year. Because such statements relate to events or conditions further in the future, they are subject to increased levels of uncertainty.

Important factors that could cause actual results to differ materially from the forward-looking statements include, but are not limited to:

•the COVID-19 pandemic, including its effects on commodity prices, downstream capacity, employee health and safety, business continuity and regulatory matters;

•changes in global production volumes and demand, including economic conditions that might impact demand and prices for the products we produce;

•geopolitical factors, such as events that may reduce or increase production from particular oil-producing regions and/or from members of the Organization of Petroleum Exporting Countries;

•impacts of Colorado political matters;

•volatility of commodity prices for crude oil, natural gas and natural gas liquids ("NGLs") and the risk of an extended period of depressed prices, including risks relating to decreased revenue, income and cash flow, write-downs and impairments and ~~capital availability;~~availability of capital;

•volatility and widening of differentials;

•reductions in the borrowing base under our revolving credit facility;

•impact of governmental policies and/or regulations, including changes in environmental and other laws, the interpretation and enforcement of those laws and regulations, liabilities arising thereunder and the costs to comply with those laws and regulations;

•timing and receipt of necessary regulatory permits;

•impact of ~~recent~~ regulatory developments in Colorado, particularly with respect to additional permit scrutiny;

•declines in the value of our crude oil, natural gas and NGLs properties resulting in impairments;

•changes in estimates of proved reserves;

•inaccuracy of reserve estimates and expected production rates;

•potential for production decline rates from our wells being greater than expected;

•timing and extent of our success in discovering, acquiring, developing and producing reserves;

•availability and cost of sufficient pipeline, gathering and other transportation facilities and related infrastructure to process and transport our production and the impact of these facilities and regional capacity on the prices we receive for our production;

~~timing and receipt of necessary regulatory permits;~~

•risks incidental to the drilling and operation of crude oil and natural gas wells;

•difficulties in integrating our operations as a result of any significant acquisitions, including the merger with SRC Energy Inc. ("SRC"), or acreage exchanges;

•increases ~~or changes~~ in costs and expenses;

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•limitations in the availability of supplies, materials, contractors and services that may delay the drilling or completion of our wells;

•potential losses of acreage due to lease expirations or otherwise;

•future cash flows, liquidity and financial condition;

•competition within the oil and gas industry;

•availability and cost of capital;

~~our~~ •success in marketing our crude oil, natural gas and NGLs;

•effect of crude oil and natural gas derivative activities;

•impact to our operations, personnel retention, strategy, stock price and expenses caused by the actions of activist shareholders;

•impact of environmental events, governmental and other third-party responses to such events and our ability to insure adequately against such events;

•cost of pending or future ~~litigation~~litigation;

•effect that acquisitions we may pursue have on our capital requirements;

•our ability to retain or attract senior management and key technical employees; and

•success of strategic plans, expectations and objectives for our future operations.

Further, we urge you to carefully review and consider the cautionary statements and disclosures, specifically those under the heading "Risk Factors," made in this Quarterly Report on Form 10-Q, our Annual Report on Form 10-K for the year ended December 31, 2019 filed with the U.S. Securities and Exchange Commission ("SEC") on February 26, 2020 (the "2019 Form 10-K"), our Quarterly Report on Form 10-Q for the quarter ended March 31, 2020 filed with the SEC on May 8, 2020 (the "First Quarter 2020 Form 10-Q"), our Quarterly Report on Form 10-Q for the quarter ended June 30, 2020 filed with the SEC on August 6, 2020 (the "Second Quarter 2020 Form 10-Q") and our other filings with the SEC for further information on risks and uncertainties that could affect our business, financial condition, results of operations and prospects, which are incorporated by this reference as though fully set forth herein. We caution you not to place undue reliance on the forward-looking statements, which speak only as of the date of this report. We undertake no obligation to update any forward-looking statements in order to reflect any event or circumstance occurring after the date of this report or currently unknown facts or conditions or the occurrence of unanticipated events. All forward-looking statements are qualified in their entirety by this cautionary statement.

REFERENCES

Unless the context otherwise requires, references in this report to "PDC Energy," "PDC," "the Company," "we," "us," "our" or "ours" refer to the registrant, PDC Energy, Inc. and all subsidiaries consolidated for the purposes of its financial statements.

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PART I - FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

PDC ENERGY, INC.

Condensed Consolidated Balance Sheets

(~~unaudited;~~ in thousands, except share and per share data)

(Unaudited)


	September 30, 2020		December 31, 2019
Assets
Current assets:
Cash and cash equivalents	$	3,818	$	963

Accounts receivable, net	207,151		266,354
Fair value of derivatives	138,652		28,078
Prepaid expenses and other current assets	11,964		8,635
Total current assets	361,585		304,030
Properties and equipment, net	4,885,234		4,095,202

Fair value of derivatives	13,027		3,746

Other assets	72,682		45,702
Total Assets	$	5,332,528	$	4,448,680

Liabilities and Stockholders' Equity
Liabilities
Current liabilities:
Accounts payable	$	103,504	$	98,934
Production tax liability	122,555		76,236
Fair value of derivatives	63,957		2,921
Funds held for distribution	174,084		98,393
Accrued interest payable	21,179		14,284
Other accrued expenses	81,892		70,462
Current portion of long-term debt	190,608		0
Total current liabilities	757,779		361,230
Long-term debt	1,525,999		1,177,226
Deferred income taxes	0		195,841
Asset retirement obligations	133,356		95,051

Fair value of derivatives	46,460		692
Other liabilities	250,535		283,133
Total liabilities	2,714,129		2,113,173

Commitments and contingent liabilities (Note 12)

Stockholders' equity

Common shares - par value $0.01 per share, 150,000,000 authorized, 99,639,727 and 61,652,412 issued as of September 30, 2020 and December 31, 2019, respectively	996		617
Additional paid-in capital	3,383,648		2,384,309
Accumulated Deficit	(765,575)		(47,945)
Treasury shares - at cost, 17,150 and 34,922 as of September 30, 2020 and December 31, 2019, respectively	(670)		(1,474)
Total stockholders' equity	2,618,399		2,335,507
Total Liabilities and Stockholders' Equity	$	5,332,528	$	4,448,680

See accompanying Notes to Condensed Consolidated Financial Statements

March 31, 2020 December 31, 2019
Assets
Current assets:
Cash and cash equivalents $ 61,244
$ 963
Accounts receivable, net 270,012
266,354
Fair value of derivatives 379,355
28,078
Prepaid expenses and other current assets 9,800
8,635
Total current assets 720,411
304,030
Properties and equipment, net 5,034,494
4,095,202
Fair value of derivatives 58,094
3,746
Other assets 66,792
45,702
Total Assets $ 5,879,791
$ 4,448,680

Liabilities and Stockholders' Equity
Liabilities
Current liabilities:
Accounts payable $ 223,277
$ 98,934
Production tax liability 121,615
76,236
Fair value of derivatives 11,620
2,921
Funds held for distribution 165,247
98,393
Accrued interest payable 20,349
14,284
Other accrued expenses 75,333
70,462
Total current liabilities 617,441
361,230
Long-term debt 1,896,324
1,177,226
Deferred income taxes —
195,841
Asset retirement obligations 138,654
95,051
Fair value of derivatives 14,030
692
Other liabilities 353,378
283,133
Total liabilities 3,019,827
2,113,173

Commitments and contingent liabilities

Stockholders' equity
Common shares - par value $0.01 per share, 150,000,000 authorized, 99,438,122 and 61,652,412 issued as of March 31, 2020 and December 31, 2019, respectively
994
617
Additional paid-in capital 3,372,711
2,384,309
Retained deficit (512,960 ) (47,945 )
Treasury shares - at cost, 20,493 and 34,922
as of March 31, 2020 and December 31, 2019, respectively
(781 ) (1,474 )
Total stockholders' equity 2,859,964
2,335,507
Total Liabilities and Stockholders' Equity $ 5,879,791
$ 4,448,680

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PDC ENERGY, INC.

Condensed Consolidated Statements of Operations

(~~unaudited;~~ in thousands, except per share data)

(Unaudited)


	Three Months Ended September 30,				Nine Months Ended September 30,
	2020		2019		2020		2019
Revenues
Crude oil, natural gas and NGLs sales	$	314,920	$	307,409	$	809,156	$	967,464
Commodity price risk management gain (loss), net	(68,061)		54,867		245,851		(87,858)
Other income	2,358		3,667		5,656		11,495
Total revenues	249,217		365,943		1,060,663		891,101
Costs, expenses and other
Lease operating expenses	37,338		36,498		122,680		106,047
Production taxes	14,621		13,039		40,937		57,849
Transportation, gathering and processing expenses	24,399		10,999		54,844		34,631
Exploration, geologic and geophysical expense	162		209		1,026		3,492

General and administrative expense	32,490		41,091		130,007		123,497
Depreciation, depletion and amortization	144,504		171,839		470,152		491,784
Accretion of asset retirement obligations	2,420		1,356		7,398		4,503
Impairment of properties and equipment	1,221		167		882,327		37,021

Loss (gain) on sale of properties and equipment	(289)		43,872		(642)		9,599

Other expenses	1,936		2,492		6,083		8,882
Total costs, expenses and other	258,802		321,562		1,714,812		877,305
Income (loss) from operations	(9,585)		44,381		(654,149)		13,796
Interest expense, net	(21,022)		(17,811)		(66,977)		(53,679)

Income (loss) before income taxes	(30,607)		26,570		(721,126)		(39,883)
Income tax benefit (expense)	(176)		(10,662)		3,496		4,163
Net income (loss)	$	(30,783)	$	15,908	$	(717,630)	$	(35,720)

Earnings (loss) per share:
Basic	$	(0.31)	$	0.25	$	(7.34)	$	(0.55)
Diluted	$	(0.31)	$	0.25	$	(7.34)	$	(0.55)

Weighted-average common shares outstanding:
Basic	99,617		62,547		97,762		64,835
Diluted	99,617		62,595		97,762		64,835

See accompanying Notes to Condensed Consolidated Financial Statements

Three Months Ended March 31,
2020 2019
Revenues
Crude oil, natural gas and NGLs sales $ 320,315
$ 321,099
Commodity price risk management gain (loss), net 434,698
(190,074 )
Other income 2,017
3,475
Total revenues 757,030
134,500
Costs, expenses and other
Lease operating expenses 49,534
35,221
Production taxes 18,470
22,168
Transportation, gathering and processing expenses 13,496
11,424
Exploration, geologic and geophysical expense 136
2,643
General and administrative expense 62,165
39,598
Depreciation, depletion and amortization 176,157
151,422
Accretion of asset retirement obligations 2,620
1,584
Impairment of properties and equipment 881,074
7,875
Gain on sale of properties and equipment (179 ) (369 )
Other expenses 2,144
3,554
Total costs, expenses and other 1,205,617
275,120
Loss from operations (448,587 ) (140,620 )
Interest expense, net (24,173 ) (16,968 )
Loss before income taxes (472,760 ) (157,588 )
Income tax benefit 7,745
37,412
Net loss $ (465,015 ) $ (120,176 )

Earnings per share:
Basic $ (4.94 ) $ (1.82 )
Diluted $ (4.94 ) $ (1.82 )

Weighted-average common shares outstanding:
Basic 94,077
66,182
Diluted 94,077
66,182

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PDC ENERGY, INC.

Condensed Consolidated Statements of Cash Flows

(~~unaudited;~~ in thousands)

(Unaudited)


	Nine Months Ended September 30,
	2020		2019
Cash flows from operating activities:
Net loss	$	(717,630)	$	(35,720)
Adjustments to net loss to reconcile to net cash from operating activities:
Net change in fair value of unsettled commodity derivatives	(18,338)		68,058
Depreciation, depletion and amortization	470,152		491,784
Impairment of properties and equipment	882,327		37,021



Accretion of asset retirement obligations	7,398		4,503
Non-cash stock-based compensation	17,441		18,124
Loss (gain) on sale of properties and equipment	(642)		9,599

Amortization and write-off of debt discount, premium and issuance costs	12,546		10,139
Deferred income taxes	(2,431)		(4,389)
Other	1,950		2,761
Changes in assets and liabilities	(3,461)		49,092
Net cash from operating activities	649,312		650,972
Cash flows from investing activities:
Capital expenditures for development of crude oil and natural gas properties	(445,505)		(755,828)
Capital expenditures for other properties and equipment	(1,940)		(15,522)
Acquisition of crude oil and natural gas properties	(139,812)		(12,445)
Proceeds from sale of properties and equipment	1,539		1,528
Proceeds from divestitures	1,796		202,046

Restricted cash	0		8,001


Net cash from investing activities	(583,922)		(572,220)
Cash flows from financing activities:



Proceeds from revolving credit facility and other borrowings	1,485,600		1,300,000
Repayment of revolving credit facility and other borrowings	(1,204,600)		(1,235,500)

Proceeds from senior notes	148,500		0
Payment of debt issuance costs	(6,197)		(53)
Purchase of treasury shares	(23,819)		(142,665)
Purchase of treasury shares for employee stock-based compensation tax withholding obligations	(8,412)		(3,874)
Redemption of senior notes	(452,153)		0

Principal payments under financing lease obligations	(1,454)		(1,492)

Net cash from financing activities	(62,535)		(83,584)
Net change in cash, cash equivalents and restricted cash	2,855		(4,832)
Cash, cash equivalents and restricted cash, beginning of period	963		9,399
Cash, cash equivalents and restricted cash, end of period	$	3,818	$	4,567

See accompanying Notes to Condensed Consolidated Financial Statements

Three Months Ended March 31,
2020 2019
Cash flows from operating activities:
Net loss $ (465,015 ) $ (120,176 )
Adjustments to net loss to reconcile to net cash from operating activities:
Net change in fair value of unsettled commodity derivatives (388,875 ) 181,622
Depreciation, depletion and amortization 176,157
151,422
Impairment of properties and equipment 881,074
7,875
Accretion of asset retirement obligations 2,620
1,584
Non-cash stock-based compensation 5,672
4,683
Gain on sale of properties and equipment (179 ) (369 )
Amortization of debt discount, premium and issuance costs 3,640
3,349
Deferred income taxes (6,331 ) (37,487 )
Other 1,011
21
Changes in assets and liabilities 56,507
(35,424 )
Net cash from operating activities 266,281
157,100
Cash flows from investing activities:
Capital expenditures for development of crude oil and natural gas properties (190,768 ) (242,187 )
Capital expenditures for other properties and equipment (455 ) (4,826 )
Acquisition of crude oil and natural gas properties (139,812 ) —
Proceeds from sale of properties and equipment 793
102
Proceeds from divestitures 62
—
Net cash from investing activities (330,180 ) (246,911 )
Cash flows from financing activities:
Proceeds from revolving credit facility 917,000
432,000
Repayment of revolving credit facility (304,000 ) (340,500 )
Payment of debt issuance costs (4,666 ) —
Purchase of treasury shares (23,819 ) —
Purchase of treasury shares for employee stock-based compensation tax withholding obligations (7,693 ) (1,460 )
Redemption of senior notes (452,153 ) —
Principal payments under financing lease obligations (489 ) (494 )
Other —
(21 )
Net cash from financing activities 124,180
89,525
Net change in cash, cash equivalents and restricted cash 60,281
(286 )
Cash, cash equivalents and restricted cash, beginning of period 963
9,399
Cash, cash equivalents and restricted cash, end of period $ 61,244
$ 9,113

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PDC ENERGY, INC.

Condensed Consolidated Statements of Stockholders' Equity

(~~unaudited;~~ in thousands, except share data)

(Unaudited)


	Nine Months Ended September 30, 2020
	Common Stock					Treasury Stock
	Shares	Amount		Additional Paid-in Capital		Shares	Amount		Accumulated Deficit		Total Stockholders' Equity

Balance, December 31, 2019	61,652,412	$	617	$	2,384,309	(34,922)	$	(1,474)	$	(47,945)	$	2,335,507
Net loss	—	—		—		—	—		(465,015)		(465,015)
Issuance pursuant to acquisition	39,182,045	391		1,014,921		—	—		—		1,015,312
Stock-based compensation	120,952	1		3,713		0	1,958		—		5,672
Purchase of treasury shares for employee stock-based compensation tax withholding obligations	—	—		—		(306,185)	(7,693)		—		(7,693)
Retirement of treasury shares for employee stock-based compensation tax withholding obligations	(251,287)	(3)		(6,425)		251,287	6,428		—		—
Purchase of treasury shares	—	—		—		(1,266,000)	(23,819)		—		(23,819)
Retirement of treasury shares	(1,266,000)	(12)		(23,807)		1,266,000	23,819		—		—
Issuance of treasury shares	0	0		0		69,327	0		—		—
Balance, March 31, 2020	99,438,122	994		3,372,711		(20,493)	(781)		(512,960)		2,859,964
Net loss	—	—		—		—	—		(221,832)		(221,832)
Stock-based compensation	212,809	2		6,164		0	198		—		6,364
Purchase of treasury shares for employee stock-based compensation tax withholding obligations	—	—		—		(64,219)	(487)		—		(487)
Retirement of treasury shares for employee stock-based compensation tax withholding obligations	(39,374)	—		(322)		39,374	322		—		—


Issuance of treasury shares	0	0		0		12,200	0		—		0
Balance, June 30, 2020	99,611,557	996		3,378,553		(33,138)	(748)		(734,792)		2,644,009
Net loss	—	—		—		—	—		(30,783)		(30,783)
Stock-based compensation	36,826	0		5,216		0	189		—		5,405
Purchase of treasury shares for employee stock-based compensation tax withholding obligations	—	—		—		(16,642)	(232)		—		(232)
Retirement of treasury shares for employee stock-based compensation tax withholding obligations	(8,656)	—		(121)		8,656	121		—		—


Issuance of treasury shares	0	0		0		23,974	0		—		0




Balance, September 30, 2020	99,639,727	$	996	$	3,383,648	(17,150)	$	(670)	$	(765,575)	$	2,618,399

See accompanying Notes to Condensed Consolidated Financial Statements

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																					Nine Months Ended September 30, 2019
	Three Months Ended March 31, 2020																				Common Stock					Treasury Stock
	Common Stock								Treasury Stock												Shares	Amount		Additional Paid-in Capital		Shares	Amount		Retained Earnings (Accumulated Deficit)		Total Stockholders' Equity
	Shares		Amount			Additional Paid-in Capital			Shares		Amount			Retained Deficit			Total Stockholders' Equity
Balance, December 31, 2018																				Balance, December 31, 2018	66,148,609	$	661	$	2,519,423	(45,220)	$	(2,103)	$	8,727	$	2,526,708
Net loss																				Net loss	—	—		—		—	—		(120,176)		(120,176)
Stock-based compensation																				Stock-based compensation	48,254	1		4,682		0	0		—		4,683
Purchase of treasury shares for employee stock-based compensation tax withholding obligations																				Purchase of treasury shares for employee stock-based compensation tax withholding obligations	—	—		—		(41,787)	(1,460)		—		(1,460)
Issuance of treasury shares																				Issuance of treasury shares	0	0		(2,547)		64,372	2,547		—		0

Balance, December 31, 2019	61,652,412		$	617		$	2,384,309		(34,922	)	$	(1,474	)	$	(47,945	)	$	2,335,507
Net loss	—		—			—			—		—			(465,015		)	(465,015		)
Issuance pursuant to acquisition	39,182,045		391			1,014,921			—		—			—			1,015,312
Balance, March 31, 2019																				Balance, March 31, 2019	66,196,863	662		2,521,558		(22,635)	(1,016)		(111,449)		2,409,755
Net income																				Net income	—	—		—		—	—		68,548		68,548
Stock-based compensation	190,279		1			3,713			—		1,958			—			5,672			Stock-based compensation	148,040	1		7,574		0	0		—		7,575
Purchase of treasury shares for employee stock-based compensation tax withholding obligations	—		—			—			(306,185	)	(7,693		)	—			(7,693		)	Purchase of treasury shares for employee stock-based compensation tax withholding obligations	—	—		—		(54,784)	(2,257)		—		(2,257)
Retirement of treasury shares for employee stock-based compensation tax withholding obligations	(251,287	)	(3		)	(6,425		)	251,287		6,428			—			—			Retirement of treasury shares for employee stock-based compensation tax withholding obligations	(2,182)	—		(78)		2,182	78		—		—
Purchase of treasury shares	—		—			—			(1,266,000	)	(23,819		)	—			(23,819		)	Purchase of treasury shares	—	—		—		(3,136,406)	(105,215)		—		(105,215)
Retirement of treasury shares	(1,266,000	)	(12		)	(23,807		)	1,266,000		23,819			—			—			Retirement of treasury shares	(2,822,259)	(28)		(94,085)		2,822,259	94,113		—		—
Issuance of treasury shares	(69,327	)	—			—			69,327		—			—			—			Issuance of treasury shares	0	0		(995)		24,604	995				—
Balance, March 31, 2020	99,438,122		$	994		$	3,372,711		(20,493	)	$	(781	)	$	(512,960	)	$	2,859,964

Balance, June 30, 2019																				Balance, June 30, 2019	63,520,462	$	635	$	2,433,974	(364,780)	$	(13,302)	$	(42,901)	$	2,378,406
Net income																				Net income	—	—		—		—	—		15,908		15,908
Stock-based compensation																				Stock-based compensation	10,808	0		5,866		0	0		—		5,866
Purchase of treasury shares for employee stock-based compensation tax withholding obligations																				Purchase of treasury shares for employee stock-based compensation tax withholding obligations	—	—		—		(4,750)	(157)		—		(157)
Retirement of treasury shares for employee stock-based compensation tax withholding obligations																				Retirement of treasury shares for employee stock-based compensation tax withholding obligations	(995)	—		(32)		995	32		—		—
Purchase of treasury shares																				Purchase of treasury shares	—	—		—		(1,228,310)	(40,268)		—		(40,268)
Retirement of treasury shares																				Retirement of treasury shares	(1,442,457)	(14)		(48,536)		1,442,457	48,550		—		—
Issuance of treasury shares																				Issuance of treasury shares	0	0		(614)		14,973	614		—		0

Balance, September 30, 2019																				Balance, September 30, 2019	62,087,818	$	621	$	2,390,658	(139,415)	$	(4,531)	$	(26,993)	$	2,359,755

See accompanying Notes to Condensed Consolidated Financial Statements

Three Months Ended March 31, 2019
Common Stock Treasury Stock
Shares Amount Additional Paid-in Capital Shares Amount Retained Earnings (Deficit) Total Stockholders' Equity

Balance, December 31, 2018 66,148,609
$ 661
$ 2,519,423
(45,220 ) $ (2,103 ) $ 8,727
$ 2,526,708
Net loss —
—
—
—
—
(120,176 ) (120,176 )
Stock-based compensation 112,626
—
2,136
—
2,547
—
4,683
Purchase of treasury shares for employee stock-based compensation tax withholding obligations —
—
—
(41,787 ) (1,460 ) —
(1,460 )
Issuance of treasury shares (64,372 ) 1
(1 ) 64,372
—
—
—
Balance, March 31, 2019 66,196,863
$ 662
$ 2,521,558
(22,635 ) $ (1,016 ) $ (111,449 ) $ 2,409,755

Table of Contents

PDC ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

~~March 31,~~September 30, 2020

(unaudited)

NOTE 1 - NATURE OF OPERATIONS AND BASIS OF PRESENTATION

PDC Energy, Inc. is a domestic independent exploration and production company that acquires, explores and develops properties for the production of crude oil, natural gas and NGLs, with operations in the Wattenberg Field in Colorado and the Delaware Basin in Texas. Our operations in the Wattenberg Field are focused in the horizontal Niobrara and Codell plays and our Delaware Basin operations are primarily focused in the Wolfcamp zones. As of ~~March 31,~~September 30, 2020, we owned an interest in approximately ~~3,900~~3,800 gross productive wells.

The accompanying unaudited condensed consolidated financial statements include the accounts of PDC and our wholly-owned subsidiaries. All material intercompany accounts and transactions have been eliminated in consolidation. In our opinion, the accompanying condensed consolidated financial statements contain all adjustments, consisting of normal recurring adjustments necessary for a fair ~~statement~~presentation of our financial statements for interim periods in accordance with accounting principles generally accepted in the United States of America ("U.S. GAAP") and with the instructions to Form 10-Q and Article 10 of Regulation S-X of the SEC. Accordingly, pursuant to such rules and regulations, certain notes and other financial information included in audited financial statements have been condensed or omitted. The December 31, 2019 condensed consolidated balance sheet data was derived from audited statements, but does not include all disclosures required by U.S. GAAP. The information presented in this Quarterly Report on Form 10-Q should be read in conjunction with our audited consolidated financial statements and notes thereto included in our 2019 Form 10-K. Our results of operations and cash flows for the ~~three~~nine months ended ~~March 31,~~September 30, 2020 are not necessarily indicative of the results to be expected for the full year or any other future period.

NOTE 2 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Recently Adopted Accounting ~~Standards.~~Pronouncement

In March 2020, the ~~Securities and Exchange Commission (“SEC”)~~SEC adopted final rules that amend the financial disclosure requirements for subsidiary issuers and guarantors of registered debt securities in Rule 3-10 of Regulation S-X. The amended rules, which can be found under new Rule 13-01 of Regulation S-X, narrow the circumstances that require separate financial statements of subsidiary issuers and guarantors and streamline the alternative disclosures required in lieu of those statements. The amended rules allow ~~the~~ registrants, among other things, to disclose summarized financial information of the issuer and guarantors on a combined basis and to present only the most recently completed fiscal year and subsequent year-to-date interim period. The rule ~~allows~~replaces the ~~parent company~~requirement to ~~omit~~provide condensed consolidating financial information with a requirement to present summarized financial information ~~if it is not material, or if assets, liabilities, and results of operations~~ of the ~~combined~~ issuers and ~~guarantors of~~guarantors. These disclosures may be provided outside the ~~security are not materially different than~~notes to the ~~amounts in the parent company’s~~condensed consolidated financial statements. The rule is effective in the first quarter of 2021, ~~but~~with earlier ~~compliance is~~adoption permitted. We early adopted the rule in the first quarter of 2020 and ~~chose~~have provided these disclosures outside the notes to ~~omit~~ the ~~summarized financial information as the combined financial statements of the issuer and guarantors were not materially different than the amounts in our~~condensed consolidated financial statements.

Recently Issued Accounting Pronouncement but Not Yet Adopted

In August 2020, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2020-06, Debt - Debt with conversion and other options and derivatives and hedging on contracts in entity's own equity. Amendments in this ASU simplify accounting for certain financial instruments with characteristics of liabilities and equity, including convertible instruments and contracts on an entity's own equity. The amendments remove the separation models for convertible debt instruments with cash conversion features and convertible instruments with beneficial conversion features. Consequently, a convertible debt instrument will be accounted for as a single liability measured at its amortized cost and convertible preferred stock will be accounted for as a single equity instrument measured at its historical cost as long as no other features require bifurcation and recognition as derivatives. The amendments also modify the accounting for certain contracts in an entity's own equity that are currently accounted for as derivatives because of specific settlement provisions. Lastly, the earnings per share ("EPS") calculation is being amended to (i) require entities to use the if-converted method for all convertible instruments and include the effect of potential share settlement; (ii) clarify that the average market price for the period should be used in the computation of the diluted EPS denominator; and (iii) require entities to use the weighted-average share count from each quarter when calculating the year-to-date weighted average share count for all potentially dilutive securities. The amendments in this ASU are effective for fiscal years beginning after December 31, 2021, including interim periods within those fiscal years and early adoption is permitted. We are in the process of evaluating the potential impact of adopting this ASU and we do not expect to adopt the amendments early.

Table of Contents

PDC ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

September 30, 2020

(unaudited)

In August 2020, the SEC issued a final rule that modernizes the disclosure requirements in Regulation S-K relating to the description of the business, legal proceedings, and risk factors, which are required in many SEC filings, including Form 10-K and registration statements. The final rule is effective on November 9, 2020, 30 days after its date of publication in the Federal Register. We will consider the amendments when preparing our annual report for the year ending December 31, 2020.

NOTE 3 - BUSINESS COMBINATION

In January 2020, we merged with SRC in a transaction valued at $1.7 billion, inclusive of SRC's net debt (the "SRC Acquisition"). Upon closing, we issued approximately 39 million shares of our common stock to SRC shareholders and holders of SRC equity awards, reflecting the issuance of 0.158 of a share of our common stock in exchange for each outstanding share of SRC common stock and the cancellation of outstanding SRC equity awards pursuant to the merger agreement that we entered into with SRC (the "Merger Agreement"). ~~We are accounting for the SRC Acquisition under the acquisition method of accounting for business combinations.~~ During the ~~three~~nine months ended ~~March 31,~~September 30, 2020, we recorded transaction costs related to the SRC Acquisition of $20.2 million. These expenses were accounted for separately from the assets and liabilities assumed and are included in general and administrative ~~expense.~~expense in the condensed consolidated statements of operations.

~~Table of contents~~

~~PDC ENERGY, INC.~~

~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS~~

~~March 31, 2020~~

~~(unaudited)~~

The details of the estimated purchase price and the preliminary allocation of the purchase price ~~for the transaction,~~ are as follows:


	Nine Months Ended September 30, 2020
	(in thousands)
Consideration:
Cash	$	40
Retirement of seller's credit facility	166,238
Total cash consideration	166,278
Common stock issued	1,009,015
Shares withheld in lieu of taxes	6,299

Total consideration	$	1,181,592

Recognized amounts of identifiable assets acquired and liabilities assumed:
Assets acquired:
Current assets	$	149,538
Properties and equipment, net - proved	1,607,175
Properties and equipment, net - unproved	109,615
Properties and equipment, net - other	16,242
Deferred tax asset	193,410
Other assets	13,266
Total assets acquired	2,089,246
Liabilities assumed:
Current liabilities	(257,285)
Senior notes	(555,500)
Asset retirement obligations	(41,901)
Other liabilities	(52,968)
Total liabilities assumed	(907,654)
Total identifiable net assets acquired	$	1,181,592

Three Months Ended March 31, 2020
(in thousands)
Consideration:
Cash $ 40
Retirement of seller's credit facility 166,238
Total cash consideration 166,278
Common stock issued 1,009,015
Shares withheld in lieu of taxes 6,299
Total consideration $ 1,181,592

Recognized amounts of identifiable assets acquired and liabilities assumed:
Assets acquired:
Current assets $ 150,487
Properties and equipment, net - proved 1,613,759
Properties and equipment, net - unproved 109,615
Properties and equipment, net - other 16,242
Deferred tax asset 189,509
Other assets 12,367
Total assets acquired 2,091,979
Liabilities assumed:
Current liabilities (261,845 )
Senior notes (555,500 )
Asset retirement obligations (40,074 )
Other liabilities (52,968 )
Total liabilities assumed (910,387 )
Total identifiable net assets acquired $ 1,181,592

This acquisition was accounted for under the acquisition ~~method.~~method of accounting for business combinations. Accordingly, we conducted assessments of the net assets acquired and recognized amounts for identifiable assets acquired and liabilities assumed at their estimated acquisition date fair values, while transaction and integration costs associated with the acquisition were expensed as incurred. The fair value measurements of assets acquired and liabilities assumed are based on inputs that are not observable in the market, and therefore represent Level 3 inputs. The fair values of crude oil and natural gas properties and asset retirement obligations were measured using valuation techniques that convert future cash flows to a single discounted amount. Significant inputs to the valuation of proved and unproved crude oil and natural gas properties include estimates of reserves, future operating and development costs, future commodity prices, estimated future cash flows, lease

Table of contents

PDC ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

September 30, 2020

(unaudited)

terms and expirations and a market-based weighted-average cost of capital rate of 10 percent. These inputs require significant judgments and estimates by management at the time of the valuation. As of the date of this report, we expect that itthe measurement period will extend into the fourth quarter of 2020, and the value of the assets and liabilities may ~~take into late 2020 until all post-closing adjustments are finalized.~~

be revised as appropriate.

~~Pro Forma Information.~~

The results of operations for the SRC Acquisition since the ~~January 14, 2020~~ closing date have been included in our ~~March 31, 2020~~ condensed consolidated financial statements for the three and nine months ended September 30, 2020 and include approximately ~~$103.5~~$82.0 million and $233.8 million of total revenue, respectively, and ~~$13.2~~$20.7 million and $19.3 million of ~~income~~loss from ~~operations.~~operations for the three and nine months ended September 30, 2020, respectively.

Pro Forma Information. The following unaudited pro forma financial information represents a summary of the consolidated results of operations for the ~~three~~nine months ended ~~March 31,~~September 30, 2020 and for the three and nine months ended September 30, 2019, assuming the acquisition had been completed as of January 1, 2019. The financial information for the three months ended September 30, 2020 is included in our condensed consolidated statements of operations and therefore does not require a pro forma disclosure. The pro forma amounts for the nine months ended September 30, 2020 include an immaterial non-recurring adjustment which was not included in our pro forma information disclosed in our six months ended June 30, 2020 and our three months ended March 31, 2020 footnotes. The pro forma financial information includes certain non-recurring pro forma adjustments that were directly attributable to the business combination. The pro forma financial information is not necessarily indicative of the results of operations that would have been achieved if the acquisition had been effective as of these dates, or of future results.

~~Table of contents~~


	Three Months Ended September 30,		Nine Months Ended September 30,
	2019		2020		2019
	(in thousands, except per share data)

Total revenue	$	511,110	$	1,082,003	$	1,373,739
Net income (loss)	63,092		(677,636)		128,337

Earnings (loss) per share:
Basic	$	0.62	$	(6.79)	$	1.23
Diluted	0.62		(6.79)		1.23

~~PDC ENERGY, INC.~~

~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS~~

~~March 31, 2020~~

~~(unaudited)~~

Three Months Ended March 31,
2020 2019
(in thousands, except per share data)

Total revenue $ 778,370
$ 301,099
Net loss (445,743 ) (62,180 )

Earnings per share:
Basic $ (4.45 ) $ (0.59 )
Diluted $ (4.45 ) $ (0.59 )

NOTE 4 - REVENUE RECOGNITION

Crude oil, natural gas and NGLs revenues are recognized when we have transferred control of crude oil, natural gas or NGLs production to the purchaser. We consider the transfer of control to have occurred when the purchaser has the ability to direct the use of, and obtain substantially all of the remaining benefits from, the crude oil, natural gas or NGLs production. We record sales revenue based on an estimate of the volumes delivered at estimated prices as determined by the applicable sales agreement. We estimate our sales volumes based on company-measured volume readings. We then adjust our crude oil, natural gas and NGLs sales in subsequent periods based on the data received from our purchasers that reflects actual volumes delivered and prices received. We receive payment for sales one to two months after actual delivery has occurred. The differences in sales estimates and actual sales are recorded one to two months later. Historically, these differences have not been material.

Table of contents

PDC ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

September 30, 2020

(unaudited)

Disaggregated Revenue. The following table presents crude oil, natural gas and NGLs sales disaggregated by commodity and operating region for the three and nine months ended ~~March 31,~~September 30, 2020 and 2019:


	Three Months Ended September 30,						Nine Months Ended September 30,
Revenue by Commodity and Operating Region	2020		2019		Percent Change		2020		2019		Percent Change
	(in thousands)
Crude oil
Wattenberg Field	$	183,420	$	185,543	(1.1)	%	$	483,608	$	569,518	(15.1)	%
Delaware Basin	42,591		70,175		(39.3)	%	107,347		191,452		(43.9)	%


Total	$	226,011	$	255,718	(11.6)	%	$	590,955	$	760,970	(22.3)	%
Natural gas
Wattenberg Field	$	39,759	$	23,949	66.0	%	$	109,279	$	100,779	8.4	%
Delaware Basin	2,140		2,613		(18.1)	%	3,183		9,293		(65.7)	%


Total	$	41,899	$	26,562	57.7	%	$	112,462	$	110,072	2.2	%
NGLs
Wattenberg Field	$	38,871	$	16,906	129.9	%	$	86,875	$	67,305	29.1	%
Delaware Basin	8,139		8,223		(1.0)	%	18,864		29,117		(35.2)	%


Total	$	47,010	$	25,129	87.1	%	$	105,739	$	96,422	9.7	%
Crude oil, natural gas and NGLs
Wattenberg Field	$	262,050	$	226,398	15.7	%	$	679,762	$	737,602	(7.8)	%
Delaware Basin	52,870		81,011		(34.7)	%	129,394		229,862		(43.7)	%


Total	$	314,920	$	307,409	2.4	%	$	809,156	$	967,464	(16.4)	%

Three Months Ended March 31,
Revenue by Commodity and Operating Region 2020 2019 Percentage Change
(in thousands)
Crude oil
Wattenberg Field $ 206,649
$ 180,426
14.5 %
Delaware Basin 42,525
50,657
(16.1 )%
Total $ 249,174
$ 231,083
7.8 %
Natural gas
Wattenberg Field $ 40,078
$ 46,701
(14.2 )%
Delaware Basin (1) (563 ) 5,770
(109.8 )%
Total $ 39,515
$ 52,471
(24.7 )%
NGLs
Wattenberg Field $ 25,241
$ 27,722
(8.9 )%
Delaware Basin 6,385
9,823
(35.0 )%
Total $ 31,626
$ 37,545
(15.8 )%
Crude oil, natural gas and NGLs
Wattenberg Field $ 271,968
$ 254,849
6.7 %
Delaware Basin 48,347
66,250
(27.0 )%
Total $ 320,315
$ 321,099
(0.2 )%

Contract Assets. ~~(1) Negative~~Contract assets include material contributions in aid of construction, which are common in purchase and processing agreements with midstream service providers that are our customers. The intent of the payments is primarily to reimburse the customer for actual costs incurred related to the construction of its gathering and processing infrastructure. Contract assets are included in other assets in the condensed consolidated balance sheet. The contract assets are amortized as a reduction to crude oil, natural gas and NGLs sales revenue ~~was due~~during the periods in which the related production is transferred to the ~~deduction~~customer.

The following table presents the changes in carrying amounts of the contract assets associated with our crude oil, natural gas and NGLs sales revenue for ~~transportation, gathering~~the nine months ended September 30, 2020:


	Amount
	(in thousands)

Beginning balance, January 1, 2020	$	11,494
Additions	15,627
Amortized as a reduction to crude oil, natural gas and NGLs sales	(1,588)
Ending balance, September 30, 2020	$	25,533

~~and processing by the purchaser exceeding the average sales price.~~

Table of contents

PDC ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

~~March 31,~~September 30, 2020

(unaudited)

NOTE 5 - FAIR VALUE OF FINANCIAL INSTRUMENTS

Determination of Fair Value

Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. Our fair value measurements are estimated pursuant to a fair value hierarchy that requires us to maximize the use of observable inputs and minimize the use of unobservable inputs when measuring fair value. The valuation hierarchy is based upon the transparency of inputs to the valuation of an asset or liability as of the measurement date, giving the highest priority to quoted prices in active markets (Level 1) and the lowest priority to unobservable data (Level 3). In some cases, the inputs used to measure fair value might fall in different levels of the fair value hierarchy. The lowest level input that is significant to a fair value measurement in its entirety determines the applicable level in the fair value hierarchy. Assessing the significance of a particular input to the fair value measurement in its entirety requires judgment, considering factors specific to the asset or liability, and may affect the valuation of the assets and liabilities and their placement within the fair value hierarchy levels. The three levels of inputs that may be used to measure fair value are defined as:

Level 1 – Quoted prices (unadjusted) for identical assets or liabilities in active markets.

Level 2 – Inputs other than quoted prices included within Level 1 that are either directly or indirectly observable for the asset or liability, including quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in inactive markets, inputs other than quoted prices that are observable for the asset or liability and inputs that are derived from observable market data by correlation or other means.

Level 3 – Unobservable inputs for the asset or liability, including situations where there is little, if any, market activity.

Derivative Financial Instruments

We measure the fair value of our derivative instruments based upon a pricing model that utilizes market-based inputs, including, but not limited to, the contractual price of the underlying position, current market prices, crude oil and natural gas forward curves, discount rates such as the LIBOR curve for a similar duration of each outstanding position, volatility factors and nonperformance risk. Nonperformance risk considers the effect of our credit standing on the fair value of derivative liabilities and the effect of our counterparties' credit standings on the fair value of derivative assets. Both inputs to the model are based on published credit default swap rates and the duration of each outstanding derivative position. We validate our fair value measurement by corroborating the original source of inputs, monitoring changes in valuation methods and assumptions and through the review of counterparty statements and other supporting documentation.

Our crude oil and natural gas fixed-price swaps are included in Level 2. Our collars are included in Level 3. Our basis swaps are included in Level 2 and Level 3. The following table presents, for each applicable level within the fair value hierarchy, our derivative assets and liabilities, including both current and non-current portions, measured at fair value on a recurring basis:

As of March 31, 2020 As of December 31, 2019
Significant Other
Observable
Inputs
(Level 2)    Significant
Unobservable
Inputs
(Level 3)    Total Significant Other
Observable
Inputs
(Level 2)    Significant
Unobservable
Inputs
(Level 3)    Total
(in thousands)
Total assets $ 365,263
$ 72,186
$ 437,449
$ 22,886
$ 8,938
$ 31,824
Total liabilities (20,704 ) (4,946 ) (25,650 ) (3,089 ) (524 ) (3,613 )
Net asset $ 344,559
$ 67,240
$ 411,799
$ 19,797
$ 8,414
$ 28,211


	As of September 30, 2020						As of December 31, 2019
	Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
	(in thousands)



Total assets	$	130,134	$	21,545	$	151,679	$	22,886	$	8,938	$	31,824



Total liabilities	(79,658)		(30,759)		(110,417)		(3,089)		(524)		(3,613)
Net derivative instruments	$	50,476	$	(9,214)	$	41,262	$	19,797	$	8,414	$	28,211

Table of contents

PDC ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

~~March 31,~~September 30, 2020

(unaudited)

The following table presents a reconciliation of our Level 3 assets measured at fair value:


	Three Months Ended September 30,				Nine Months Ended September 30,
	2020		2019		2020		2019
	(in thousands)
Fair value of Level 3 instruments, net asset beginning of period	$	26,958	$	22,504	$	8,414	$	58,329
Changes in fair value included in condensed consolidated statement of operations line item:
Commodity price risk management gain (loss), net	(21,521)		10,846		32,840		(22,077)

Settlements included in condensed consolidated statement of operations line items:
Commodity price risk management loss, net	(14,652)		(2,445)		(50,469)		(5,347)

Fair value of Level 3 instruments, net asset end of period	$	(9,215)	$	30,905	$	(9,215)	$	30,905

Net change in fair value of Level 3 unsettled derivatives included in condensed consolidated statement of operations line item:
Commodity price risk management gain (loss), net	$	(13,171)	$	6,787	$	9,466	$	(11,620)

Three Months Ended March 31,
2020 2019
(in thousands)
Fair value of Level 3 instruments, net asset beginning of period $ 8,414
$ 58,329
Changes in fair value included in condensed consolidated statement of operations line item:
Commodity price risk management gain (loss), net 67,530
(43,520 )
Settlements included in condensed consolidated statement of operations line items:
Commodity price risk management gain (loss), net (8,704 ) (1,819 )
Fair value of Level 3 instruments, net asset end of period $ 67,240
$ 12,990

Net change in fair value of Level 3 unsettled derivatives included in condensed consolidated statement of operations line item:
Commodity price risk management gain (loss), net $ 59,417
$ (38,680 )

The significant unobservable input used in the fair value measurement of our derivative contracts is the implied volatility curve, which is provided by a third-party vendor. A significant increase or decrease in the implied volatility, in isolation, would have a directionally similar effect resulting in a significantly higher or lower fair value measurement of our Level 3 derivative contracts. There has been no change in the methodology we apply to measure the fair value of our Level 3 derivative contracts during the periods covered by the financial statements.

Non-Derivative Financial Assets and Liabilities

We utilize fair value on a nonrecurring basis to review our proved crude oil and natural gas properties for possible impairment when events and circumstances indicate a possible decline in the recoverability of the carrying value of such assets. The fair value of the properties is determined based upon estimated future discounted cash flow, a Level 3 input, using estimated production and prices at which we reasonably expect the crude oil and natural gas will be sold. Unobservable inputs include estimated future crude oil and natural gas production, forward strip commodity pricing curves (adjusted for basis differentials), operating and development costs, future development plans and a discount rate of 17 percent, which was based on a weighted-average cost of capital for the area for which the assets are located (all of which were designated as Level 3 inputs within the fair value hierarchy).

The portion of our long-term debt related to our revolving credit facility approximates fair value, ~~due to~~as the applicable interest rates are variable ~~nature~~and reflective of ~~related interest~~market rates. We have not elected to account for the portion of our debt related to our senior notes under the fair value option; however, we have determined an estimate of the fair values based on measurements of trading activity and broker and/or dealer quotes, respectively, which are published market prices, and therefore are Level 2 inputs. The table below presents these estimates of the fair value of the portion of our long-term debt related to our senior notes and convertible notes.


		As of September 30, 2020				As of December 31, 2019
		Estimated Fair Value		Percent of Par		Estimated Fair Value		Percent of Par
		(in millions)
Senior Notes:
	2021 Convertible Notes	$	192.6	96.3	%	$	188.6	94.3	%
	2024 Senior Notes	382.8		95.7	%	409.2		102.3	%
	2025 Senior Notes	96.1		93.9	%	0		0	%
	2026 Senior Notes (1)	696.8		92.9	%	599.4		99.9	%

As of March 31, 2020 As of December 31, 2019
Estimated Fair Value Percent of Par Estimated Fair Value Percent of Par
(in millions)
Senior notes:
2021 Convertible Notes $ 162.0
81.0 % $ 188.6
94.3 %
2024 Senior Notes 225.6
56.4 % 409.2
102.3 %
2025 Senior Notes 52.5
51.3 % —
— %
2026 Senior Notes 307.8
51.3 % 599.4
99.9 %
_____________

(1)Includes additional $150.0 million aggregate principal amount of 2026 Senior Notes issued in September 2020. For further discussion see footnote titled Long-term Debt.

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PDC ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

September 30, 2020

(unaudited)

The carrying value of the financial instruments included in current assets and current liabilities approximate their fair ~~value~~values due to the short-term maturities of these instruments.

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~~PDC ENERGY, INC.~~

~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS~~

~~March 31, 2020~~

~~(unaudited)~~

Concentration of Risk

Derivative Counterparties. A portion of our liquidity relates to commodity derivative instruments that enable us to manage a portion of our exposure to price volatility from producing crude oil and natural gas. These arrangements expose us to credit risk of nonperformance by our counterparties. We primarily use financial institutions who are also lenders under our revolving credit facility as counterparties to our commodity derivative contracts. To date, we have had no derivative counterparty default losses. We have evaluated the credit risk of our derivative assets from our counterparties using relevant credit market default rates, giving consideration to amounts outstanding for each counterparty and the duration of each outstanding derivative position. Based on our evaluation, we have determined that the potential impact of nonperformance of our current counterparties on the fair value of our derivative instruments is not significant at ~~March 31,~~September 30, 2020; however, this determination may ~~change given the volatility of current market conditions.~~change.

Cash and Cash Equivalents. We consider all highly liquid instruments purchased with an original maturity of three months or less to be cash equivalents. Cash and cash equivalents potentially subject us to a concentration of credit risk as substantially all of our deposits held in financial institutions were in excess of the FDIC insurance limits at ~~March 31,~~September 30, 2020 and December 31, 2019. We maintain our cash and cash equivalents in the form of money market and checking accounts with financial institutions that we believe are creditworthy and are also lenders under our revolving credit facility.

NOTE 6 - COMMODITY DERIVATIVE FINANCIAL INSTRUMENTS

Our results of operations and operating cash flows are affected by changes in market prices for crude oil, natural gas and NGLs. To manage a portion of our exposure to price volatility from producing crude oil and natural gas we enter into commodity derivative contracts such as collars, fixed-price swaps and basis protection swaps, to protect against price declines in future periods. We do not enter into derivative contracts for speculative or trading purposes.

Collars are designed to establish floor and ceiling prices on anticipated future oil or gas production, while swaps establish a fixed price for anticipated future oil or gas production. While we structure these commodity derivatives to reduce our exposure to decreases in commodity prices, they also limit the benefit we might otherwise receive from price increases.

We believe our commodity derivative instruments continue to be effective in achieving the risk management objectives for which they were intended. Depending on changes in oil and gas futures markets and management’s view of underlying supply and demand trends, we may increase or decrease our derivative positions from current levels. As of ~~March 31,~~September 30, 2020, we had derivative instruments ~~which were comprised of collars, fixed-price swaps and basis protection swaps,~~ in place for a portion of our anticipated 2020, 2021 and 2022 production. Our commodity derivative contracts have been entered into at no upfront cost to us as we hedge our anticipated production at the then-prevailing commodity market prices, without adjustment for premium or discount.

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PDC ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

~~March 31,~~September 30, 2020

(unaudited)

As of ~~March 31,~~September 30, 2020, we had the following outstanding derivative contracts. When aggregating multiple contracts, the weighted-average contract price is shown.


		Collars					Fixed-Price Swaps												Collars					Fixed-Price Swaps
Commodity/ Index/ Maturity Period		Quantity (Crude oil - MBls Natural Gas - BBtu)	Weighted-Average Contract Price				Quantity (Crude Oil - MBbls Gas and Basis- BBtu )	Weighted- Average Contract Price			Fair Value March 31, 2020 (1) (in thousands)			Commodity/ Index/ Maturity Period						Quantity (Crude oil - MBbls Natural Gas - BBtu)	Weighted-Average Contract Price					Quantity (Crude Oil - MBbls Gas and Basis- BBtu)	Weighted- Average Contract Price				Fair Value September 30, 2020 (1) (in thousands)
			Floors		Ceilings										Floors			Ceilings					Fair Value September 30, 2020 (1) (in thousands)
Crude Oil																	Crude Oil
NYMEX																NYMEX

2020		2,700	$	55.00	$	71.68	9,212	$	59.08		$	331,947		2020						900	$	55.00		$	71.68	3,174	$	58.90			$	71,119
2021		—	—		—		7,180	49.80			94,946			2021						996	35.00			46.22		9,180	46.90				40,547
2022		—	—		—		1,980	34.88			(6,962		)	2022						0	0			0		3,984	40.01				(13,433)
Total Crude Oil		2,700					18,372				$	419,931		Total Crude Oil						1,896						16,338					$	98,233

Natural Gas														Natural Gas
NYMEX														NYMEX
2020		15,250	$	2.00	$	2.23	3,000	$	2.30		$	2,353		2020						17,308	$	2.02		$	2.34	1,000	$	2.30			$	(6,576)
2021		22,200	2.25		2.58		24,000	2.36			(4,203		)	2021						62,625	2.46			2.86		31,800	2.40				(31,070)
2022														2022						8,700	2.50			2.79		8,700	2.62				(21)

Total Natural Gas		37,450					27,000				$	(1,850	)	Total Natural Gas						88,633						41,500					$	(37,667)


Basis Protection - Natural Gas														Basis Protection - Natural Gas
CIG														CIG
2020		—	$	—	$	—	15,375	$	(0.62	)	$	(2,571	)	2020						—	$	—		$	—	17,350	$	(0.48)			$	(4,627)
2021		—	—		—		46,200	(0.50		)	(2,195		)	2021						—	—			—		94,425	(0.46)				(13,433)
2022														2022						—	—			—		17,400	(0.36)				(733)
Waha														Waha
2020		—	—		—		3,000	(1.40		)	(1,516		)	2020						—	—			—		1,000	(1.40)				(511)

Total Basis Protection - Natural Gas		—					64,575				$	(6,282	)	Total Basis Protection - Natural Gas						—						130,175					$	(19,304)


Commodity Derivatives Fair Value	Commodity Derivatives Fair Value										$	411,799		Commodity Derivatives Fair Value															$	41,262

(1)Approximately 14 percent of the fair value of our commodity derivative assets and 28 percent of the fair value of our commodity derivative liabilities were measured using significant unobservable inputs (Level 3).

Subsequent to ~~March 31,~~September 30, 2020, we entered into the following commodity derivative positions covering ~~approximately 21,200~~

~~BBtu and 15,600 BBtu of New York Mercantile Exchange ("NYMEX") and CIG basis~~our natural gas ~~production, at average contract prices of $2.00 and $2.43, respectively, for 2020 and 2021, respectively.~~production:


	Collars					Fixed-Price Swaps
Commodity/ Index/ Maturity Period		Quantity (BBtu)		Weighted-Average Contract Price				Quantity (BBtu)	Weighted- Average Contract Price
	Floors		Ceilings
NYMEX
2022		8,700		$	2.50	$	3.00	—	—
Basis Protection
CIG
2022		—		—		—		8,700	$	(0.31)

We have not elected to designate any of our derivative instruments as cash flow hedges; therefore, these instruments do not qualify for hedge accounting. Accordingly, changes in the fair value of our derivative instruments are recorded in the condensed consolidated statements of operations.

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PDC ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

~~March 31,~~September 30, 2020

(unaudited)

The following table presents the condensed consolidated balance sheet line item and fair value amounts of our derivative instruments as of ~~March 31,~~September 30, 2020 and December 31, 2019:

The following table presents the impact of our derivative instruments on our condensed consolidated statements of operations:

Three Months Ended March 31,
Condensed Consolidated Statement of Operations Line Item 2020 2019
(in thousands)
Commodity price risk management gain (loss), net
Net settlements $ 45,823
$ (8,452 )
Net change in fair value of unsettled derivatives 388,875
(181,622 )
Total commodity price risk management gain (loss), net $ 434,698
$ (190,074 )

Our financial derivative agreements contain master netting provisions that provide for the net settlement of contracts through a single payment in the event of early termination. We have elected not to offset the fair value positions recorded on our condensed consolidated balance sheets.

The following table reflects the impact of netting agreements on gross derivative assets and liabilities:

As of March 31, 2020 Derivative Instruments, Gross Effect of Master Netting Agreements Derivative Instruments, Net
(in thousands)
Asset derivatives:
Derivative instruments, at fair value $ 437,449
$ (24,014 ) $ 413,435

Liability derivatives:
Derivative instruments, at fair value $ 25,650
$ (24,014 ) $ 1,636


As of September 30, 2020	Derivative Instruments, Gross		Effect of Master Netting Agreements		Derivative Instruments, Net
	(in thousands)
Derivative assets:
Derivative instruments, at fair value	$	151,679	$	(51,823)	$	99,856

Derivative liabilities:
Derivative instruments, at fair value	$	110,417	$	(51,823)	$	58,594

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PDC ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

~~March 31,~~September 30, 2020

(unaudited)


As of December 31, 2019	Derivative Instruments, Gross		Effect of Master Netting Agreements		Derivative Instruments, Net
	(in thousands)
Derivative assets:
Derivative instruments, at fair value	$	31,824	$	(2,619)	$	29,205

Derivative liabilities:
Derivative instruments, at fair value	$	3,613	$	(2,619)	$	994

As of December 31, 2019 Derivative Instruments, Gross Effect of Master Netting Agreements Derivative Instruments, Net
(in thousands)
Asset derivatives:
Derivative instruments, at fair value $ 31,824
$ (2,619 ) $ 29,205

Liability derivatives:
Derivative instruments, at fair value $ 3,613
$ (2,619 ) $ 994

NOTE 7 - PROPERTIES AND EQUIPMENT

The following table presents the components of properties and equipment, net of accumulated depreciation, depletion and amortization ("DD&A"):

March 31, 2020 December 31, 2019
(in thousands)
Properties and equipment, net:
Crude oil and natural gas properties
Proved $ 7,131,659
$ 6,241,780
Unproved 385,138
403,379
Total crude oil and natural gas properties 7,516,797
6,645,159
Equipment and other 64,498
41,888
Land and buildings 26,664
12,312
Construction in progress 615,073
408,428
Properties and equipment, at cost 8,223,032
7,107,787
Accumulated DD&A (3,188,538 ) (3,012,585 )
Properties and equipment, net $ 5,034,494
$ 4,095,202

Impairment Charges.During the three months ended March 31, 2020, we recorded impairment charges of $881.1 million. The impairment charges during the three months ended March 31, 2020 were due to a significant decline in crude oil prices, ~~we experienced~~which was considered a triggering event that required us to assess our crude oil and natural gas properties for possible impairment. As a result of our assessment, we recorded impairment charges of $881.1 million to ~~write-down~~ our proved and unproved properties. Of these impairment charges, approximately $753.0 million was related to our Delaware Basin proved properties. These impairment charges represented the amount by which the carrying value of the crude oil and natural gas properties exceeded the estimated fair value. The estimated fair value was determined based on estimated future discounted net cash flows, a Level 3 input, using estimated production and realized prices at which we reasonably expect the crude oil and natural gas will be sold. In addition to our proved property impairment, we also recognized approximately $127.3 million of impairment charges for our unproved properties in the Delaware Basin. These impairment charges were recognized based on a review of our current drilling plans, estimated future cash flows for probable well locations and expected future lease expirations, primarily in areas where we have no development plans.

There were no triggering events identified as of June 30 and September 30, 2020 and therefore we did not recognize any significant impairment write-downs with respect to our proved and unproved properties for the second and third quarter of 2020.

During the nine months ended September 30, 2019, we recorded impairment charges ~~of $7.9~~totaling $10.3 million, ~~recorded for~~including $0.1 million during the three months ended ~~March 31,~~September 30, 2019 ~~were primarily~~ related to leaseholds and leasehold expirations within our non-focus areas of the Delaware Basin where we were no longer pursuing plans to develop the properties. During the nine months ended September 30, 2019, we also recorded impairments of $26.7 million related to certain midstream facility infrastructure in the Delaware Basin. We determined the fair value of the properties based upon estimated future discounted cash flow, a Level 3 input, using estimated production and prices at which we reasonably expect the crude oil and natural gas will be sold.

Midstream Asset Divestitures. During the second quarter of 2019, we completed the sales of our Delaware Basin produced water gathering and disposal, crude oil gathering and natural gas gathering assets (the "Midstream Asset Divestitures") for aggregate proceeds of $345.6 million. The proceeds were received upon closing, with the exception of $82.0 million that we received in June 2020. Concurrent with the Midstream Asset Divestitures, we entered into agreements with the

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PDC ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

~~March 31,~~September 30, 2020

(unaudited)

purchasers which provide us with certain gathering, processing, transportation and water disposal services. See footnote titled Other Accrued Expenses and Other Liabilities for further details regarding these agreements. Proceeds were allocated first to the assets sold based upon the fair values of the tangible assets sold, with the remainder of $179.6 million allocated to the acreage dedication agreements. We recorded an aggregate gain on the sale of $34.0 million based on the fair value of the tangible assets sold.

Suspended Well Costs. The following table presents the capitalized exploratory well cost pending determination of proved reserves and included in properties and equipment, net on the condensed consolidated balance sheets:

During ~~three~~nine months ended ~~March 31,~~September 30, 2020,2wells classified as exploratory at December 31, 2019 were reclassified as productive and 0 new wells drilled were classified as exploratory.

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PDC ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

~~March 31,~~September 30, 2020

(unaudited)

NOTE 8 - OTHER ACCRUED EXPENSES AND OTHER LIABILITIES

Other Accrued Expenses. The following table presents the components of other accrued expenses as of:


	September 30, 2020		December 31, 2019
	(in thousands)

Employee benefits	$	19,833	$	21,611
Asset retirement obligations	30,348		32,200

Environmental expenses	11,988		2,256
Operating and finance leases	8,809		5,926

Other	10,914		8,469
Other accrued expenses	$	81,892	$	70,462

~~(1) Amount includes $8.9 million of environmental liability assumed in the SRC Acquisition.~~

Other Liabilities. The following table presents the components of other liabilities as of:

Deferred Oil Gathering Credits. In 2018, we entered into an agreement that dedicates crude oil production from the majority of our Wattenberg Field acreage to the midstream provider's gathering lines and extends the term of the agreement through December 2029. The ~~payment~~acreage dedication agreement resulted in an initial cash receipt and is being amortized over the life of the agreement. Amortization charges related to this deferred oil gathering credit totaling approximately $0.5 million for each of the three months ended ~~March 31,~~September 30, 2020 and 2019 and $1.5 millionfor each of the nine months ended September 30, 2020 and 2019, are included as a reduction to transportation, gathering and processing ~~expenses in our condensed consolidated statements of operations.~~expenses.

Deferred Midstream Gathering Credits. In the second quarter of 2019, concurrent with the sale of our Delaware Basin midstream assets, we entered into agreements with the purchasers that dedicated the gathering of certain of our production and all water gathering and disposal volumes in the Delaware Basin. The terms of these agreements range from 10 to 22 years. The ~~credits~~acreage dedication agreements resulted in initial cash receipts and are being amortized on a units-of-production basis. ~~Amortization~~The amortization rates are assessed on an annual basis for changes in estimated future production.

The following table presents the amortization charges ~~included~~recognized in the condensed consolidated statements of operations for the periods indicated:


	Three Months Ended September 30,				Nine Months Ended September 30,
	2020		2019		2020		2019
	(in thousands)
Crude oil, natural gas and NGL sales (1)	$	0	$	201	$	368	$	259
Transportation, gathering and processing expenses	1,535		711		2,991		914
Lease operating expenses	686		373		1,458		557

(1)In July 2020, we entered into amendments to existing crude oil sales ~~totaled approximately $0.2 million for the three months ended March 31, 2020. Amortization charges included as~~contracts, which resulted in a ~~reduction~~change in recognition of related deferred credit amortization from a net-back to a gross presentation of transportation, gathering and processing expenses totaled approximately $0.8 million for the three months ended March 31, 2020. Amortization charges included as a reduction to lease operating expenses and capital costs totaled approximately $0.3 million for the three months ended March 31, 2020.expenses.

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PDC ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

~~March 31,~~September 30, 2020

(unaudited)

NOTE 9 - LONG-TERM DEBT

Long-term debt consisted of the following as of:

2021 Convertible Notes. In September 2016, we issued $200 million of 1.125% convertible notes due September 15, 2021 (the "2021 Convertible Notes"). Interest is payable semi-annually on March 15 and September 15. The conversion price at maturity is $85.39 per share. We allocated the gross proceeds of the 2021 Convertible Notes between the liability and equity components of the debt. The initial $160.5 million liability component was determined based on the fair value of similar debt instruments, excluding the conversion feature, priced on the same day we issued the 2021 Convertible Notes. The initial $39.5 million equity component represents the debt discount and was calculated as the difference between the fair value of the debt and the gross proceeds of the 2021 Convertible Notes. Approximately $4.8 million in costs associated with the issuance of the 2021 Convertible Notes were capitalized as debt issuance costs and are being amortized as interest expense over the life of the notes.

Upon conversion, the 2021 Convertible Notes may be settled, at our sole election, in shares of our common stock, cash or a combination thereof. We have initially elected a combination settlement method to satisfy our conversion obligation, which allows us to settle the principal amount of the 2021 Convertible Notes in cash and to settle the excess conversion value, if any, in shares, as well as cash in lieu of fractional shares.

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PDC ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

September 30, 2020

(unaudited)

2024 Senior Notes. In September 2016, we issued $400 million aggregate principal amount of 6.125% senior notes due September 15, 2024 (the “2024 Senior Notes”). Interest is payable semi-annually on March 15 and September 15.

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~~PDC ENERGY, INC.~~

~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS~~

~~March 31, 2020~~

~~(unaudited)~~

Approximately $7.8 million in costs associated with the issuance of the 2024 Senior Notes were capitalized as debt issuance costs and are being amortized as interest expense over the life of the notes.

2025 Senior Notes. Upon completion of the SRC Acquisition in January 2020, we assumed $550 million aggregate principal amount of 6.25% senior notes due December 1, 2025 (the "2025 Senior Notes"). The 2025 Senior Notes were recorded at $555.5 million, representing the approximate fair value. The difference between the acquisition date fair value and the principal amount of the 2025 Senior Notes will be recognized as a reduction to interest expense over the remaining life of the notes. Interest is payable semi-annually on June 1 and December 1.

On January 17, 2020, we commenced an offer to repurchase the 2025 Senior Notes from the holders at 101 percent of the principal amount of the 2025 Senior Notes, together with any accrued and unpaid interest. Upon expiration of the repurchase offer on February 18, 2020, holders of $447.7 million of the outstanding 2025 Senior Notes accepted the redemption offer for a total redemption price of approximately $452.2 million, plus accrued and unpaid interest of $6.2 million. The fair value of the 2025 Senior Notes approximated the repurchase offer price, resulting in recognition of an immaterial loss on extinguishment of the repurchased notes. The repurchase was funded by proceeds from our revolving credit facility. An aggregate principal amount of approximately $102.3 million remains outstanding.

2026 Senior Notes.In November 2017, we issued ~~$600~~$600.0 million aggregate principal amount of 5.75% senior notes due May 15, 2026 (the "2026 Senior Notes"). Interest is payable semi-annually on May 15 and November 15. Approximately $7.6 million in costs associated with the issuance of the 2026 Senior Notes were capitalized as debt issuance costs and are being amortized as interest expense over the life of the notes.

In September 2020, we issued an additional $150.0 million aggregate principal amount of the 2026 Senior Notes at a price equal to 99 percent of par, which resulted in net proceeds of $146.7 million, after deducting the original issuance discount of $1.5 million and debt issuance costs of $1.8 million. The additional 2026 Senior Notes issued have the same terms and conditions as the existing 2026 Senior Notes.

Our wholly-owned subsidiary, PDC Permian, Inc., is a guarantor of our obligations under the 2021 Convertible Notes, the 2024 Senior Notes, the 2025 Senior Notes and the 2026 Senior Notes (collectively, the "Notes"). As of ~~March 31,~~September 30, 2020, we were in compliance with all covenants related to the Notes.

Revolving Credit Facility

In May 2018, we entered into a Fourth Amended and Restated Credit Agreement (the “Restated Credit Agreement”). Among other things, the Restated Credit Agreement provides for a maximum credit amount of $2.5 billion. The amount we may borrow under the Restated Credit Agreement is subject to certain limitations. As a result of closing the SRC Acquisition, the borrowing base on our revolving credit facility increased to $2.1 billion and we elected to increase the aggregate commitment amount under our revolving credit facility to $1.7 billion. On May 5, 2020, we entered into a Second Amendment to the Restated Credit Agreement (the “Second Amendment”) that amended our interest rate and certain other provisions in the Restated Credit Agreement. In ~~connection with the Second Amendment and~~October 2020, as part of our fall 2020 semi-annual redetermination, ~~of our borrowing base,~~ the borrowing base ~~under the Restated Credit Agreement~~of our credit facility was reduced to ~~$1.7~~$1.6 billion, ~~while maintaining the commitment amount at $1.7~~with a corresponding automatic reduction to our elected commitments of $1.6 billion.

The revolving credit facility is available for working capital requirements, capital investments, acquisitions, to support letters of credit and for general corporate purposes. The borrowing base is based on, among other things, the loan value assigned to the proved reserves attributable to our crude oil and natural gas interests. The borrowing base is subject to a semi-annual redetermination on November 1 and May 1 based upon quantification of our reserves at June 30 and December 31, and is also subject to a redetermination upon the occurrence of certain events. Substantially all of our crude oil and natural gas properties have been mortgaged or pledged as security for our revolving credit facility.

The outstanding principal amount under the revolving credit facility accrues interest at a varying interest rate that fluctuates with an alternate base rate (equal to the greatest of the administrative agent's prime rate, the federal funds rate plus a premium and the rate for dollar deposits in the London interbank market (“LIBOR”) for one month, plus a premium) or, at our election, a rate equal to LIBOR for certain time periods. Additionally, commitment fees, interest margin and other bank fees, charged as a component of interest, vary with our utilization of the facility. As of ~~March 31,~~September 30, 2020, the applicable interest margin is ~~0.5~~0.75 percent for the alternate base rate option or ~~1.5~~1.75 percent for the LIBOR option, and the unused commitment fee

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PDC ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

September 30, 2020

(unaudited)

is 0.375 percent. Principal payments are generally not required until the revolving credit facility expires in May 2023, unless the borrowing base falls below the outstanding balance.

The revolving credit facility contains covenants customary for agreements of this type, with the most restrictive being certain financial tests on a quarterly basis. The financial tests, as defined per the revolving credit facility, include

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~~PDC ENERGY, INC.~~

~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS~~

~~March 31, 2020~~

~~(unaudited)~~

requirements to: (a) maintain a minimum current ratio of 1.0:1.0 and (b) not exceed a maximum leverage ratio of 4.0:1.0. As of ~~March 31,~~September 30, 2020, we were in compliance with all covenants related to the revolving credit ~~facility covenants.~~facility.

As of ~~March 31,~~September 30, 2020 and December 31, 2019, debt issuance costs related to our revolving credit facility were ~~$11.0~~$9.4 million and $8.9 million, respectively, and are included in other ~~assets.~~assets in our condensed consolidated balance sheets. As of ~~March 31,~~September 30, 2020, the weighted-average interest rate on the outstanding balance on our revolving credit facility, exclusive of fees on the unused commitment, was ~~2.7~~2.2 percent.

We determine if an arrangement is representative of a lease at contract inception. Right-of-use ("ROU") assets represent our right to use the underlying assets for the lease term and the corresponding lease liabilities represent our obligations to make lease payments arising from the leases. Operating and finance lease ROU assets and liabilities are recognized at the commencement date based on the present value of the expected lease payments over the lease term. As most of our leases do not provide an implicit interest rate, we utilize our incremental borrowing rate based on information available at the commencement date in determining the present value of lease payments. Subsequent measurement, as well as presentation of expenses and cash flows, will depend upon the classification of the lease as either a finance or operating lease. Terms of our leases include options to extend or terminate the lease only when we can ascertain that it is reasonably certain we will exercise that option.

We have operating leases for office space and compressors and finance leases for vehicles. Our leases have remaining lease terms ranging from one to five years. The vehicle leases include options to renew for up to four years. Lease payments associated with vehicle leases also include a contractually stated residual value guarantee.

The following table presents the components of lease costs:

Lease Costs Three Months Ended March 31, 2020 Three Months Ended March 31, 2019
(in thousands)
Operating lease costs $ 1,881
$ 1,348

Finance lease costs:
  Amortization of ROU assets $ 489
$ 483
  Interest on lease liabilities 55
60
Total finance lease costs $ 544
$ 543
Short-term lease costs 96,073
61,030
  Total lease costs $ 98,498
$ 62,921


	Three Months Ended September 30,				Nine Months Ended September 30,
Lease Costs	2020		2019		2020		2019
	(in thousands)
Operating lease costs	$	2,030	$	1,093	$	5,842	$	3,824

Finance lease costs:
Amortization of ROU assets	473		506		1,462		1,493
Interest on lease liabilities	44		66		150		195
Total finance lease costs	517		572		1,612		1,688
Short-term lease costs	17,975		35,118		149,960		147,223

Total lease costs	$	20,522	$	36,783	$	157,414	$	152,735

Our operating lease costs are recorded in lease operating expenses or general and administrative expense and our finance lease costs are recorded in DD&A expense and interest expense. Our short-term lease costs include amounts that are capitalized as part of the cost of another asset and are recorded as properties and equipment or recognized as expense.

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PDC ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

~~March 31,~~September 30, 2020

(unaudited)

The following table presents the balance sheet classification and other information regarding our leases as of:

Leases Condensed Consolidated Balance Sheet Line Item March 31, 2020 December 31, 2019
(in thousands)
Operating Leases:
  Operating lease ROU assets Other assets $ 16,864
$ 14,926
  Operating lease obligation - short-term Other accrued expenses $ 8,278
$ 4,159
  Operating lease obligation - long-term Other liabilities 13,469
12,944
    Total operating lease liabilities $ 21,747
$ 17,103
Finance Leases:
  Finance lease ROU assets Properties and equipment, net $ 4,556
$ 4,637
     Finance lease obligation - short-term Other accrued expenses $ 1,893
$ 1,767
     Finance lease obligation - long-term Other liabilities 2,614
2,835
    Total finance lease liabilities $ 4,507
$ 4,602
Weighted-average remaining lease term (years)
  Operating leases 3.41
4.28
Finance leases 2.94
3.17
Weighted-average discount rate
     Operating leases 5.0 % 5.0 %
     Finance leases 5.0 % 5.0 %


Leases	Condensed Consolidated Balance Sheet Line Item	September 30, 2020			December 31, 2019
		(in thousands)
Operating Leases:
Operating lease ROU assets	Other assets	$	13,484		$	14,926
Operating lease obligation - short-term	Other accrued expenses	7,183			4,159
Operating lease obligation - long-term	Other liabilities	10,496			12,944
Total operating lease liabilities		$	17,679		$	17,103
Finance Leases:
Finance lease ROU assets	Properties and equipment, net	$	3,647		$	4,637
Finance lease obligation - short-term	Other accrued expenses	1,626			1,767
Finance lease obligation - long-term	Other liabilities	1,998			2,835
Total finance lease liabilities		$	3,624		$	4,602
Weighted-average remaining lease term (years)
Operating leases		3.15			4.28
Finance leases		2.72			3.17
Weighted-average discount rate
Operating leases		5.0		%	5.0		%
Finance leases		5.0		%	5.0		%

Maturity of lease liabilities by year and in the aggregate, under operating and financing leases with terms of one year or more, as of ~~March 31,~~September 30, 2020 consist of the following:

Operating Leases Finance Leases Total
(in thousands)
2020 $ 6,870
$ 1,549
$ 8,419
2021 7,026
1,604
8,630
2022 5,493
937
6,430
2023 1,559
641
2,200
2024 950
95
1,045
Thereafter 1,698
—
1,698
Total lease payments 23,596
4,826
28,422
Less interest and discount (1,849 ) (319 ) (2,168 )
Present value of lease liabilities $ 21,747
$ 4,507
$ 26,254

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PDC ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

~~March 31,~~September 30, 2020

(unaudited)

NOTE 11 - ASSET RETIREMENT OBLIGATIONS

The following table presents the changes in carrying amounts of the asset retirement obligations associated with our working interests in crude oil and natural gas properties:

Amount
(in thousands)

Balance at December 31, 2019 $ 127,251
Obligations incurred with development activities and other 5,357
Obligations incurred with acquisition 43,953
Accretion expense 2,620
Obligations discharged with asset retirements (9,597 )
Balance at March 31, 2020 169,584
Current portion (30,930 )
Long-term portion $ 138,654

Our estimated asset retirement obligations liability is based on historical experience in plugging and abandoning wells, estimated economic lives and estimated plugging, abandonment and surface reclamation costs considering federal and state regulatory requirements in effect at that time. The liability is discounted using the credit-adjusted risk-free rate estimated at the time the liability is incurred or revised. To the extent future revisions to these assumptions impact the present value of the existing asset retirement obligations liability, a corresponding adjustment is made to the properties and equipment balance. Changes in the liability due to the passage of time are recognized as an increase in the carrying amount of the liability and as accretion expense. Short-term asset retirement obligations are included in other accrued ~~expenses.~~expenses in our condensed consolidated balance sheets.

NOTE 12 - COMMITMENTS AND CONTINGENCIES

Firm Transportation and Processing Agreements. We enter into contracts that provide firm transportation and processing on pipeline systems through which we transport or sell crude oil and natural gas. Satisfaction of the volume requirements includes volumes produced by us, purchased from third parties and produced by other third-party working, royalty and overriding royalty interest owners whose volumes we market on their behalf. Our condensed consolidated statements of operations reflect our share of these firm transportation and processing costs. These contracts require us to pay these transportation and processing charges whether or not the required volumes are delivered. ~~Given current market conditions, we~~We may from time to time find ourselves unable to market our commodities at prices acceptable to us, or at all, which could cause us to be unable to meet these obligations. In such cases, we may be subject to penalties, fees, minimum margins or other payments.

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PDC ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

~~March 31,~~September 30, 2020

(unaudited)

The following table presents gross volume information related to our long-term firm transportation, sales and processing agreements for pipeline capacity and water delivery and disposal commitments:

For the Twelve Months Ending March 31,
Area 2021 2022 2023 2024 2025 and
Through
Expiration Total Expiration
Date

Natural gas (MMcf)
Wattenberg Field 63,922
63,922
63,922
64,098
118,925
374,789

August 31, 2026
Delaware Basin 33,410
25,222
9,125
9,150
63,900
140,807

March 31, 2031
Gas Marketing 7,117
6,966
2,830
—
—
16,913

August 31, 2022
Total 104,449
96,110
75,877
73,248
182,825
532,509

Crude oil (MBbls)
Wattenberg Field 13,703
16,507
21,718
16,737
55,796
124,461

March 31, 2029
Delaware Basin 8,580
8,030
8,030
6,050
—
30,690

December 31, 2023
Total 22,283
24,537
29,748
22,787
55,796
155,151

Water (MBbls)
Wattenberg Field 6,207
6,207
6,207
6,223
4,676
29,520

December 31, 2024

Dollar commitment (in thousands) $ 139,258
$ 128,413
$ 133,551
$ 112,411
$ 294,673
$ 808,306

Wattenberg Field. We ~~have~~ entered into two facilities expansion agreements with our primary midstream provider to expand and improve its natural gas gathering pipelines and processing facilities. The midstream provider completed and turned on line the first of the two 200 MMcfd cryogenic plants in August 2018 and the second plant was completed in August 2019. We are bound to the volume requirements in these agreements on the first day of the calendar month following the actual in-service date of the relevant plant. Both agreements require baseline volume commitments, consisting of our gross wellhead volume delivered in November 2016 to this midstream provider, and incremental wellhead volume commitments of 51.5 MMcfd and 33.5 MMcfd for the first and second agreements, respectively, for seven years. In addition, as a result of the SRC Acquisition, we are subject to substantially similar facilities expansion agreements with the same primary midstream provider of 46.4 MMcfd and 43.8 MMcfd, respectively. We may be required to pay shortfall fees for any volumes under the 97.9 MMcfd and 77.3 MMcfd incremental commitments. Any shortfall in these volume commitments may be offset by other producers’ volumes sold to the midstream provider that are greater than a certain total baseline volume. We are also required for the first three years of the contracts to guarantee a certain target profit margin to the midstream provider on these incremental volumes. The actual shortfall in target profit margin incurred, which we guaranteed to our midstream provider, was included as part of contract assets as part of Other assets in the condensed consolidated balance sheets.

Delaware Basin. In May 2018, we entered into a firm sales agreement that is effective from June 2018 through December 2023 with an integrated marketing company for our crude oil production in the Delaware Basin. Contracted volumes are currently 24,000 barrels of crude oil per day and decrease over time to 22,000 barrels ~~of crude oil~~ per day. This agreement is expected to provide price diversification through realization of export market pricing via a Corpus Christi terminal and exposure to Brent-weighted prices.

Crude Oil, Natural Gas and NGLs Sales. For the three months ended ~~March 31,~~September 30, 2020 and 2019, amounts related to long-term transportation volumes in the table above were ~~$6.4~~$4.5 million and ~~$10.9~~$13.7 million, respectively, and were netted against our crude oil and natural gas sales. For the nine months ended September 30, 2020 and 2019, amounts related to long-term transportation volumes in the table above were $17.6 million and $36.8 million, respectively, and were netted against our crude oil and natural gas sales.

Litigation and Legal Items. We are involved in various legal proceedings. We review the status of these proceedings on an ongoing basis and, from time to time, may settle or otherwise resolve these matters on terms and conditions that management believes are in our best interests. We have provided the necessary estimated accruals in the accompanying balance

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PDC ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

September 30, 2020

(unaudited)

sheets where deemed appropriate for litigation and legal related items that are ongoing and not yet concluded. Although the results cannot be known with certainty, we currently believe that the ultimate results of such proceedings will not have a material adverse effect on our financial position, results of operations or liquidity.

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~~PDC ENERGY, INC.~~

~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS~~

~~March 31, 2020~~

~~(unaudited)~~

Environmental. Due to the nature of the natural gas and oil industry, we are exposed to environmental risks. We have various policies and procedures to minimize and mitigate the risks from environmental contamination. We conduct periodic reviews and simulated drills to identify changes in our environmental risk profile. Liabilities are recorded when environmental damages resulting from past events are probable and the costs can be reasonably estimated. Except as discussed herein, we are not aware of any material environmental claims existing as of ~~March 31,~~September 30, 2020 which have not been provided for or would otherwise have a material impact on our financial statements; however, there can be no assurance that current regulatory requirements will not change or that unknown potential past non-compliance with environmental laws or other environmental liabilities will not be discovered on our properties. Accrued environmental liabilities are recorded in other accrued ~~expenses.~~expenses in the condensed consolidated balance sheets. The liability ultimately incurred with respect to a matter may exceed the related accrual.

On October 23, 2018, we agreed to an Administrative Order by Consent ("AOC") with the COGCC relating to a historical release discovered during the decommissioning of a location in Weld County, Colorado, pursuant to which, among other things, we agreed to a penalty of approximately $130,000, of which 20 percent would be suspended subject to compliance with certain corrective actions identified in the AOC. In addition to the penalty, we agreed to timely complete certain corrective actions set forth in the AOC relating to procedures for completing future work on buried or partially buried produced water vessels, and to reestablish vegetation and otherwise reclaim the location. We have completed the corrective actions in a timely manner and some of our reclamation activities are ongoing.

In recent years, we have been executing a program to plug and abandon certain of our older vertical wells in the Wattenberg Field. A self-audit of final reclamation activities associated with site retirements, which we concluded in 2019, identified deficiencies, including incomplete documentation and agency submittals, inadequate plant growth and incomplete earthwork. In December 2019, we formally disclosed these deficiencies to the ~~COGCC~~Colorado Oil and Gas Conservation Commission ("COGCC") and are working to close this backlog of site reclamation work. On August 19, 2020, COGCC issued to PDC a Notice of Alleged Violation ("NOAV") citing a failure to comply with reclamation requirements at multiple locations. During 2020, we are similarly assessing reclamation activities at sites acquired through the SRC Acquisition. We do not believe potential penalties and other expenditures associated with the deficiencies disclosed to the COGCC and the resulting NOAV, nor any potential future disclosure of deficiencies associated with reclamation of sites acquired in the SRC Acquisition, will have a material effect on our financial condition or results of operations, but they may exceed $100,000.

In July 2020, a ruling by the U.S. Court of Appeals for the District of Columbia Circuit found that the U.S. Environmental Protection Agency (“EPA”) established the northern boundary of the Denver Metro/Northern Front Range ozone non-attainment area based on erroneous criteria and ordered the EPA to reconsider that boundary, potentially including more land within the designated area. All of our Wattenberg Field operations and leaseholds are within the current non-attainment area. Accordingly, we do not expect the ruling to impact us, regardless of the results of the EPA’s boundary reconsideration.

As part of our integration activities over the facilities acquired through the SRC Acquisition, we are in the process of conducting a comprehensive air quality compliance audit. We do not believe potential penalties and other expenditures associated with deficiencies identified through the audit will have a material effect on our financial condition or results of operations, but they may exceed $100,000.

Clean Air Act Agreement and Related Consent Decree. In June 2017, following our receipt of a 2015 Clean Air Act information request from the EPA and a 2015 compliance advisory from the Colorado Department of Public Health and Environment's (“CDPHE”) Air Pollution Control Division, the U.S. Department of Justice, on behalf of the EPA and the state of Colorado, filed a complaint against us in the U.S. District Court for the District of Colorado, claiming that we failed to operate and maintain certain condensate collection facilities at 65 facilities so as to minimize leakage of volatile organic compounds in compliance with applicable law.

In October 2017, we entered into a consent decree to resolve the lawsuit and the compliance advisory. Pursuant to the consent decree, we agreed to implement a variety of operational enhancements, and ~~mitigation~~environmental mitigations and similar projects, including vapor control system modifications and verification, increased inspection and monitoring and installation of tank pressure monitors. ~~The three primary elements~~While many of those actions are complete, some requirements will continue until the consent decree ~~are: (i) fine/supplemental environmental projects ($1.5 million cash fine, plus $1 million in supplemental environmental projects)~~is terminated.

In addition, as a result of ~~which~~ the ~~cash fines~~SRC Acquisition, we are subject to the obligations and the full cost of supplemental environmental projects were paid in the first and third quarters of 2018, respectively, (ii) injunctive relief with an estimated cost of approximately $18 million, primarily representing capital enhancements to our operations and (iii) mitigation with an estimated cost of $1.7 million continue to incur costs associated with these activities. If we fail to comply fully with the requirements of a 2018 Compliance Order on Consent (“COC”) entered into by SRC with CDPHE, applicable to certain SRC oil and gas production facilities. The CDPHE has agreed to revise the COC to make the inspection and monitoring requirements, among others, consistent with those contained in our consent decree with respect to those matters, we could be subject to additional liability. We do not believe that the expenditures resulting from the settlement will have a material adverse effect on our condensed consolidated financial statements.decree.

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PDC ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

September 30, 2020

(unaudited)

Since the consent decree took effect, and more recently was expanded to include the COC, we have timely implemented the various programs that meet its requirements. Over the course of this execution, we have identified certain immaterial deficiencies in our implementation of the programs. We report these immaterial deficiencies to the appropriate authorities and remediate them promptly. We do not believe that the penalties and expenditures associated with the consent decree, including any sanctions associated with these deficiencies, will have a material effect on our financial condition or results of operations, but they may exceed $100,000.

In addition, in December 2018, we were named as a nominal defendant in a derivative action filed in the Delaware chancery court. The complaint, which seeks unspecified monetary damages and various forms of equitable relief, alleges that certain current and former members of our Board of Directors (the "Board") violated their fiduciary duties, committed waste

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~~PDC ENERGY, INC.~~

~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS~~

~~March 31, 2020~~

~~(unaudited)~~

and were unjustly enriched by, among other things, failing to implement adequate environmental safeguards in connection with the issues that gave rise to the Department of Justice lawsuit and consent decree. We believe that this lawsuit is without merit but cannot predict its outcome.

Further, we could be the subject of other enforcement actions by regulatory authorities in the future relating to our past, present or future operations.

NOTE 13 - COMMON STOCK

Stock-Based Compensation Plans

2018 Equity Incentive Plan. In May ~~2018,~~2020, our stockholders approved aan amendment to increase the number of shares of our common stock reserved for issuance pursuant to our long-term equity compensation plan for ~~our~~ employees and non-employee directors (the “2018 Plan”). from 1,800,000 to 7,050,000. The 2018 Plan ~~provides for a reserve of 1,800,000 shares of our common stock that may be issued pursuant to awards under the~~was approved in May 2018 ~~Plan~~ and ~~a term that~~ expires in March 2028. Shares issued may be ~~either~~ authorized but unissued shares, treasury shares or any ~~combination.~~combination thereof. Additionally, the 2018 Plan permits the reuse or reissuance of shares of common stock which were canceled, expired, forfeited or paid out in the form of cash. However, shares tendered or withheld to satisfy the exercise price of options or tax withholding obligations, and shares covering the portion of exercised stock-settled stock appreciation rights ("SARs") (regardless of the number of shares actually delivered), count against the share limit. Awards may be issued in the form of options, SARs, restricted stock, restricted stock units ("RSUs"), performance stock units ("PSUs") and other stock-based awards. Awards may vest over periods of continued service or upon the satisfaction of performance conditions set at the discretion of the Compensation Committee of the Board (the "Compensation Committee"), with a minimum one-year vesting period applicable to most awards. With regard to SARs and options, awards have a maximum exercisable period of ten years. As of ~~March 31,~~September 30, 2020, there were ~~485,079~~5,244,358 shares available for grant under the 2018 Plan.

2010 Long-Term Equity Compensation Plan. Our Amended and Restated 2010 Long-Term Equity Compensation Plan, which was ~~most recently~~ approved by stockholders in 2013 (as the same has been amended and restated from time to time, the "2010 Plan"), ~~will remain~~remains outstanding and we may continue to use the 2010 Plan to grant awards. No awards may be granted under the 2010 Plan on or after June 5, 2023. As of ~~March 31,~~September 30, 2020, there were ~~78,011~~159,237 shares available for grant under the 2010 Plan.

2015 SRC Equity Incentive Plan. Pursuant to the closing of the SRC Acquisition, SRC granted 155,928 PSUs to certain SRC executives under the 2015 SRC Equity Incentive Plan (the “2015 SRC Plan”). These PSUs (the “SRC PSUs”) were granted ~~immediately~~ prior to ~~execution~~the consummation of the ~~Merger Agreement,~~merger, were assumed and converted into PDC PSUs at a rate of 0.158 per share and remain subject to the same terms and conditions (including performance-vesting terms) that applied immediately prior to the closing of the SRC Acquisition. The PSUs will result in a payout between 0 and 200 percent of the target PSUs awarded. As of ~~March 31,~~September 30, 2020, there were no shares available for grant under the 2015 SRC Plan.

Stock-based Compensation. The ~~following table provides a summary of the~~ impact of our ~~outstanding~~ stock-based compensation plans on ~~the~~our results of operations was $5.4 million and $17.4 million for the ~~periods presented:~~

Three Months Ended March 31,
2020 2019
(in thousands)

Stock-based compensation expense $ 5,672
$ 4,683
Income tax benefit (1,375 ) (1,120 )
Net stock-based compensation expense $ 4,297
$ 3,563

three and nine months ended September 30, 2020, respectively, and $5.9 million and $18.1 million for the three and nine months ended September 30, 2019, respectively.

Restricted Stock Units

Time-Based Awards. The fair value of the time-based RSUs is amortized ratably over the requisite service period, primarily three years. The time-based RSUs generally vest ratably on each anniversary following the grant date provided that a participant is continuously employed.

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PDC ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

~~March 31,~~September 30, 2020

(unaudited)

The following table presents the changes in non-vested time-based RSUs to all employees, including executive officers, for the ~~three~~nine months ended ~~March 31,~~September 30, 2020:

Shares Weighted-Average
Grant Date
Fair Value per Share

Non-vested at December 31, 2019 795,926
$ 45.51
Granted 316,778
22.73
Vested (168,998 ) 47.34
Forfeited (21,927 ) 44.89
Non-vested at March 31, 2020 921,779
37.36

The following table presents the weighted-average grant date fair value per share and related information as of/for the periods presented:

As of/Three Months Ended March 31,
2020 2019
(in thousands, except per share data)

Total intrinsic value of time-based awards vested $ 3,748
$ 3,311
Total intrinsic value of time-based awards non-vested 5,724
28,544
Market price per share as of March 31 6.21
40.68
Weighted-average grant date fair value per share 22.73
38.59

Total compensation cost related to non-vested time-based awards and not yet recognized in our condensed consolidated statements of operations as of ~~March 31,~~September 30, 2020 was ~~$23.5~~$15.7 million. This cost is expected to be recognized over a weighted-average period of 2.0 years.

Performance Stock Units

Market-Based Awards. The fair value of the market-based PSUs is amortized ratably over the requisite service period, primarily three years. The market-based shares vest if the participant is continuously employed throughout the performance period and the market-based performance measure is achieved, with a maximum vesting period of three years. All compensation cost related to the market-based awards will be recognized if the requisite service period is fulfilled, even if the market condition is not achieved.

The Compensation Committee awarded a total of ~~278,889~~368,077 market-based PSUs to our executive officers during the ~~three~~nine months ended ~~March 31,~~September 30, 2020. In addition to continuous employment, the vesting of these PSUs is contingent on a combination of absolute stock performance and our total stockholder return ("TSR"), which is essentially our stock price change, including any dividends over a three-year period ending on December 31, 2022, as compared to the TSR of a group of peer companies over the same period. The PSUs will result in a payout between 0 and 250 percent of the target PSUs awarded. The weighted-average grant date fair value per PSU granted was computed using the Monte Carlo pricing model using the following assumptions:

Three Months Ended March 31,
2020 2019

Expected term of award (in years) 3
3
Risk-free interest rate 1.4 % 2.5 %
Expected volatility 46.6 % 41.4 %

The expected term of the awards was based on the requisite service period. The risk-free interest rate was based on the U.S. Treasury yields in effect at the time of grant and extrapolated to approximate the life of the award. The expected volatility was based on our historical volatility.

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PDC ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

~~March 31,~~September 30, 2020

(unaudited)

SRC Performance Stock Units. ~~Terms~~The terms of the SRC PSUs are substantially the same as those of the PDC PSUs, except that the ~~awards~~SRC PSUs do not require continuous employment and the performance period associated with the awards of January 1, 2019 through December 31, 2021 predates the grant date. The fair value of the SRC PSU awards was determined on the grant date of January 13, 2020 using the Monte Carlo pricing model using the following assumptions:

Three Months Ended March 31,
2020

Expected term of awards (in years) 2
Risk-free interest rate 1.6 %
Expected volatility 56.9 %
Weighted-average grant date fair value per share $ 33.35

The expected term of the awards is based on the number of years from the grant date through the end of the performance period. The risk-free interest rate was based on the U.S. Treasury yields in effect at the time of grant, extrapolated to approximate the life of the awards. The expected volatility was based on our historical volatility, as well as that of our peer group.

The following table presents the change in non-vested market-based awards, including SRC PSUs, during the ~~three~~nine months ended ~~March 31,~~September 30, 2020:

Shares
Weighted-Average
Grant Date
Fair Value per Share

Non-vested at December 31, 2019
221,142
$ 61.61
Granted
434,817
33.46
Non-vested at March 31, 2020 655,959
42.95

The following table presents the weighted-average grant date fair value per share and related information as of/for the periods presented:

As of/Three Months Ended March 31,
2020 2019
(in thousands, except per share data)

Total intrinsic value of market-based awards non-vested $ 4,074
$ 9,849
Market price per common share as of March 31, 6.21
40.68
Weighted-average grant date fair value per share 33.46
56.68

Total compensation cost related to non-vested market-based awards not yet recognized in our condensed consolidated statements of operations as of ~~March 31,~~September 30, 2020 was ~~$15.3~~$9.3 million. This cost is expected to be recognized over a weighted-average period of ~~2.1~~1.7 years.

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PDC ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

~~March 31,~~September 30, 2020

(unaudited)

Stock Appreciation Rights

The SARs vest ratably over a three-year period and may generally be exercised at any point after vesting through ten years from the date of issuance. Pursuant to the terms of the awards, upon exercise, the executive officers will receive, in shares of common stock, the excess of the market price of the award on the date of exercise over the market price of the award on the date of issuance. The following table presents the change in SARs during the ~~three~~nine months ended ~~March 31,~~September 30, 2020:

Shares Weighted-Average
Grant Date
Fair Value per Share

Outstanding at December 31, 2019 290,258
$ 46.64
Exercised (7,807 ) 24.44
Expired (56,162 ) 45.39
Outstanding at March 31, 2020 226,289
47.72

All outstanding SARs as of ~~March 31,~~September 30, 2020 have vested and the related compensation cost has been fully recognized.

We are authorized to issue 50,000,000 shares of preferred stock, par value $0.01 per share, which may be issued in one or more series, with such rights, preferences, privileges and restrictions as shall be fixed by the Board from time to time. Through ~~March 31,~~September 30, 2020, 0 shares of preferred stock have been issued.

Stock Repurchase Program

In April 2019, the Board approved the acquisition of up to $200 million of our outstanding common stock, depending on market conditions (the "Stock Repurchase Program"). Effective upon the closing of the SRC Acquisition, our Board approved an increase and extension to the Stock Repurchase Program from $200 million to $525 million. Repurchases under the Stock Repurchase Program can be made in open markets at our discretion and in compliance with safe harbor provisions, or in privately negotiated transactions. The Stock Repurchase Program does not require any specific number of shares to be acquired, and can be modified or discontinued by the Board at any time. During the ~~three~~nine months ended ~~March 31,~~September 30, 2020, we repurchased 1.3 million shares of our outstanding common stock at a cost of $23.8 million. ~~The last repurchases occurred~~We suspended the program in ~~early~~ March 2020. Approximately $346.8 million of our outstanding common stock remains available for repurchase under the ~~Stock Repurchase Program; however, further~~program. If the program is reactivated, we expect repurchases made pursuant to the ~~program have been suspended and, if we resume the program, we expect~~Stock Repurchase Program to ~~slow the pace of previously planned share repurchases as we continue to prioritize our financial strength and liquidity.~~extend beyond December 31, 2021, given current market conditions.

NOTE 14 - INCOME TAXES

We compute our quarterly tax provision using the effective tax rate method by applying the anticipated annual effective rate to our year-to-date income or loss, except for discrete items. Income tax on discrete items is computed and recorded in the period in which the specific transaction occurs.

As previously noted, we recorded impairments totaling ~~$881.1~~$882.3 million for the ~~three~~nine months ~~ending March 31,~~ended September 30, 2020. These impairments resulted in three years of cumulative historical pre-tax losses and a net deferred tax asset position. We also have estimated net operating loss carryovers (“NOLs”) for federal income tax purposes of ~~$400.0~~$470.0 million. These losses were a key consideration that led ~~PDC~~us to continue to provide a valuation allowance against ~~its~~our net deferred tax assets as of ~~March 31,~~September 30, 2020 since itwe cannot conclude that it is more likely than not that ~~its~~our net deferred tax asset will be fully realized in future periods.

The ultimate realization of deferred tax assets is dependent upon the generation of future taxable income during the periods in which those temporary differences become deductible. At each reporting period, management considers the scheduled reversal of deferred tax liabilities, available taxes in carryback periods, tax planning strategies and projected future taxable income in making this assessment. Future events or new evidence which may lead us to conclude that it is more likely than not that our net deferred tax assets will be realized include, but are not limited to, cumulative historical pre-tax earnings,

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PDC ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

~~March 31,~~September 30, 2020

(unaudited)

sustained or continued improvements in oil prices, and taxable events that could result from one or more transactions. We will continue to evaluate whether the valuation allowance is needed in future reporting periods.

As ~~long as we conclude that we will continue~~noted in the footnote Business Combinations, the accounting for the SRC Acquisition is still in the measurement period. Additional adjustments during the measurement period for the SRC Acquisition may have an impact on the income tax provision in future periods, although such adjustments are not expected to ~~have a need for a valuation allowance against our net deferred tax assets,~~be material. Other than business combination accounting adjustments during the measurement period, we will likely not have any additional income tax expense or benefit other than for state income ~~taxes.~~taxes as long as we continue to conclude that it is appropriate to maintain a full valuation allowance against our net deferred tax assets.

The effective income tax ~~rates~~rate for the three and nine months ended September 30, 2020 was a 0.6 percent provision on loss and a 0.5 percent benefit on loss, respectively, compared to a 40.1 percent provision on income for the three months ended ~~March 31,~~September 30, 2019 and a 10.4 percent benefit on loss for the nine months ended September 30, 2019. The effective tax rate for the three and nine months ended September 30, 2020 differs from the amount that would be provided by applying the statutory U.S. federal income tax rate of 21% to pre-tax income due to the effect of a full valuation allowance in effect at September 30, 2020. The effective tax rate for the three and nine months ended September 30, 2019 ~~were 1.6 percent~~differs from the statutory U.S. federal income tax rate of 21% due to state income taxes, non-deductible lobbying expenses, stock-based compensation and ~~23.7 percent, respectively.~~non-deductible officers’ compensation.

As of ~~March 31,~~September 30, 2020, there is no liability for unrecognized income tax benefits. As of the date of this report, we are current with our income tax filings in all applicable state jurisdictions and are not currently under any state income tax examinations. The IRS ~~partially~~has accepted our 2018 ~~tax return. The 2018~~federal income tax return ~~is in the IRS CAP Program post-filing review process,~~ with no ~~significant~~ tax ~~adjustments currently proposed.~~adjustments. We continue to voluntarily participate in the IRS CAP Program for the review of our 2019 and 2020 tax year. Participation in the IRS CAP Program has enabled us to have minimal uncertain tax benefits associated with our federal tax return filings.

NOTE 15 - EARNINGS PER SHARE

Basic earnings per share is computed by dividing net earnings by the weighted-average number of common shares outstanding for the period. Diluted earnings per share is similarly computed, except that the denominator includes the effect, using the treasury stock method, of unvested equity-based employee awards, convertible notes and shares held pursuant to our non-employee director deferred compensation plan, if including such potential shares of common stock is dilutive.

The following table presents our weighted-average basic and diluted shares outstanding:

Three Months Ended March 31,
2020 2019
(in thousands)

Weighted-average common shares outstanding - basic 94,077
66,182
Weighted-average common shares and equivalents outstanding - diluted 94,077
66,182

We reported a net loss for the three and nine months ended ~~March 31,~~September 30, 2020 and the ~~three~~nine months ended ~~March 31,~~September 30, 2019. As a result, our basic and diluted weighted-average common shares outstanding were the same for those periods because the effect of the common share equivalents was anti-dilutive.

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PDC ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

September 30, 2020

(unaudited)

The following table presents the weighted-average common share equivalents excluded from the calculation of diluted earnings per share due to their anti-dilutive effect:

Three Months Ended March 31,
2020 2019
(in thousands)

Weighted-average common share equivalents excluded from diluted earnings per share due to their anti-dilutive effect:
RSUs and PSUs 1,319
895
Other equity-based awards 245
302
Total anti-dilutive common share equivalents 1,564
1,197

The 2021 Convertible Notes give the holders, at our election, the right to convert the aggregate principal amount into 2.3 million shares of our common stock at a conversion price of $85.39 per share. The 2021 Convertible Notes were not included in the diluted earnings per share calculation using the treasury stock method for any periods presented because the average market price of our common stock did not exceed the conversion price.

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~~PDC ENERGY, INC.~~

~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS~~

~~March 31, 2020~~

~~(unaudited)~~

NOTE 16 - SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION

Subsequent to the filing of our Quarterly Report on Form 10-Q for the quarterly period ended September 30, 2019, we identified an immaterial error in our condensed consolidated statement of cash flows related to cash paid for capital expenditures for development of crude oil and natural gas properties for the period ended ~~March 31,~~September 30, 2019. Our balance sheet and statement of operations for the relevant period were not impacted. We evaluated the error under the guidance of Accounting Standards Codification 250, Accounting Changes and Error Corrections ("ASC 250"). Based on the guidance in ASC 250, we determined that the error did not have a material impact on our previously-issued financial statements or those of the period of correction.

The error resulted in an overstatement of cash flows from operations of $24.8 million and an overstatement of cash used in investing activities of $24.8 million in each period as follows:

Three Months Ended
March 31, 2019
(dollars in thousands)
Cash flows from operating activities, as reported $ 181,853
Adjustment (24,753 )
Cash flows from operating activities, as adjusted $ 157,100

Cash flows from investing activities, as reported $ (271,664 )
Adjustment 24,753
Cash flows from investing activities, as adjusted $ (246,911 )

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PDC ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

September 30, 2020

(unaudited)

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PDC ENERGY, INC.

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

The following discussion and analysis should be read in conjunction with our condensed consolidated financial statements and related notes included elsewhere in this report. Further, we encourage you to review the Special Note Regarding Forward-Looking Statements.

~~March 31,~~September 30, 2020 Financial Overview of Operations and Liquidity

We have been adversely affected ~~as a result of~~by the ongoing global COVID-19 pandemic, including its effects on commodity demand and pricing, downstream capacity, employee health and safety, business continuity and regulatory matters. We expect those impacts to continue in the near-term and we may experience additional impacts in the future. See Item 1A. Risk Factors for additional information regarding the potential impacts of the COVID-19 pandemic.

Production volumes increased to ~~16.8~~17.7 MMboe and 51.8 MMboe for the three and nine months ended ~~March 31,~~September 30, 2020, respectively, representing ~~an increase~~increases of 5039 percent and 43 percent as compared to the three and nine months ended ~~March 31, 2019.~~September 30, 2019, respectively. The majority of the increase can be attributed to producing properties received in the SRC Acquisition. Total liquids production of crude oil and NGLs comprised 5961 percent and 60 percent of production during the three and nine months ended ~~March 31, 2020.~~September 30, 2020, respectively. For the month ended ~~March 31,~~September 30, 2020, we maintained an average daily production rate of approximately ~~194,000~~181,000 Boe per day, up from approximately ~~124,000~~138,000 Boe per day for the month ended ~~March 31,~~September 30, 2019.

On a sequential quarterly basis, total production for the three months ended ~~March 31,~~September 30, 2020 increased three percent to 17.7 MMboe as compared to 17.2 MMboe for the three months ended ~~December 31, 2019 increased by 3.8~~MMboe, or 29 percent, with the increase in production attributable to producing properties received in the SRC Acquisition. The increase was partially offset by the impact of decreased capital investments during the fourth quarter of 2019.June 30, 2020.

Crude oil, natural gas and NGLs sales revenue increased to $314.9 million for the three months ended ~~March 31,~~September 30, 2020 compared to $307.4 million for the three months ended September 30, 2019 and ~~2019 were~~decreased to $809.2 million for the nine months ended September 30, 2020 compared to $967.5 million for the comparable period of 2019. The year to date decrease in revenues between periods was primarily due to the 3441 percent decrease in weighted-average realized commodity prices, ~~being~~partially offset by the 5042 percent increase in production.

We had positive net settlements from our commodity derivative contracts of ~~$45.8~~$66.9 million and $227.5 million for the three and nine months ended September 30, 2020, respectively, as compared to positive net settlements of $1.8 million for the three months ended ~~March 31, 2020, as compared to~~September 30, 2019 and negative net settlements of ~~$8.5~~$19.8 million for the ~~three~~nine months ended ~~March 31,~~September 30, 2019.

The combined revenue from crude oil, natural gas and NGLs sales and net settlements from our commodity derivative instruments increased 1723 percent to ~~$366.1~~$381.8 million for the three months ended ~~March 31,~~September 30, 2020 from ~~$312.6~~$309.2 million for the three months ended ~~March 31,~~September 30, 2019 and increased nine percent to $1,036.7 million for the nine months ended September 30, 2020 from $947.7 million for the nine months ended September 30, 2019.

For the three months ended ~~March 31,~~September 30, 2020, we generated a net loss of ~~$465.0~~$30.8 million, or ~~$4.94~~$0.31 per diluted share, compared to a net ~~loss~~income of ~~$120.2~~$15.9 million, or ~~$1.82~~$0.25 per diluted share, for the comparable period in 2019. Our net loss for the three months ended ~~March 31,~~September 30, 2020 as compared to the net income for the three months ended ~~March 31,~~September 30, 2019 was primarily due to a negative net change in the fair value of commodity derivatives, partially offset by decrease in loss on sale of properties and equipment of $44.2 million between periods. For the nine months ended September 30, 2020, we generated a net loss of $717.6 million, or $7.34 per diluted share, compared to a net loss of $35.7 million, or $0.55 per diluted share, for the comparable period in 2019. Our net loss for the nine months ended September 30, 2020 as compared to the nine months ended September 30, 2019 was most significantly impacted by the increase in impairment of properties and equipment and the decrease in crude oil, natural gas and NGLs sales, partially offset by the commodity price risk management gain.

During the three and nine months ended ~~March 31,~~September 30, 2020, our adjusted EBITDAX, a non-U.S. GAAP financial measure, was ~~$228.1~~$278.8 million and $705.2 million, respectively, compared to ~~$208.8~~$214.7 million and $646.4 million for the comparable ~~period~~periods in 2019. The ~~increase~~increases for the three and nine months ended ~~March 31,~~September 30, 2020 ~~was~~were primarily due to the increase in ~~the gain on~~ commodity derivative settlements of ~~$54.3~~$65.1 million ~~which was~~and $247.3 million, respectively, partially offset by ~~the increase~~increases in lease operating ~~costs~~expenses, transportation, gathering and processing expenses and general and administrative expense between periods.

Our cash flows from operations were ~~$266.3~~$649.3 millionand ~~$157.1~~$651.0 million and our adjusted cash flows from operations, a non-U.S. GAAP financial measure, were ~~$209.8~~$652.8 million and ~~$192.5~~$601.9 million for the ~~three~~nine months ended ~~March 31,~~September 30, 2020 and ~~March 31,~~September 30, 2019, respectively.~~Free cash flow deficit, a non-U.S. GAAP financial measure, was $51.0 million and $89.4 million for the three months ended March 31, 2020 and 2019, respectively. Free cash flow deficit for the three months ended March 31, 2020 includes approximately $20.2 million of transaction costs incurred related to the SRC Acquisition.~~

See Reconciliation of Non-U.S. GAAP Financial Measures below for a more detailed discussion of these non-U.S. GAAP financial measures and a reconciliation of these measures to the most comparable U.S. GAAP measures.

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~~PDC ENERGY, INC.~~

In January 2020, we merged with SRC in a transaction valued at $1.7 billion, inclusive of SRC's net debt. Upon closing, we issued approximately 39 million shares of our common stock to SRC shareholders and holders of SRC equity awards, reflecting the issuance of 0.158 of a share of our common stock in exchange for each share of SRC common stock and the cancellation of outstanding SRC equity awards pursuant to the Merger Agreement.

Available liquidity as of ~~March 31,~~September 30, 2020 was ~~$1.1~~$1.4 billion, which was comprised of ~~$61.2~~$3.8 million of cash and cash equivalents and ~~$1.1~~$1.4 billion available for borrowing under our revolving credit facility.

~~Pursuant~~ In September 2020, we issued an additional $150.0 million principal amount of our 2026 Senior Notes. The net proceeds from the offering were used to ~~closing~~repay a portion of the ~~SRC Acquisition,~~amount outstanding under our revolving credit facility. Total net repayments of revolver borrowings during the third quarter of 2020 were $368.0 million. In October 2020, as part of our fall 2020 semi-annual redetermination, the borrowing base of our credit facility was reduced from $1.7 billion to$1.6 billion, with a corresponding automatic reduction to our elected commitments to $1.6 billion. Looking forward into 2021, based on our expected cash flows from operations, our cash and cash equivalents and availability under our revolving credit facility, ~~increased~~we believe that we will have sufficient capital available to ~~$2.1 billion~~repay our 2021 Convertible Notes, which mature in September 2021, and ~~we elected~~ to ~~increase~~fund our planned activities through the ~~aggregate commitment amount under~~12-month period following the ~~facility to$1.7 billion. On May 5, 2020, we entered into the Second Amendment, and, in connection with the Second Amendment and as part~~filing of ~~our semi-annual redetermination of our borrowing base, the borrowing base under the revolving credit facility was reduced to $1.7 billion, while maintaining the commitment amount at $1.7 billion.~~this report.

As part of the SRC Acquisition, we assumed $550 million in 6.25% Senior Notes due December 2025 and paid off and terminated SRC's revolving credit facility, which had an outstanding balance of $165 million at closing.The indenture governing the SRC Senior Notes has a change of control provision and on January 17, 2020, we commenced an offer to repurchase the SRC Senior Notes at 101 percent of the principal amount of the notes, together with any accrued and unpaid interest. Upon expiration of the repurchase offer on February 18, 2020, holders of $447.7 million of the outstanding SRC Senior Notes accepted our redemption offer for a total redemption price of approximately $452.2 million, plus accrued and unpaid interest of $6.2 million. The repurchase was funded by proceeds from our revolving credit facility. An aggregate principal amount of approximately $102.3 million remains outstanding.

~~Stock Repurchase Program~~

In April 2019, the Board approved the Stock Repurchase Program. Effective upon the closing of the SRC Acquisition, our Board approved an increase and extension to the Stock Repurchase Program from $200 million to $525 million. During the three months ended March 31, 2020, we repurchased 1.3 million shares of our outstanding common stock at a cost of $23.8 million. The last repurchases occurred in early March 2020. Approximately $346.8 million remains available for repurchases under the Stock Repurchase Program; however, further repurchases pursuant to the program have been suspended and, if we resume the program, we expect to slow the pace of previously planned share repurchases as we continue to prioritize our financial strength and liquidity.

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~~PDC ENERGY, INC.~~

Drilling and Completion Overview

The following tables summarize our drilling and completion activity for the ~~three~~nine months ended ~~March 31,~~September 30, 2020:


	Operated Wells
	Wattenberg Field		Delaware Basin		Total
	Gross	Net	Gross	Net	Gross	Net
In-process as of December 31, 2019	145	134.3	30	29.1	175	163.4
Wells spud	86	77.5	2	2.0	88	79.5
Wells acquired in-process (1)	88	81.9	—	—	88	81.9
Wells turned-in-line	(101)	(93.5)	(13)	(13.0)	(114)	(106.5)

In-process as of September 30, 2020	218	200.2	19	18.1	237	218.3

Operated Wells
Wattenberg Field Delaware Basin Total
Gross Net Gross Net Gross Net
In-process as of December 31, 2019 145
134.3
30
29.1
175
163.4
Wells spud 42
36.3
1
1.0
43
37.3
Wells acquired in-process (1) 88
80.5
—
—
88
80.5
Wells turned-in-line (47 ) (44.0 ) (6 ) (6.0 ) (53 ) (50.0 )
In-process as of March 31, 2020 228
207.1
25
24.1
253
231.2
(1)Represents in-process wells and wells being completed that we received as part of the SRC Acquisition.

Non-Operated Wells
Wattenberg Field Delaware Basin Total
Gross Net Gross Net Gross Net
In-process as of December 31, 2019 41
5.3
—
—
41
5.3
Wells spud 64
6.6
—
—
64
6.6
Wells acquired in-process (now operated by PDC) (1) (15 ) (1.1 ) —
—
(15 ) (1.1 )
Wells turned-in-line (27 ) (2.4 ) —
—
(27 ) (2.4 )
In-process as of March 31, 2020 63
8.4
—
—
63
8.4
(1)Represents in-process wells and wells being completed that we received as part of the SRC Acquisition.

Our in-process wells represent wells that are in the process of being drilled or have been drilled and are waiting to be fractured and/or for gas pipeline connection. Our in-process wells are generally completed and turned-in-line within a year of drilling.

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PDC ENERGY, INC.

2020 Operational and Financial Outlook

In February 2020, the Board approved our initial 2020 development plan. This plan ~~was~~is based upon our February 2020 internal outlook for crude oil and natural gas prices, favorable debt metrics and the strength of our balance sheet, including our hedge position for 2020. Since ~~approving our 2020 development plan in February 2020,~~that time, future commodity prices, and future crude oil prices in particular, have significantly declined. As a result, in April 2020, we finalized a comprehensive revision to our 2020 development plan, which includes estimated service cost savings ~~as well as~~and further reductions to planned drilling and completion activity.

Our ~~revised~~ 2020 capital investments in crude oil and natural gas properties are now expected to range between $500 million and ~~$600~~$550 million. The revised 2020 development plan is based upon our current outlook for the remainder of the year and is subject to further revision due to the significant volatility in market conditions and historically high levels of uncertainty affecting the oil and gas exploration sector. We will further revise our development plans as necessary to react to market conditions in the best interest of our shareholders, while prioritizing our financial strength and liquidity

We currently anticipate that our total production for 2020 will range between ~~170,000~~175,000 Boe to ~~180,000~~185,000 Boe per day, approximately ~~60,000~~64,000 Bbls to ~~65,000~~68,000 Bbls of which are expected to be crude oil. This decrease as compared to our ~~earlier estimate~~initial 2020 development plan is reflective of, among other things, ~~an expected~~a curtailment of ~~20 percent to 30 percent of~~ our ~~anticipated May 2020~~second quarter production volumes ~~with potential for increasing curtailments in mid-2020,~~ in response to takeaway capacity or market limitations, decreases in NYMEX pricing and significantly widened differentials, largely due to the global COVID-19 pandemic.

We believe that we maintain a degree of operational flexibility to control the pace of our capital spending and may further revise our 2020 capital investment program during the year. As we execute our capital investment program, we will continue to monitor potential further deterioration of commodity prices and our internal long-term outlook for commodity prices throughout 2020, as well as expected rates of return, the political environment, requirements to hold acreage, the cost of services for drilling and well completion activities, drilling results, changes in our borrowing capacity, cash flows, requirements

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~~PDC ENERGY, INC.~~

to maintain continuous activity on leaseholds or acquisition and/or divestiture opportunities and our remaining inventory in order to best meet our short- and long-term corporate strategy. Should commodity pricing or the operating environment further deteriorate, we may determine that additional adjustments to our development plan are appropriate.


	Three Months Ended March 31,			Year Ended December 31, 2019				Nine Months Ended September 30,		Year Ended December 31, 2019
	(in thousands, except for number of wells)							(in thousands, except for number of wells)

Beginning balance	$	16,078		$	12,188		Beginning balance	$	16,078	$	12,188
Additions to capitalized exploratory well costs pending the determination of proved reserves	11,408			31,901			Additions to capitalized exploratory well costs pending the determination of proved reserves	11,540		31,901
Reclassifications to proved properties	(20,311		)	(28,011		)	Reclassifications to proved properties	(20,392)		(28,011)

Ending balance	$	7,175		$	16,078		Ending balance	$	7,226	$	16,078

Number of wells pending determination at period-end	2			4			Number of wells pending determination at period-end	2		4


	March 31, 2020		December 31, 2019			September 30, 2020		December 31, 2019
	(in thousands)					(in thousands)

Production taxes	$	140,175	$	68,020	Production taxes	$	46,500	$	68,020
Deferred oil gathering credits	19,597		20,100		Deferred oil gathering credits	18,593		20,100
Deferred midstream gathering credits	174,638		175,897		Deferred midstream gathering credits	170,508		175,897
Operating and finance leases	16,083		15,779		Operating and finance leases	12,494		15,779
Other	2,885		3,337		Other	2,440		3,337
Other liabilities	$	353,378	$	283,133	Other liabilities	$	250,535	$	283,133



	March 31, 2020			December 31, 2019
	(in thousands)
Senior Notes:
1.125% Convertible Notes due September 2021:
Principal amount	$	200,000		$	200,000
Unamortized discount	(12,691		)	(14,763		)
Unamortized debt issuance costs	(1,422		)	(1,666		)
Net of unamortized discount and debt issuance costs	185,887			183,571

6.125% Senior Notes due September 2024:
Principal amount	400,000			400,000
Unamortized debt issuance costs	(4,366		)	(4,611		)
Net of unamortized debt issuance costs	395,634			395,389

6.25% Senior Notes due December 2025:
Principal amount	102,324			—
Unamortized premium	990			—
Net of unamortized premium	103,314			—

5.75% Senior Notes due May 2026:
Principal amount	600,000			600,000
Unamortized debt issuance costs	(5,511		)	(5,734		)
Net of unamortized debt issuance costs	594,489			594,266

Total senior notes	1,279,324			1,173,226

Revolving Credit Facility:
Revolving credit facility due May 2023	617,000			4,000
Total long-term debt, net of unamortized discount and debt issuance costs	$	1,896,324		$	1,177,226


	September 30, 2020		December 31, 2019
	(in thousands)
Senior Notes:
1.125% Convertible Notes due September 2021:
Principal amount	$	200,000	$	200,000
Unamortized discount	(8,458)		(14,763)
Unamortized debt issuance costs	(934)		(1,666)
Net of unamortized discount and debt issuance costs	190,608		183,571

6.125% Senior Notes due September 2024:
Principal amount	400,000		400,000
Unamortized debt issuance costs	(3,876)		(4,611)
Net of unamortized debt issuance costs	396,124		395,389

6.25% Senior Notes due December 2025:
Principal amount	102,324		0
Unamortized premium	914		0
Net of unamortized premium	103,238		0

5.75% Senior Notes due May 2026:
Principal amount	750,000		600,000
Unamortized discount	(1,490)		0
Unamortized debt issuance costs	(6,873)		(5,734)
Net of unamortized discount and debt issuance costs	741,637		594,266

Total senior notes	1,431,607		1,173,226

Revolving Credit Facility:
Revolving credit facility due May 2023	285,000		4,000
Total debt, net of unamortized discount and premium and debt issuance costs	1,716,607		1,177,226
Less current portion of long-term debt	190,608		0
Long-term debt	$	1,525,999	$	1,177,226



	Three Months Ended March 31, 2019
	Common Stock							Treasury Stock
	Shares		Amount		Additional Paid-in Capital			Shares		Amount			Retained Earnings (Deficit)			Total Stockholders' Equity

Balance, December 31, 2018	66,148,609		$	661	$	2,519,423		(45,220	)	$	(2,103	)	$	8,727		$	2,526,708
Net loss	—		—		—			—		—			(120,176		)	(120,176		)
Stock-based compensation	112,626		—		2,136			—		2,547			—			4,683
Purchase of treasury shares for employee stock-based compensation tax withholding obligations	—		—		—			(41,787	)	(1,460		)	—			(1,460		)
Issuance of treasury shares	(64,372	)	1		(1		)	64,372		—			—			—
Balance, March 31, 2019	66,196,863		$	662	$	2,521,558		(22,635	)	$	(1,016	)	$	(111,449	)	$	2,409,755



	As of March 31, 2020									As of December 31, 2019
	Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)			Total			Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)			Total
	(in thousands)
Total assets	$	365,263		$	72,186		$	437,449		$	22,886		$	8,938		$	31,824
Total liabilities	(20,704		)	(4,946		)	(25,650		)	(3,089		)	(524		)	(3,613		)
Net asset	$	344,559		$	67,240		$	411,799		$	19,797		$	8,414		$	28,211


~~(1)~~	Approximately 16.5 percent of the fair value of our commodity derivative assets and 19.3 percent of the fair value of our commodity derivative liabilities were measured using significant unobservable inputs (Level 3).



			Fair Value
Derivative Instruments:		Condensed Consolidated Balance Sheet Line Item	March 31, 2020		December 31, 2019
			(in thousands)
Derivative assets:	Current
	Commodity derivative contracts	Fair value of derivatives	$	379,355	$	27,766
	Basis protection derivative contracts	Fair value of derivatives	—		312
			379,355		28,078
	Non-current
	Commodity derivative contracts	Fair value of derivatives	58,094		3,746
Total derivative assets			$	437,449	$	31,824

Derivative liabilities:	Current
	Commodity derivative contracts	Fair value of derivatives	$	5,910	$	529
	Basis protection derivative contracts	Fair value of derivatives	5,710		2,392
			11,620		2,921
	Non-current
	Commodity derivative contracts	Fair value of derivatives	13,458		692
	Basis protection derivative contracts	Fair value of derivatives	572		—
			14,030		692
Total derivative liabilities			$	25,650	$	3,613


	Three Months Ended September 30,				Nine Months Ended September 30,
Condensed Consolidated Statement of Operations Line Item	2020		2019		2020		2019
	(in thousands)
Commodity price risk management gain (loss), net
Net settlements	$	66,895	$	1,845	$	227,513	$	(19,800)
Net change in fair value of unsettled derivatives	(134,956)		53,022		18,338		(68,058)
Total commodity price risk management gain (loss), net	$	(68,061)	$	54,867	$	245,851	$	(87,858)


	Amount
	(in thousands)

Balance at December 31, 2019	$	127,251
Obligations incurred with development activities and other	7,588
Obligations incurred with acquisition	47,158
Accretion expense	7,398

Obligations discharged with asset retirements	(25,545)
Obligations discharged with divestitures	(146)
Balance at September 30, 2020	163,704

Current portion	(30,348)
Long-term portion	$	133,356


	For the Twelve Months Ending September 30,
Area	2021		2022		2023		2024		2025 and Through Expiration		Total		Expiration Date

Natural gas (MMcf)
Wattenberg Field	63,922		63,922		63,922		64,098		86,876		342,740		August 31, 2026
Delaware Basin	32,022		14,510		9,125		9,150		57,075		121,882		March 31, 2031
Gas Marketing	7,117		6,228		0		0		0		13,345		August 31, 2022

Total	103,061		84,660		73,047		73,248		143,951		477,967

Crude oil (MBbls)
Wattenberg Field	17,338		15,500		13,035		9,882		18,900		74,655		August 31, 2026
Delaware Basin	8,214		8,030		8,030		2,024		0		26,298		December 31, 2023
Total	25,552		23,530		21,065		11,906		18,900		100,953

Water (MBbls)
Wattenberg Field	6,207		6,207		6,206		6,224		1,564		26,408		December 31, 2024



Dollar commitment (in thousands)	$	140,186	$	117,235	$	97,036	$	70,981	$	117,736	$	543,174



	For the Twelve Months Ending March 31,
Area	2021		2022		2023		2024		2025 and Through Expiration		Total		Expiration Date

Natural gas (MMcf)
Wattenberg Field	63,922		63,922		63,922		64,098		118,925		374,789		August 31, 2026
Delaware Basin	33,410		25,222		9,125		9,150		63,900		140,807		March 31, 2031
Gas Marketing	7,117		6,966		2,830		—		—		16,913		August 31, 2022
Total	104,449		96,110		75,877		73,248		182,825		532,509

Crude oil (MBbls)
Wattenberg Field	13,703		16,507		21,718		16,737		55,796		124,461		March 31, 2029
Delaware Basin	8,580		8,030		8,030		6,050		—		30,690		December 31, 2023
Total	22,283		24,537		29,748		22,787		55,796		155,151

Water (MBbls)
Wattenberg Field	6,207		6,207		6,207		6,223		4,676		29,520		December 31, 2024

Dollar commitment (in thousands)	$	139,258	$	128,413	$	133,551	$	112,411	$	294,673	$	808,306


	Shares	Weighted-Average Grant Date Fair Value per Share

Non-vested at December 31, 2019	795,926	$	45.51
Granted	1,151,273	12.00
Vested	(444,611)	41.87
Forfeited	(300,841)	22.87
Non-vested at September 30, 2020	1,201,747	20.42


	As of/Nine Months Ended September 30,
	2020		2019
	(in thousands, except per share data)

Total intrinsic value of time-based awards vested	$	6,124	$	11,251
Total intrinsic value of time-based awards non-vested	14,896		22,673
Market price per share as of September 30	12.40		27.75
Weighted-average grant date fair value per share	12.00		40.38



	As of/Three Months Ended March 31,
	2020		2019
	(in thousands, except per share data)

Total intrinsic value of time-based awards vested	$	3,748	$	3,311
Total intrinsic value of time-based awards non-vested	5,724		28,544
Market price per share as of March 31	6.21		40.68
Weighted-average grant date fair value per share	22.73		38.59


	Nine Months Ended September 30,
	2020

Expected term of awards (in years)	2
Risk-free interest rate	1.6		%
Expected volatility	56.9		%
Weighted-average grant date fair value per share	$	33.35


	Shares	Weighted-Average Grant Date Fair Value per Share

Outstanding at December 31, 2019	290,258	$	46.64
Exercised	(7,807)	24.44
Expired	(71,776)	40.83
Outstanding at September 30, 2020	210,675	49.45



	Three Months Ended
	March 31, 2019
	(dollars in thousands)
Cash flows from operating activities, as reported	$	181,853
Adjustment	(24,753		)
Cash flows from operating activities, as adjusted	$	157,100

Cash flows from investing activities, as reported	$	(271,664	)
Adjustment	24,753
Cash flows from investing activities, as adjusted	$	(246,911	)


	Nine Months Ended
	September 30, 2019
	(dollars in thousands)
Cash flows from operating activities, as reported	$	675,725
Adjustment	(24,753)
Cash flows from operating activities, as adjusted	$	650,972

Cash flows from investing activities, as reported	$	(596,973)
Adjustment	24,753
Cash flows from investing activities, as adjusted	$	(572,220)



~~(1)~~	~~Represents in-process wells and wells being completed that we received as part of the SRC Acquisition.~~


	Non-Operated Wells
	Wattenberg Field		Delaware Basin		Total
	Gross	Net	Gross	Net	Gross	Net
In-process as of December 31, 2019	41	5.3	—	—	41	5.3
Wells spud	68	7.2	—	—	68	7.2
Wells spud and subsequently sold prior to turned-in-line	(39)	(7.7)	—	—	(39)	(7.7)
Wells acquired in-process (now operated by PDC) (1)	(15)	(1.1)	—	—	(15)	(1.1)
Wells turned-in-line	(27)	(0.9)	—	—	(27)	(0.9)
In-process as of September 30, 2020	28	2.8	—	—	28	2.8


	Low			High
Operating Expenses
Lease operating expenses (in millions)	$	160		$	165
Transportation, gathering and processing expenses ("TGP") ($/Boe)	$	1.00		$	1.15
Production taxes (% of crude oil, natural gas and NGLs sales)	5		%	6		%
General and administrative expense (in millions)(1)	$	135		$	140


	Three Months Ended March 31, 2020				Three Months Ended September 30, 2020		Nine Months Ended September 30, 2020
	(in millions)				(in millions)
Change in:				Change in:
Production	$	127.4		Production	$	87.9	$	316.6

Average crude oil price	(51.5		)	Average crude oil price	(91.7)		(375.5)
Average natural gas price	(45.1		)	Average natural gas price	4.0		(49.9)
Average NGLs price	(31.6		)	Average NGLs price	7.3		(49.5)
Total change in crude oil, natural gas and NGLs sales revenue	$	(0.8	)	Total change in crude oil, natural gas and NGLs sales revenue	$	7.5	$	(158.3)


	Three Months Ended September 30,				Nine Months Ended September 30,
Production by Operating Region	2020	2019	Percent Change		2020	2019	Percent Change
Crude oil (MBbls)
Wattenberg Field	4,888	3,525	38.7	%	14,984	10,777	39.0	%
Delaware Basin	1,141	1,328	(14.1)	%	3,149	3,500	(10.0)	%


Total	6,029	4,853	24.2	%	18,133	14,277	27.0	%
Natural gas (MMcf)
Wattenberg Field	35,450	22,945	54.5	%	105,286	67,139	56.8	%
Delaware Basin	6,297	6,328	(0.5)	%	18,516	16,777	10.4	%


Total	41,747	29,273	42.6	%	123,802	83,916	47.5	%
NGLs (MBbls)
Wattenberg Field	4,006	2,178	83.9	%	11,037	6,086	81.4	%
Delaware Basin	708	805	(12.0)	%	1,991	2,005	(0.7)	%


Total	4,714	2,983	58.0	%	13,028	8,091	61.0	%
Crude oil equivalent (MBoe)
Wattenberg Field	14,803	9,527	55.4	%	43,569	28,053	55.3	%
Delaware Basin	2,898	3,187	(9.1)	%	8,225	8,301	(0.9)	%


Total	17,701	12,714	39.2	%	51,794	36,354	42.5	%
Average crude oil equivalent per day (Boe)
Wattenberg Field	160,902	103,554	55.4	%	159,011	102,758	54.7	%
Delaware Basin	31,500	34,641	(9.1)	%	30,018	30,407	(1.3)	%

Total	192,402	138,195	39.2	%	189,029	133,165	42.0	%


	Three Months Ended September 30,						Nine Months Ended September 30,
Weighted-Average Realized Sales Price by Operating Region					Percent Change						Percent Change
(excluding net settlements on derivatives)	2020		2019				2020		2019
Crude oil (per Bbl)
Wattenberg Field	$	37.52	$	52.64	(28.7)	%	$	32.28	$	52.84	(38.9)	%
Delaware Basin	37.33		52.84		(29.4)	%	34.09		54.70		(37.7)	%
Weighted-average price	37.49		52.70		(28.9)	%	32.59		53.30		(38.9)	%
Natural gas (per Mcf)
Wattenberg Field	$	1.12	$	1.04	7.7	%	$	1.04	$	1.50	(30.7)	%
Delaware Basin	0.34		0.41		(17.1)	%	0.17		0.55		(69.1)	%
Weighted-average price	1.00		0.91		9.9	%	0.91		1.31		(30.5)	%
NGLs (per Bbl)
Wattenberg Field	$	9.70	$	7.76	25.0	%	$	7.87	$	11.06	(28.8)	%
Delaware Basin	11.50		10.22		12.5	%	9.48		14.53		(34.8)	%
Weighted-average price	9.97		8.43		18.3	%	8.12		11.92		(31.9)	%
Crude oil equivalent (per Boe)
Wattenberg Field	$	17.70	$	23.76	(25.5)	%	$	15.60	$	26.29	(40.7)	%
Delaware Basin	18.24		25.42		(28.2)	%	15.73		27.69		(43.2)	%
Weighted-average price	17.79		24.18		(26.4)	%	15.62		26.61		(41.3)	%



~~(1)~~		~~Negative realized natural gas pricing due to the deduction for transportation, gathering and processing by the purchaser exceeding the average sales price of natural gas.~~
	Amounts may not recalculate due to rounding.



For the Three Months Ended March 31, 2020	Average NYMEX Price		Average Realized Price Before Transportation, Gathering and Processing Expenses		Average Realization Percentage Before Transportation, Gathering and Processing Expenses		Average Transportation, Gathering and Processing Expenses		Average Realized Price After Transportation, Gathering and Processing Expenses		Average Realization Percentage After Transportation, Gathering and Processing Expenses
Three Months Ended September 30, 2020													Three Months Ended September 30, 2020	Average NYMEX Price		Average Realized Price Before Transportation, Gathering and Processing Expenses		Average Realization Percentage Before Transportation, Gathering and Processing Expenses		Average Transportation, Gathering and Processing Expenses		Average Realized Price After Transportation, Gathering and Processing Expenses		Average Realization Percentage After Transportation, Gathering and Processing Expenses
Crude oil (per Bbl)	$	46.17	$	42.32	92	%	$	1.46	$	40.86	88	%	Crude oil (per Bbl)	$	40.93	$	37.49	92	%	$	3.00	$	34.49	84	%
Natural gas (per MMBtu)	1.95		0.96		49	%	0.11		0.85		44	%	Natural gas (per MMBtu)	1.98		1.00		51	%	0.12		0.88		44	%
NGLs (per Bbl)	46.17		7.78		17	%	—		7.78		17	%	NGLs (per Bbl)	40.93		9.97		24	%	—		9.97		24	%
Crude oil equivalent (per Boe)	32.08		19.02		59	%	0.77		18.25		57	%	Crude oil equivalent (per Boe)	29.50		17.79		60	%	1.30		16.49		56	%

For the Three Months Ended March 31, 2019	Average NYMEX Price		Average Realized Price Before Transportation, Gathering and Processing Expenses		Average Realization Percentage Before Transportation, Gathering and Processing Expenses		Average Transportation, Gathering and Processing Expenses		Average Realized Price After Transportation, Gathering and Processing Expenses		Average Realization Percentage After Transportation, Gathering and Processing Expenses
Three Months Ended September 30, 2019													Three Months Ended September 30, 2019	Average NYMEX Price		Average Realized Price Before Transportation, Gathering and Processing Expenses		Average Realization Percentage Before Transportation, Gathering and Processing Expenses		Average Transportation, Gathering and Processing Expenses		Average Realized Price After Transportation, Gathering and Processing Expenses		Average Realization Percentage After Transportation, Gathering and Processing Expenses
Crude oil (per Bbl)	$	54.90	$	51.06	93	%	$	1.21	$	49.85	91	%	Crude oil (per Bbl)	$	56.45	$	52.70	93	%	$	1.29	$	51.41	91	%
Natural gas (per MMBtu)	3.15		2.05		65	%	0.19		1.86		59	%	Natural gas (per MMBtu)	2.23		0.91		41	%	0.15		0.76		34	%
NGLs (per Bbl)	54.90		15.55		28	%	0.24		15.31		28	%	NGLs (per Bbl)	56.45		8.43		15	%	—		8.43		15	%
Crude oil equivalent (per Boe)	41.17		28.63		70	%	0.98		27.65		67	%	Crude oil equivalent (per Boe)	39.92		24.18		61	%	0.83		23.35		58	%



	Three Months Ended March 31, 2020
	(in millions)
Increase in production	$	72.2
Decrease in weighted-average depreciation, depletion and amortization rates	(48.3		)
Total increase in DD&A expense related to crude oil and natural gas properties	$	23.9


	Three Months Ended September 30,				Nine Months Ended September 30,
Operating Region/Area	2020		2019		2020		2019
	(per Boe)
Wattenberg Field	$	8.33	$	12.42	$	8.80	$	12.32
Delaware Basin	6.87		16.34		10.06		17.07

Total weighted-average	8.16		13.41		9.08		13.41


	As of/Nine Months Ended				As of/Year Ended
	September 30, 2020				December 31, 2019
	Issuer		Guarantor		Issuer		Guarantor
	(in millions)

Assets
Current assets	$	334.5	$	25.3	$	175.8	$	126.0
Intercompany accounts receivable, guarantor subsidiary	110.5		—		348.8		—
Intercompany accounts receivable, non-guarantor subsidiary	—		—		6.3		—
Investment in guarantor subsidiary	1,766.8		—		1,766.8		—
Properties and equipment, net	3,996.5		888.7		2,328.3		1,766.9
Other non-current assets	67.7		4.5		41.8		6.8

Liabilities
Current liabilities	$	726.0	$	30.1	$	306.6	$	52.4
Intercompany accounts payable	—		102.6		—		348.8
Long-term debt	1,526.0		—		1,177.2		—
Other non-current liabilities	248.6		180.3		361.1		211.6

Statement of Operations
Crude oil, natural gas and NGLs sales	$	679.8	$	129.4	$	999.3	$	308.0
Commodity price risk management gain (loss), net	245.9		—		(162.8)		—
Total revenues	927.7		128.2		838.1		308.7
Production costs	165.4		53.0		180.1		89.2
Gross profit	514.4		76.4		819.2		218.8
Impairment of properties and equipment	2.0		880.4		0.3		38.2
Net income (loss)	(34.9)		(681.5)		(24.6)		(30.0)



	As of/Three Months Ended					As of/Year Ended
	March 31, 2020					December 31, 2019
	Issuer		Guarantor			Issuer			Guarantor
	(in millions)

Assets
Current assets	$	614.5	$	104.1		$	175.8		$	126.0
Intercompany accounts receivable, guarantor subsidiary	176.6		—			348.8			—
Intercompany accounts receivable, non-guarantor subsidiary	6.7		—			6.3			—
Investment in guarantor subsidiary	1,766.8		—			1,766.8			—
Properties and equipment, net	4,120.1		914.4			2,328.3			1,766.9
Other non-current assets	118.6		5.6			41.8			6.8

Liabilities
Current liabilities	$	550.3	$	65.3		$	306.6		$	52.4
Intercompany accounts payable	—		176.6			—			348.8
Long-term debt	1,896.3		—			1,177.2			—
Other non-current liabilities	319.5		184.7			361.1			211.6

Statement of Operations
Crude oil, natural gas and NGLs sales	$	272.0	$	48.3		$	999.3		$	308.0
Commodity price risk management gain (loss), net	434.7		—			(162.8		)	—
Total revenues	707.2		48.1			838.1			308.7
Production costs	61.7		19.8			180.1			89.2
Gross profit	210.3		28.5			819.2			218.8
Impairment of properties and equipment	0.8		880.3			0.3			38.2
Net income (loss)	224.8		(689.4		)	(24.6		)	(30.0		)


▪	~~Current market conditions and impacts on our business generally may lead to an increased risk of litigation; and~~



Period	Total Number of Shares Purchased (1) (2)	Average Price Paid per Share		Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs (2)	Approximate Dollar Value of Shares That May Yet Be Purchased Under the Plans or Programs (in millions)

January 1 - 31, 2020	485,948	$	23.72	217,500	$	366.0
February 1 - 29, 2020	585,455	20.95		552,500	354.5
March 1 - 31, 2020	500,782	15.41		496,000	346.8
Total first quarter 2020 purchases	1,572,185	$	20.04	1,266,000	$	346.8


		PDC Energy, Inc.
		(Registrant)


		~~PDC Energy, Inc.~~
		~~(Registrant)~~
Date: November 4, 2020



~~Date: May 7, 2020~~	/s/ Barton Brookman
		Barton Brookman
		President and Chief Executive Officer
		(principal executive officer)

		/s/ R. Scott Meyers
		R. Scott Meyers
		Senior Vice President and Chief Financial Officer
		(principal financial officer)